Abstract: A method for monitoring and/or measuring an, at least at times, two-phase medium flowing in a pipeline, and having a first phase, especially a gaseous first phase, with a first density and a second phase, especially a liquid second phase, having a second density different from the first density. The method is performed with a vortex flow measuring device, which has at least one measuring tube inserted into the pipeline, a bluff body and a vortex sensor. In such case, the vortex sensor includes a sensitive section that responds to pressure fluctuations, and that is arranged at least partially adjoining the wall of the measuring tube.

Abstract: A method for determining the flow rates of a fluid comprising a multi-component mixture of a gas and at least one liquid in a pipe, the method comprising the following steps: a. the permittivity of the multi-component mixture is determined based on an electromagnetic measurement, b. a statistical parameter related to the electromagnetic measurement is calculated, c. the density of the multi-component is determined, d. the temperature and pressure are obtained, e. based on the knowledge of densities and dielectric constants of the components of the fluid mixture, and the result from the above steps a-c, the water fraction of the multi-component mixture is calculated, characterized by a method for determining the liquid fraction and flow rates of the multi-component mixture where f. the liquid fraction is calculated based on the statistical parameter from step b and the calculated water fraction from step e using an empirical derived curve, g. the velocity of the multi-component mixture is derived, and h.

Abstract: A flow rate measuring method for a multiphase fluid mixture flowing into a line is provided. The method comprises the steps of passing the fluid mixture through a Venturi tube having a pressure drop, measuring a differential pressure across the Venturi tube and a line pressure of the fluid mixture, measuring by a second measuring device, measured parameter(s) of the fluid mixture correlated to first and second phase relative quantities, determining estimated parameter(s) of the fluid mixture correlated to the first and second phase relative quantities based on the measured parameter and an extrapolating scheme, determining phase flow rate(s) based on the differential pressure, the line pressure and the measured parameter(s) of the fluid mixture, and determining flow rate(s) based on the differential pressure, the line pressure of the fluid mixture and the estimated parameter(s) of the fluid mixture.

Abstract: A process fluid flow system is provided having an input, an output, and a plurality of fluid circuits disposed between the input and output. At least one valve is disposed to selectably cause process fluid to flow through either a first circuit of the plurality of circuits, or a second circuit of the plurality of circuits. Process fluid flows through the first circuit during normal production, and through the second circuit during process fluid sequestration. A process fluid flow measurement device is operably interposed between the input and output and configured to measure total flow through the system. A separator is disposed in the second circuit and is arranged to allow the process fluid to separate gravitationally over time into immiscible components of the process fluid, the separator having a known internal volume. A guided wave radar level measurement device is preferably disposed to measure heights of interfaces within the separator.

Abstract: In an aspiration flow measurement system, a flow channel is provided for receiving an aspiration fluid flow therethrough. The flow measurement system further includes an aspiration flow measurement chamber and a flow sensor that is configured to generate a raw signal indicative of the rate of fluid flow through the flow channel. A control system is configured to monitor the signals indicating the flow through the flow measurement chamber, and to determine when a value of the raw signal is indicative of a disruption caused by the presence of an air bubble, wherein the control system generates a filtered signal of the flow rate that is exclusive of any signal values that are indicative of a disruption.

Abstract: A device is provided for determining a mass flow of a first gas flowing in a flowing channel of an internal combustion engine of a motor vehicle. The device includes: sound transducers arranged at respective ends of a measuring path for providing sound signals, a temperature sensor for determining a temperature of an overall mass flowing in the flow channel, and an evaluation unit arranged downstream of the sound transducers. The evaluation unit is capable of carrying out the following: determining a flow rate of the overall mass and a speed of sound based on delay times of the sound signals, determining an overall mass flow based on the flow rate, the temperature, and a pressure of the overall mass in the flowing channel, ascertaining a proportion of a second gas flowing in the flow channel at a temperature above 10° C. and based on the speed of sound and the temperature, and correcting the overall mass flow to obtain the mass flow of the first gas.

