12results about "Specific gravity using flow properties" patented technology

In some implementations, a method is disclosed that may include operating the Coriolis meter on a process fluid where the process fluid may include a liquid continuous process fluid with particles. The method may include measuring a measured speed of sound of the process fluid, deriving a first correlation input parameter from the measured speed of sound the process fluid, determining at least one correlation output parameter utilizing an optimized Coriolis correction correlation between the correlation output parameter and the first correlation input parameter and at least a second correlation input parameter. Also, the method may include where the optimized Coriolis correction correlation is determined utilizing a training data set which relates the correlation input parameters to the correlation output parameters at a plurality of operating conditions and correcting the at least one measured Coriolis output parameter utilizing the at least one correlation output parameter.

Vibrating a vibration transducer element within a fluid at a vibration frequency, the vibration transducer element comprising an elongated member in contact with the fluid characterized by a width, a half-width equal to half of the width, and a length longer than the width, the half-width being smaller than the propagation depth of the shear wave of the fluid at the vibration frequency; measuring the vibration of the vibration transducer element within the fluid at the vibration frequency; and determining a physical property of the fluid, such as viscosity, viscoelasticity, density, fluid stiffness, loss tangent, storage modulus, loss modulus, or yield stress, based on the measurement of the vibration, to determine the physical property of the fluid.

Differential density system and method. A differential pressure transmitter measures a pressure difference between first and second pressure sensing locations. A reference vessel in fluid communication with the first pressure sensing location contains a reference fluid and a sample vessel in fluid communication with the second pressure sensing location contains a sample fluid. The reference fluid is in a first column above the first pressure sensing location and the sample fluid is in a second column above the second pressure sensing location. The second column is of substantially equal height as the first column. A value of total dissolved solids (TDS) in the sample fluid is determined based on the pressure difference.

A method for measuring the material properties of a viscoelastic fluid using one or more vibrating transducers, the method comprising: vibrating one or more vibrating transducers within the viscoelastic fluid so as to generate a first wave propagating from a first surface of the one or more vibrating transducers and a second wave propagating from a second surface of the one or more vibrating transducers; during vibration of the one or more vibrating transducers, the first surface and the second surface being spaced apart from and oriented with respect to each other such that the first wave and the second wave combine with each other to produce a final constructive or destructive interference; and determining the material properties of the viscoelastic fluid based on the vibration of the one or more vibrating transducers within the viscoelastic fluid.

This invention relates to a Coriolis measuring transmitter and a Coriolis measuring device. The Coriolis measuring transmitter includes: at least a pair of measuring tubes arranged to oscillate relative to each other, wherein each measuring tube includes a centrally located bend; at least one actuator and at least two sensors; two guiding devices, wherein each guiding device includes a fluid chamber having a first opening for connection to a pipe and a second opening for connection to each measuring tube. The Coriolis measuring transmitter is characterized in that each guiding device is formed from multiple portions, particularly two portions, wherein the first portion forms a pipe connection portion, and wherein at least one second portion forms a measuring tube connection portion.

The invention relates to a method (100) for operating a Coriolis meter (1), wherein the method comprises the following steps: recording the measurement voltages from the sensors and creating an asymmetry value sequence (AS) by means of the amplitudes of the measurement voltages for the purpose of diagnosing the Coriolis meter in a first method step (101), checking whether the asymmetry value sequence satisfies at least one invalidity criterion in a second method step (102), creating a stabilized asymmetry value sequence (SAS) on the basis of the asymmetry value sequence by replacing asymmetry measured values with substitute values in a third method step (103), wherein while an invalidity criterion is satisfied a last valid measured value of the asymmetry value sequence is used as the current value of the stabilized asymmetry value sequence, or the stabilized asymmetry value sequence is set to a predetermined value, a first invalidity criterion being based on a variance parameter of the asymmetry value exceeding a first limit value.

The measurement system includes a vibration transducer (10) and electrically coupled measurement system electronics (20) for controlling the transducer and evaluating the vibration measurement signal provided by the transducer. The exciter device has a vibration exciter (31) positioned and oriented such that the drive offset (ΔE) is no greater than 0.5% of the tube length. The measurement system electronics (20) is configured to provide electrical power to the vibration exciter (31) via an electrical drive signal (e1) having a time-varying current, and to at least intermittently provide a drive signal (e1) containing a sinusoidal (second useful) current (eN2) with a (second) (AC) frequency, so as to monitor the mass of the measured substance based on a corresponding (second) useful signal component (s1N2; s2N2) of at least one of the vibration measurement signals (s1, s2).

An apparatus for estimating an oil, water, and solids fraction of a drilling fluid includes a conduit containing the drilling fluid, an electromagnetic sensor in communication with the drilling fluid that senses a combined water and solids fraction, and at least one of a conductivity sensor or a density sensor, each in communication with the drilling fluid. The apparatus also includes a processing system determining the fraction of oil, water, and solids in the drilling fluid using the combined water and solid fraction and at least one of the conductivity value from the conductivity sensor or the density value from the density sensor and a controller coupled to the processing system, the controller having an output coupled to a drilling fluid additive control device controlling an additive to be added to the drilling fluid based on the fraction of oil, water, and solids of the drilling fluid.

The application relates to a gas-liquid two-phase flow parameter measurement method, a measurement device, an apparatus, a computer device, a storage medium and a computer program product. The method comprises the following steps: if a measured value of liquid phase superficial velocity is equal to a calculated value of the liquid phase superficial velocity, then according to the calculated value of the liquid phase superficial velocity, a preset void fraction, a distribution parameter and a gas phase drift velocity, a P index is obtained, a calculated value of the void fraction and a calculated value of gas-liquid two-phase flow density are obtained, the initial value of the gas-liquid two-phase flow density is corrected according to the calculated value of the gas-liquid two-phase flow density, a corrected value of the gas-liquid two-phase flow density is obtained, if the deviation rate of the calculated value of the gas-liquid two-phase flow density and the corrected value of the gas-liquid two-phase flow density is less than a preset value, then according to the calculated value of the gas-liquid two-phase flow density, a measurement result of the gas-liquid two-phase flow is obtained, the calculated value and the corrected value of the gas-liquid two-phase flow density are compared, the density of the gas-liquid two-phase flow measurement is calibrated, and the measurement accuracy is improved.

Fluid property sensors described herein may include a resonator configured to be immersed in a fluid or flowable medium and a vibrator coupled to the resonator, such that vibrations of the vibrator are transmitted to the resonator, e.g., to discourage and / or remove any buildup or deposits on the resonator and / or increase accuracy of the sensors. The frequency of the vibrator is configured to be substantially lower than the frequency of the resonator, such that operation of the resonator is not negatively affected. The vibrator may be located internal to, or external to, a chassis of the device.