A system and method for rheology measurement of a drilling fluid. The system may comprise an ultrasound transmitter positioned to direct ultrasound pulses into the drilling fluid; an ultrasound receiver positioned to receive sound waves reflected from the drilling fluid; and a computer system configured to determine a velocity profile of the drilling fluid based at least in part on the reflected sound waves. The method may comprise flowing at least a portion of the drilling fluid through a rheology measurement system; directing ultrasound pulses into the drilling fluid while the drilling fluid is flowing through the rheology measurement system; measuring sound waves reflected by the drilling fluid; and determining a velocity profile of the drilling fluid based at least on the measured sound waves.

An ultrasonic gas flow meter based on FPGA and DSP consists of ultrasonic gas transducers and sensor components, transmitting/receiving signal channel switch circuits, a driving signal generation and amplification circuit, an echo signal conditioning and collection circuit, a time sequential controlling and signal processing circuit, a man-machine interface, a serial communication module and a power management module, propagation time of ultrasonic echo waves is calculated by adopting a variable ratio threshold and zero-crossing detection method of tracking maximum peak of the echo signal to obtain gas flow rates.

An ultrasonic gas flow meter based on FPGA and DSP consists of ultrasonic gas transducers and sensor components, transmitting/receiving signal channel switch circuits, a driving signal generation and amplification circuit, an echo signal conditioning and collection circuit, a time sequential controlling and signal processing circuit, a man-machine interface, a serial communication module and a power management module, propagation time of ultrasonic echo waves is calculated by adopting a variable ratio threshold and zero-crossing detection method of tracking maximum peak of the echo signal to obtain gas flow rates.

Apparatus features a signal processor or signal processing module configured to: receive signaling containing information about a central air-core of an overflow pipe of a hydrocyclone where fluid flow is concentrated in an outer annular region of the overflow pipe that is against an inner wall of the overflow pipe during a normal operation of the hydrocyclone; and determine corresponding signaling containing information about a collapse of the central air-core of the overflow pipe of the hydrocyclone during an abnormal operation of the hydrocyclone, based upon the signaling received. The signaling contains information about a fluid flow rate of the fluid flow by detecting a change in the magnitude of a force and/or a moment on the probe.

Apparatus features a signal processor or signal processing module configured to: receive signaling containing information about a central air-core of an overflow pipe of a hydrocyclone where fluid flow is concentrated in an outer annular region of the overflow pipe that is against an inner wall of the overflow pipe during a normal operation of the hydrocyclone; and determine corresponding signaling containing information about a collapse of the central air-core of the overflow pipe of the hydrocyclone during an abnormal operation of the hydrocyclone, based upon the signaling received. The signaling contains information about a fluid flow rate of the fluid flow by detecting a change in the magnitude of a force and/or a moment on the probe.

A Holographic Multiphase Flowmeter permits reconstructing the type, size and distribution of Objects within a Multiphase Medium by analysis of the ultrasonic energy reflected from these Objects. If this Multiphase Medium is flowing through a pipe into which a preferred mode of ultrasonic energy is injected at a Reference location, and the amplitude of reflections from the current multiphase Objects at that location and the time it took after the last transmission for that reflected signal amplitude to arrive at the Receive transducer are recorded, it is possible to determine the velocity of the medium by measuring the travel time taken for these same Objects to arrive at a known distance downstream by correlating the same type of reflection data at this second Correlation location. Analysis of this data permits displaying type and size of the Objects in a graphic image showing their distribution within the liquid in real time.

A technique facilitates evaluation of a fluid, such as a fluid produced from a well. The technique utilizes a modular and mobile system for testing flows of fluid which may comprise mixtures of constituents, and for sampling fluids thereof. The multiphase sampling method includes flowing a multiphase fluid comprising an oil phase and a water phase through a first conduit, the oil phase and water phase at least partially separating in the first conduit, mixing together the oil phase and water phase to form a mixed bulk liquid phase by flowing the multiphase fluid through a flow mixer toward a second conduit downstream the flow mixer, sampling a portion of the mixed bulk liquid phase at location at or within the second conduit, wherein the sampled portion of the mixed bulk liquid phase has a water-to-liquid ratio (WLR) representative of the pre-mixed oil phase and water phase.

A technique facilitates evaluation of a fluid, such as a fluid produced from a well. The technique utilizes a modular and mobile system for testing flows of fluid which may comprise mixtures of constituents, and for sampling fluids thereof. The multiphase sampling method includes flowing a multiphase fluid comprising an oil phase and a water phase through a first conduit, the oil phase and water phase at least partially separating in the first conduit, mixing together the oil phase and water phase to form a mixed bulk liquid phase by flowing the multiphase fluid through a flow mixer toward a second conduit downstream the flow mixer, sampling a portion of the mixed bulk liquid phase at location at or within the second conduit, wherein the sampled portion of the mixed bulk liquid phase has a water-to-liquid ratio (WLR) representative of the pre-mixed oil phase and water phase.

A carbonated water dispenser comprises a carbonator with a water inlet and a carbonated water outlet. A backflow preventer module is fluidically coupled to the water inlet and comprises a check valve and a thermal mass flow meter. The thermal mass flow meter is configured to communicate a first signal based on a measured amount of heat transferred from a heater to a temperature sensor by a flow of a fluid through the backflow preventer module. A shut-off valve is fluidically coupled between the carbonated water outlet and a nozzle. The shut-off valve is configured to allow or prevent fluid flow from the carbonated water outlet to the nozzle base on a control signal. A controller is configured to detect a backflow condition based on the first signal and generate the control signal to configure the shut-off valve to prevent dispensing carbonated water upon detection of the backflow condition.

A system, method, and computer program product for identifying an incorrectly sized utility meter having a measuring system for fluid passing through the utility meter, including monitoring a plurality of utility meters, each utility meter being installed at a utility location, receiving utility meter data, transmitted by at least one utility meter of the plurality of utility meters to a central computer including at least one processor, wherein the utility meter data comprises a measurement of a volumetric amount of fluid passing through the utility meter or other utility meter data for deriving the volumetric amount of fluid passing through the utility meter, identifying the incorrectly sized utility meter by detecting whether a flow rate associated with the volumetric amount of fluid passed through the utility meter is outside of a flow rate range; and providing an interactive interface to report/receive a status associated with the incorrectly sized utility meter.