Abstract: This invention relates to a method of measuring mass flow of a first gas component in a gas consisting of one or more known gas components. Typically such methods assume that certain parameters were constant, such as the gas composition, pressure and/or temperature, and likewise the heat capacity, density, etc., of the gas were presumed to be such that they could be determined to have a constant value. However, it has been found that the determination of the mass flow is associated with a comparatively high degree of measurement uncertainty, when it is assumed that the parameters are constant. The core of the invention relies on this discovery and on a method wherein all of the gas parameters that are used in the determination of the mass flow of the first gas component and that may vary considerably as a function of the gas composition, pressure and/or temperature are determined continually.

Abstract: A device for measuring rates in individual phases of a multiphase flow, such as in flow of hydrocarbon fluid through a pipe line, comprising a venturi having, seen in the flow direction thereof, a first inlet portion with deceasing cross-section, a second intermediate portion with mainly uniform cross-section, and a third outlet portion with increasing cross-section, and being situated within the pipe line. According to the present invention, the venturi is provided with a number of sensors, and the sensors are arranged in mutual distance at different cross-section areas along at least the first of the three portion of the venturi as thereby being able to determine a pressure profile along the venturi as a base for estimating rates for actual rates of the flow.

Abstract: An in-line flow separator (1) comprises an uphill section (2) of pipeline which, in use, carries a gravitationally stratified flow of a first liquid (3) and a second denser liquid (4). The second liquid (4) forms a sump (5) extending uphill from the foot of the uphill section (2), and an interface between the first and second liquids on the uphill section is inclined from the horizontal. An extraction port (6) in the pipeline extracts the second liquid from the sump.

Abstract: Various methods of metering a multi-phase composition in a pipe using patch antenna(s), that operate in a radio or microwave frequency range, are disclosed including locating and then exciting the patch antenna(s) over a range of frequencies; measuring transmitted and reflected signals over time; estimating a shift in a resonant frequency from a baseline resonant frequency; then calculating a permittivity of the composition, based on the shift; and calculating a phase composition of the multi-phase composition. The present invention has been described in terms of specific embodiment(s), and it is recognized that equivalents, alternatives, and modifications, aside from those expressly stated, are possible and within the scope of the appending claims.

Abstract: The present invention relates to a flow rate sensor 52 which causes a gas 80 included in a liquid 81 to travel in a piping 56, and which measures a flow speed of a sample by detecting the gas 80. The flow rate sensor 52 is configured to maintain a contact area of the gas with respect to the piping 56 at constant or at substantially constant.

Abstract: Meter electronics (20) for determining a liquid flow fraction in a gas flow material flowing through a flow meter (5) is provided according to an embodiment of the invention. The meter electronics (20) includes an interface (201) for receiving a first sensor signal and a second sensor signal from the flow meter (5) and a processing system (203) in communication with the interface (201). The processing system (203) is configured to receive the first and second sensor signals from the interface (201), determine a substantially instantaneous flow stream density of the gas flow material using the first sensor signal and the second sensor signal, compare the substantially instantaneous flow stream density to at least one of a predetermined gas density that is representative of a gas flow fraction of the gas flow material and a predetermined liquid density that is representative of a liquid flow fraction, and determine the liquid flow fraction from the comparison.

Abstract: The in-line sampler separator utilizes an improved method of measuring the gas, oil and water components in a fuel material mixture being processed at high pressure in a processing system. A sampling loop obtains mixture samples to be collected in a sampler. The sampler releases the collected sample to a separator tank when a certain volume has been reached. The tank operates at or below a pressure that allows the gas component to be released in gaseous form. The oil and water components separate within the tank, and their respective volumes are determined.

Abstract: This invention relates to a cyclonic sensor chamber and a multiphase composition meter employing a sensor array compatible with such a sensor chamber. The sensor geometry imparts centripetal force to radially stratify a multiphase composition, and permits radial measurement of the entire flow composition in a linearly independent manner at different regions within the sensor. An appropriate array of sensors may be chosen to measure the properties of the composition from the group of testable composition properties consisting of speed of propagation of ultrasonic waves; amplitude modulation or attenuation of ultrasonic waves, X-rays, gamma rays, microwaves, infrared, visible and ultraviolet light; phase modulation or standing wave resonance of ultrasonic waves and microwaves; spin states of nuclei of nuclear magnetic resonance; and complex impedance, capacitance, inductance, mutual inductance, conductance, frequency response and phase delay. The sensor may be used to measure the water cut in an oil-well flow.

