86 results about "Gas volume fraction" patented technology

A flow measuring system combines a density measuring device and a device for measuring the speed of sound (SOS) propagating through the fluid flow and / or for determining the gas volume fraction (GVF) of the flow. The GVF meter measures acoustic pressures propagating through the fluids to measure the speed of sound αmix propagating through the fluid to calculate at least gas volume fraction of the fluid and / or SOS. In response to the measured density and gas volume fraction, a processing unit determines the density of non-gaseous component of an aerated fluid flow. For three phase fluid flows, the processing unit can determine the phase fraction of the non-gaseous components of the fluid flow. The gas volume fraction (GVF) meter may include a sensing device having a plurality of strain-based or pressure sensors spaced axially along the pipe for measuring the acoustic pressures propagating through the flow.

A flow measuring system is provided that provides at least one of a compensated mass flow rate measurement and a compensated density measurement. The flow measuring system includes a gas volume fraction meter in combination with a coriolis meter. The GVF meter measures acoustic pressures propagating through the fluids to measure the speed of sound αmix propagating through the fluid to calculate at least gas volume fraction of the fluid and / or the reduced natural frequency. For determining an improved density for the coriolis meter, the calculated gas volume fraction and / or reduced frequency is provided to a processing unit. The improved density is determined using analytically derived or empirically derived density calibration models (or formulas derived therefore), which is a function of the measured natural frequency and at least one of the determined GVF, reduced frequency and speed of sound, or any combination thereof. The gas volume fraction (GVF) meter may include a sensing device having a plurality of strain-based or pressure sensors spaced axially along the pipe for measuring the acoustic pressures propagating through the flow.

An apparatus for determining a fluid cut measurement of a multi-liquid mixture includes a first device configured to sense at least one parameter of the mixture to determine a fluid cut of a liquid in the mixture. A second device is configured to determine a concentration of gas in the mixture in response to a speed of sound in the mixture; and a signal processor is configured to adjust the fluid cut of the liquid using the concentration of the gas to determine a compensated fluid cut of the liquid. The parameter of the mixture sensed by the first device may include a density of the mixture (e.g., by way of a Coriolis meter), a permittivity of the mixture (e.g., by way of a resonant microwave oscillator), or an amount of microwave energy absorbed by the mixture (e.g., by way of a microwave absorption watercut meter). The signal processor may employ different correction factors depending on the type of fluid cut device used. The second device may include a gas volume fraction meter.

A method and apparatus for measuring at least one characteristic of an aerated fluid flowing within a pipe is provided, wherein the method includes generating a measured sound speed, a measured density, a pressure and a gas volume fraction for the aerated fluid. The method also includes correcting the measured density responsive to the measured sound speed, the pressure and the gas volume fraction to generate a corrected density. The method further includes calculating a liquid phase density, determining whether the gas volume fraction is above a predetermined threshold value and generating a mass flow rate responsive to whether the gas volume fraction is above the predetermined threshold value.

A flow measuring system is provided that provides at least one of a compensated mass flow rate measurement and a compensated density measurement. The flow measuring system includes a gas volume fraction meter in combination with a coriolis meter. The GVF meter measures acoustic pressures propagating through the fluids to measure the speed of sound αmix propagating through the fluid to calculate at least gas volume fraction of the fluid and / or the reduced natural frequency. For determining an improved density for the coriolis meter, the calculated gas volume fraction and / or reduced frequency is provided to a processing unit. The improved density is determined using analytically derived or empirically derived density calibration models (or formulas derived therefore), which is a function of the measured natural frequency and at least one of the determined GVF, reduced frequency and speed of sound, or any combination thereof. The gas volume fraction (GVF) meter may include a sensing device having a plurality of strain-based or pressure sensors spaced axially along the pipe for measuring the acoustic pressures propagating through the flow.

A system and method for determining characteristics of a multiphase flow in a well / pipe are disclosed. The disclosed system and method use an optical immersion probe including a flow gap across which two or more types of radiation are transmitted in order to measure absorptions of two or more substances within the multiphase flow. Primarily, broadband ultraviolet (UV) and / or near infrared radiations (NIR) are utilized with the probe to gather absorption data at and / or around at least one of the water peaks and at and / or around one or more oil or oil-condensate peaks. This data may be utilized to calculate the water-cut of the multiphase flow over a wider range of gas volume fractions. Additionally, pressure ports having pressure sensors being located on the optical immersion probe for determining the impact pressures and flow rates of different phases of the multiphase flow may also be used.

Multiphase flow measurement in extreme environments such as subsea or in-well is a difficult task for many reasons including reliability, survivability, and longevity issues; accessibility to the equipment; and complexity of the varying flow field as a function of position and time. Embodiments of the present invention provide techniques and apparatus for performing subsea multiphase flow measurement by combining two technologies. One is based on infrared water-cut measurement technology which is capable of measuring water and oil concentrations in multiphase flow with up to 99.5% gas volume fractions. The second technology is based on in-well fiber-optic flow measurement capable of resolving gas and total liquid flow through the measurements of flow velocity, fluid mixture speed of sound, and absolute pressure and temperature at meter location. This hybrid system represents an approach to subsea multiphase metering that may offer advantages compared to traditional systems for some applications.