Abstract: A multiphase flowmeter, and a method of analyzing and measuring multiphase flow is described. The body of the multiphase flowmeter consists of the following components. It has a straight flow pipe in which two orifice plates a lodged near the extremities. At each of these two locations, a pressure differential transmitter measures the pressure drop that occurs as the fluid passes through the orifice plates. Along the length between the orifice plates, an ultrasound Doppler sensor measures the volume flow rate of the multiphase fluid, a pressure transmitter measures the in-pipe pressure and a temperature sensor measures the temperature. From the signals obtained from the above sensors, an overall analysis of the multiphase fluid flow is performed providing a complete set of flow measurement data for the mixture and for each of the three phases consisting of oil, water and gas.

Abstract: A method and system for measuring a property of a multiphase fluid comprising a mixture of at least an oil phase and a water phase travelling through a conduit, the method comprising measuring the thickness of the liquid mixture, measuring the permittivity of a portion of the multiphase fluid, combining the thickness measurement with the permittivity measurement to obtain a derived value for the permittivity of the liquid mixture, and using at least the derived permittivity of the liquid mixture and a relationship between a single phase liquid property and a corresponding two-phase property of the liquid mixture, to obtain a calculated water-to-liquid ratio of the liquid mixture.

Abstract: A method and apparatus for determining a level of stratification of a multiphase fluid flow passing through a pipe is provided. The method includes, and the apparatus is operable to perform, the steps of: 1) determining a flow velocity of the multiphase fluid flow passing through a first radial region of the pipe; 2) determining a flow velocity of a portion of the multiphase fluid flow passing within a second radial region of the pipe, wherein the second radial region is above the first radial region; and 3) comparing the flow velocity from the first radial region and flow velocity from the second radial region to determine information indicative of the stratification of the multiphase fluid flow.

Abstract: A process for determining a fluid flow velocity and then a mass flow rate of a cryogenic fluid in which a Helmholtz resonator is used to detect a presence of a two-phase flow in a conduit. The process first measures a frequency of the fluid flow, then determines a speed of sound of the fluid from the frequency, then measures the temperature of the fluid flow, and from the speed of sound and the temperature determines a quality of the fluid flow (liquid or vapor), and from the frequency and the fluid quality determines a Strouhal Number. The fluid flow velocity is found from an equation relating the frequency and a diameter of the surface area to the Strouhal Number. The mass flow rate is found from the fluid flow velocity and the temperature.

Abstract: The invention relates in a one aspect to a method or apparatus for measuring flow properties of a multiphase fluid stream flowing in a pipeline comprising means for sampling, with a sampling probe, a portion of the fluid stream; for measuring a differential pressure between a first pressure of the fluid stream in the pipeline and a second pressure of the portion of the fluid stream in the sampling probe; for controlling flow rate of the sampled portion, wherein the flow rate of the sampled portion is controlled to provide for nullification of the differential pressure in order to obtain substantially isokinetic sampling of the fluid stream; for measuring properties of the portion of the fluid stream; and for processing the measured properties to determine the flow properties of the multiphase fluid stream flowing in the pipeline, wherein the above elements do not require- or are performed without the determination of the density of fluid in the fluid stream through nuclear radiation methods.

Abstract: Embodiments of the present invention provide for measuring flow properties of multiphase mixtures within a pipe carrying hydrocarbons. Embodiments of the present invention use differential pressure measurements of multiphase mixtures flowing in phase-separated flow regimes to analyze characteristics of a liquid phase of the multiphase mixture. The phase-separated flow regimes may be provided by flowing the multiphase mixture in a substantially horizontal pipeline or swirling the multiphase mixture. The combination of differential measurements with measurements from other sensors, such as ultrasonic sensors, microwave sensors, densitometers and/or the like may provide for multiphase flow measurements, such as flow rates of the different phases or determination of the speed of sound.

Abstract: An apparatus is provided for measuring a flow rate of a two-phase fluid flowing within a conduit including a chamber having at least one transparent wall in fluid communication with the conduit; a high-speed imaging system in visual communication with the at least one transparent wall; means for obtaining a temperature value and a pressure value of the two-phase fluid flowing within the conduit; and means for determining the flow rate of the two-phase fluid by analyzing the images obtained by the high-speed imaging system, and from the temperature value and the pressure value for the two-phase fluid flowing within the conduit. Processes for determining the flow rate of a two-phase fluid flowing within a conduit are also provided.

Abstract: A flow meter for measuring flow rate and flow composition of a process fluid includes a microwave source configured to generate a microwave signal. A probe tip is coupled to the microwave source and in near field proximity to the process fluid. The probe tip is configured to apply the microwave signal to the process fluid. A microwave detector coupled to the probe tip is configured to detect a near field microwave signal from the process fluid in response to the applied microwave signal. Flow calculation circuitry determines flow rate and/or composition of the process fluid as a function of the detected microwave signal.

Abstract: The present invention includes systems, methods and apparatus for detecting whether an acceptable mixture of fluid and water has been delivered by a vending machine. Embodiments of the invention utilize one or more second flow meters located downstream of a mix manifold. The additional flow meter allows the controller of the delivery system or vending machine to monitor and compare the volume of water to the volume of the final mix in order to determine whether an appropriate volume of syrup has or has not been mixed in the dispensed beverage.

Abstract: This disclosure relates in general to methods and systems for measuring multiphase flows in a pipeline using a combination of venturi, microwave and radiation techniques, where the pipeline is configured to transport hydrocarbons. More specifically, but not by way of limitation, certain embodiments of the present invention provide methods and systems in which low activity radiation sources may be used in combination with one or more microwave transmitter-receiver pairs and pressure differential sensors to measure the flow rates and fractions of phases in multiphase flows in a pipeline, such as may be encountered in producing hydrocarbon wells. Additionally, other embodiments of the present invention provide for the arrangement of one or more microwave transmitter-receiver pairs, one or more radiation source-detector pairs and/or one or more pressure sensor ports in the same cross-section of the throat of a venturi to measure multiphase flow in a hydrocarbon transporting pipeline.

Abstract: A flow monitoring system includes a pipe for transporting a fluid therethrough. An optical fiber generally spirals about the pipe along a longitudinal portion having a predetermined length to serve as a single transducer for detecting flow information from the longitudinal portion. A linear polarizer/analyzer circuit communicates with the optical fiber. A light source communicates with the linear polarizer/analyzer circuit and generates a light signal along the optical fiber at a frequency greater than a period of a disturbance to flow past the predetermined length of the transducer. A reflector is disposed along the optical fiber for reflecting the light signal along the optical fiber. An optical detector communicates with the linear polarizer/analyzer circuit. The optical detector determines from the light signal dynamic events along the optical fiber indicative of flow disturbances passing by the transducer.

Abstract: A method, system, apparatus and computer program product for determining values of flow rates of components of a liquid hold up of a gaseous and liquid (water and oil) multiphase flow in an oil well. Including measuring total quantities of flow (Qtot), gas (Qgas) and liquid phase (Qliq) with a multiphase flow meter. Disposing an inlet of a core sampler inside a main pipe of the oil well at a place where a concentration of the liquid phase is greater than an average concentration of the liquid phase in the main pipe, to obtain a derived sample having a greater concentration of oil and water than the average concentration. Measuring quantities of water (Qwater) and oil (Qoil) of the derived sample. And calculating from Qwater, Qoil and Qliq, quantities of water and oil in the flow.

Abstract: In order to extract a part of a three-phase flow from a pipe line, a pair of communication pipes, which are connected to upstream and downstream sides of an orifice provided in the pipe line, and a gas-liquid extraction tank are used. Flowing of a slag flow or the like into the pipe line causes a periodical change in a pressure difference between input and output sides of the orifice. This causes extraction of gas-liquid and discharge mainly of gas to be simultaneously effected in the pair of communication pipes and the gas-liquid extraction tank. Within the gas-liquid extraction tank, the gas-liquid is forcibly shaken horizontally, vertically, etc. for agitating, whereby gas-liquid of high liquid-phase rate remains. Then, the gas is removed from this gas-liquid of high liquid-phase rate to thereby extract mixture liquid, which is accumulated in a liquid storage tank. The mixture liquid flows from the liquid storage tank in an amount required at a Coriolis meter.

Abstract: Multi-phase flow is estimated in a flow meter having a first and a second stage by empirically deriving an algorithm for the water and gas fractions, measuring pressures within the flow meter, and estimating a total mass flow rate based on the measured pressures. A corrected total mass flow rate is calculated using a liquid/gas slip correction technique. The oil fraction can be determined from the corrected total mass flow rate and gas and water fractions.

Abstract: A multiphase flowmeter, and a method of analyzing and measuring multiphase flow is described. The body of the multiphase flowmeter consists of the following components. It has a straight flow pipe in which two orifice plates a lodged near the extremities. At each of these two locations, a pressure differential transmitter measures the pressure drop that occurs as the fluid passes through the orifice plates. Along the length between the orifice plates, an ultrasound Doppler sensor measures the volume flow rate of the multiphase fluid, a pressure transmitter measures the in-pipe pressure and a temperature sensor measures the temperature. From the signals obtained from the above sensors, an overall analysis of the multiphase fluid flow is performed providing a complete set of flow measurement data for the mixture and for each of the three phases consisting of oil, water and gas.

Abstract: A vibratory flow meter (5) for measuring flow characteristics of a three phase flow is provided according to the invention. The vibratory flow meter (5) includes a meter assembly (10) including pickoff sensors (105, 105?) and meter electronics (20) coupled to the pickoff sensors (105, 105?). The meter electronics (20) is configured to receive a vibrational response from the pickoff sensors (105, 105), generate a first density measurement of the three phase flow using a first frequency component of the vibrational response, and generate at least a second density measurement of the three phase flow using at least a second frequency component of the vibrational response. The at least second frequency component is a different frequency than the first frequency component. The meter electronics (20) is further configured to determine one or more flow characteristics from the first density measurement and the at least second density measurement.

Abstract: A method of allocating hydraulic fluid between actuators in a machine accepts a first command to provide a first requested fluid flow to a first actuator, wherein the first actuator is a bounded actuator such as a steering actuator, and a second command to provide a second requested fluid flow to a second actuator. The system adjusts the first and second commands to produce adjusted first and second commands corresponding to adjusted first and second fluid flows, such that the sum of the adjusted first and second fluid flows is less than or equal to a maximum available flow and the adjusted first fluid flow meets or exceeds the lesser of the first requested fluid flow and a threshold curve that is a function of engine speed or other variable.

Abstract: A method of detecting an additional element from a plurality of other elements forming a multiphase flow. The method comprising: measuring an energy spectrum response based on electromagnetic irradiation of the multiphase flow. Determining a fraction concentration of the other elements forming the multiphase flow based on a lower energy peak in the spectrum response and detecting an additional element in the multiphase flow based on measuring a variation of a higher energy peak in the spectrum response. It is also possible to measure the quantity of the additional element and to compensate the fractional concentrations of the respective n-phase measurements.

Abstract: This disclosure relates in general to systems and methods for spot checking flow properties of a multiphase mixture containing one or more hydrocarbons flowing through a pipeline or the like. More specifically, but not by way of limitation, embodiments of the present invention provide systems and methods for creating slug-type flows of isokinetically obtained samples of the multiphase mixture flow. By spot checking the slug-type flow of an isokinetically obtained sample of the multiphase flow, embodiments of the present invention may provide for determining flow properties of gas, oil/condensate and/or water components of the multiphase flow. In certain aspects of the present invention, an active sampling device may be used to enrich one of the phases of the slug-type flow of the sampled multiphase mixture and/or take a representative sample of one of the phases of the slug-type flow of the sampled multiphase mixture.

Abstract: A first property of a process fluid is measured using a differential pressure flowmeter. A second property of the process fluid is measured using a Coriolis flowmeter. A third property of the process fluid is determined based on the measured first property and the measured second property.

Abstract: Systems and methods are described for measuring flow properties of a high gas-cut multiphase mixture flowing in a conduit, such as a wet-gas produced from a hydrocarbon well. In aspects of the present invention, one or more receivers are used to receive Doppler shifted signals resulting from an interaction between a propagating dominant microwave mode developed in the conduit and the high gas-cut multiphase mixture flowing in the conduit. Analysis of the Doppler shift in the received signals may provide for determining the velocity of the gas and/or the liquid phase of the high gas-cut multiphase mixture. In other aspects, analysis of the phase difference of Doppler signals received at the plurality of receivers provides for a determination of the content of the wet-gas, such as the water holdup.

Abstract: Multi-phase flow is estimated in a flow meter having a first and a second stage by empirically deriving an algorithm for the water and gas fractions, measuring pressures within the flow meter, and estimating a total mass flow rate based on the measured pressures. A corrected total mass flow rate is calculated using a liquid/gas slip correction technique. The oil fraction can be determined from the corrected total mass flow rate and gas and water fractions.

Abstract: A Coriolis flowmeter is configured to determine a first property of a multi-phase fluid. A flow model is configured to determine a second property of the multi-phase fluid. A determination system is configured to determine a third property of the multi-phase fluid based, at least in part, on the first property and the second property.

Abstract: Reliably and quickly acting device that can be cheaply employed for monitoring the flow of water vapor, having a water vapor line extending between a switching valve and a cross-section connection, in particular a nozzle, and a temperature sensor monitoring the temperature in the line.

Abstract: The invention relates to a method and device for measuring a multiple-phase fluid flowing through a pipe. The inventive method comprises the following steps in which: a fluid is illuminated using a first coaxial probe (32) placed in contact with the liquid phase (16) of the fluid and a first electromagnetic wave is emitted at a high frequency, the admittance at the interface between the rust probe (32) and the fluid is measured, and the fractions of at least two constituents of the liquid phase (16) are calculated in order to obtain the effective permittivity (?l) of said phase. Said method also includes the following steps in which: the fluid is illuminated using a second coaxial probe (50) and a second electromagnetic wave is emitted at a low frequency, the admittance at the interface between the second probe (50) and the liquid is measured, and the thickness (e) of the liquid is measured.

Abstract: This disclosure relates in general to robust and efficient methods and systems for obtaining a sample of a liquid or gas phase from a multiphase mixture flowing in a pipeline, where the multiphase mixture comprises oil and/or a gaseous hydrocarbon and the pipeline is configured for the transport of the oil and/or gaseous hydrocarbon. In certain aspects of the present invention, after obtaining the sample of the liquid or gas phase of the multiphase mixture, sensing devices, meters, sensor systems or the like may be used to analyze the properties of the collected liquid phase sample.

Abstract: A system for detecting and controlling a slug event in a flow through a pipeline is provided. The system includes multiple sensors configured to indicate one or more parameters of the flow for a slug at multiple locations in the pipeline. The system also includes a controller configured to receive one or more response signals corresponding to at least one of the parameters from the sensors. The system further includes a variable speed drive system electrically coupled to the controller and a compressor pumping fluid in the pipeline such that a ratio of liquid to gas is within an acceptable range, wherein the variable speed drive is configured to receive one or more signals from the controller and further configured to regulate at least one of a translational or a rotational speed or a power of the compressor based upon the signals. The system also includes a display unit coupled to the controller, the display unit configured to output the plurality of signals received from the controller.

Abstract: A system for stabilizing flow in a pipeline is provided. The system includes at least one of an internal supply or an external supply configured to provide fluid into the pipeline such that a ratio of liquid to gas in the flow is within an acceptable range. The system also includes one or more sensors configured to indicate the ratio of liquid to gas in the fluid. The system further includes at least one valve configured to regulate a flow of the fluid from the internal supply or the external supply into the pipeline based upon the ratio indicated by the one or more sensors.

Abstract: The present application is directed to an apparatus and method of managing transport of fluid commodities in a pipeline network. The method includes obtaining operational settings, which include equipment settings and measured parameters, associated with a pipeline network as a fluid commodity is transported through the pipeline network. From the operational settings, a recommendation is generated concurrently with the transport of the fluid commodity through the pipeline network to optimize at least one of the operational settings. The recommendation comprises revised equipment settings associated with equipment disposed along the pipeline network. The equipment settings in the recommendation may be based on empirical data from previous experience with the transport of fluid commodities through the pipeline network and/or based on theoretical data from modeling of the transport of the fluid commodity through the pipeline network.

Abstract: A method and corresponding system is provided for determining fluid properties of a two phase fluid flowing through various portions of a wellbore. Specifically, the method and corresponding system determines fluid properties (e.g. enthalpy flux) of the two phase fluid flowing upstream of the injector portion of the wellbore as well as fluid properties (e.g., mass flow rate and enthalpy flux) of the two phase fluid at various measurement locations along the injector.

Abstract: An apparatus (and corresponding method) for characterizing the fluid properties of a two phase fluid includes a restriction element (e.g., orifice plate or nozzle) along the flow path of the two phase fluid. At least one temperature sensor measures temperature of the two phase fluid flowing through the restriction element. A pressure sensor measures the pressure downstream of the restriction element. Time-of-flight measurements of pulses passing through the two phase fluid are made. The speed of sound within the two phase fluid is calculated from the time-of-flight measurements. At least one fluid property (e.g., a vapor phase fraction) of the two phase fluid is calculated from the measured pressure, the measured temperature, and the calculated speed of sound.

Abstract: An apparatus and method for determining the water cut value of a multiphase fluid flowing within a pipe is provided. The device includes a sequestering structure disposed within the pipe, a transmitting device, a receiving device, and a processing device. The sequestering structure at least partially defines a sensing passage within the pipe, which passage has a gap extending substantially normal to a direction of fluid flow within the pipe. The sensing passage is oriented to sequester an amount of a liquid component of the multi-phase fluid sufficient to form a continuous liquid body extending across the gap of the sensing passage. The transmitting device is operable to transmit a signal through the liquid across the gap of the sensing passage. The receiving device is operable to receive the signal after it has traversed the liquid within the sensing passage, and create sensor data.

Abstract: Multi-phase flow is estimated in a flow meter having a first and a second stage by empirically deriving an algorithm for the water and gas fractions, measuring pressures within the flow meter, and estimating a total mass flow rate based on the measured pressures. A corrected total mass flow rate is calculated using a liquid/gas slip correction technique. The oil fraction can be determined from the corrected total mass flow rate and gas and water fractions.

Abstract: A Coriolis flowmeter is configured to determine a first property of a multi-phase fluid. A flow model is configured to determine a second property of the multi-phase fluid. A determination system is configured to determine a third property of the multi-phase fluid based, at least in part, on the first property and the second property.

Abstract: An apparatus (and corresponding method) for characterizing the fluid properties of a two phase fluid includes a restriction element (e.g., orifice plate or nozzle) along the flow path of the two phase fluid. At least one temperature sensor measures temperature of the two phase fluid flowing through the restriction element. A pressure sensor measures the pressure downstream of the restriction element. Time-of-flight measurements of pulses passing through the two phase fluid are made. The speed of sound within the two phase fluid is calculated from the time-of-flight measurements. At least one fluid property (e.g., a vapor phase fraction) of the two phase fluid is calculated from the measured pressure, the measured temperature, and the calculated speed of sound.

Abstract: A self-checking analyzer system is provided according to an embodiment of this disclosure. The analyzer system includes a pipeline for receiving a multi-phase fluid flow and a first measuring device configured to provide a first frequency response corresponding to the multi-phase fluid flow. The analyzer system also includes a second measuring device differing in frequency response from the first measuring device and configured to provide a second frequency response corresponding to the multi-phase fluid flow. The analyzer system is configured to validate the first frequency response using the second frequency response.