Abstract: System and methods for analyzing a multiphase production fluid include a fluidic supply and analysis unit configured to transition the fluidic separation chamber to a static state after a complete gaseous phase column and a complete oil phase column are formed within the fluidic separation chamber; communicate with the fluidic separation detector to measure the absolute or relative sizes of the complete gaseous phase column and the complete oil phase column; and calculate an oil/gas volume fraction as a function of the measured sizes of the gaseous phase and oil phase columns in the fluidic separation chamber.

Abstract: The present invention relates to a method and system for measuring characteristics of a multiphase flow from structural vibration signals. In this sense, the objectives of the invention are achieved by means of a method for measuring characteristics of a multiphase flow from structural vibration signals which comprises: obtaining, by means of acceleration sensors (V01, V02, T00) externally fixed to a pipeline, signals based on pipeline internal flow vibration; processing, by means of a processing device, the obtained signals; and determining a dispersion curve fitting coefficient to determine the void fraction of the mixture.

Abstract: A multi-sensor device is disclosed, for monitoring in real time a flowing fluid substance, the device comprises a main body structure having at least one fluid port and fluid passage for receiving a stream of the fluid substance and flowing it through the fluid passage, and one or more openings for establishing fluid communication with the fluid passage, a sensing foil/film having one or more sensor elements, wherein each portion of the sensing foil/film having at least one of the sensor elements is in fluid communication with at least one of the openings, to thereby enable the sensing element to measure at least one property of condition of the fluid and generate sensor data/signals indicative thereof. The main body structure and the sensing assembly attached to it constitute an integrated component configured as an insertable and removable/exchangeable element of the device.

Abstract: The disclosure provides a method for measuring energy of natural gas components. The method may comprise obtaining, at a plurality of time points, the natural gas components at a target position in a natural gas transmission channel to obtain a distribution of the natural gas components in an area that the natural gas energy is to be measured. The method may comprise determining, based on the calorific value of natural gas at the each time point in each subarea of the plurality of subareas, a calorific value distribution function corresponding to the each subarea. The method may comprise determining, based on the calorific value distribution function corresponding to the each subarea, natural gas energy of the each subarea. The method may comprise determining, based on the natural gas energy of the each subarea, the natural gas energy of the area that the natural gas energy is to be measured.

Abstract: A vapor-generating system includes a pump having an inlet and an outlet, the inlet configured to be connected to a liquid storage portion. The system includes a fluid channel fluidly connected to the pump and a fluid sensor. The fluid sensor is configured to determine a presence of liquid vapor-forming substrate in the fluid channel based on measuring an electrical property of the fluid in the fluid channel.

Abstract: Disclosed are a method and a device for measuring a sand content in a miscible phase fluid, the method comprising: flowing of the miscible phase fluid out of an oil and gas well through a pipeline, the miscible phase fluid of the wellhead of the oil and gas well including at least two fluid media; carrying out a measurement with a light quantum of four levels on the miscible phase fluid by a phase separator installed on the pipeline, such that a linear mass of each fluid medium is obtained; calculating a sand content in mass fraction based on the linear mass of all the fluid media, when the fluid media in the miscible phase fluid includes a solid phase sand.

Abstract: A method of determining a mixing state of a medium in a container includes: transmitting a plurality of acoustic signals at least partly through the medium and receiving the plurality of acoustic signals after at least partly traversing the medium; determining at least one propagation value of at least one propagation quantity for each of the plurality of received acoustic signals to provide determined propagation values, each at least one propagation quantity being indicative of an interaction of the acoustic signals with the medium; determining at least one fluctuation value of at least one fluctuation quantity based on the determined propagation values to provide a determined at least one fluctuation value, each at least one fluctuation quantity being indicative of and/or correlating with a variance of the determined propagation values and/or with a state of a mixture; and determining the mixing state of the medium.

Abstract: An object permittivity measurement apparatus according to the present disclosure includes: a light wave distance measurement device configured to measure reciprocating time t of a light wave with which an object is irradiated and that is reflected and returned from the object, and calculate a distance L to the object using the following equation (1), L=ct/2??(1) c: light speed; an electromagnetic wave phase measurement device configured to measure a rotated phase ? of an electromagnetic wave having a frequency f with which the object is irradiated and that is reflected and returned from the object; and a permittivity calculation circuit configured to calculate permittivity ? of a foreign material on an object surface using the following equation (2), ?=4?Lf/c+4?(?)1/2df/c??(2) d: a thickness of the foreign material on the object surface.

Abstract: There is provided a method of estimating flowrate in a pipeline based on acoustic behaviour of the pipe. First acoustic data is measured from the pipeline. A flowrate of the fluid in the pipeline is then estimated. The estimation is based on the first acoustic data and based on a correlation established between second acoustic data and corresponding flowrate data from an experimental pipeline. The correlation is established by a machine learning process (which may include the use of an artificial neural network, such as an autoencoder). The second acoustic data and corresponding flowrate data are used as inputs to the machine learning process.

Abstract: Multiphase flowmeters and related methods are disclosed herein. An example multiphase flowmeter includes a microwave transmitter to transmit a signal through a fluid, a microwave receiver to determine at least one of attenuation or phase shift, a sensor to obtain at least one of pressure, temperature, or differential pressure, an intermediate-output generator to determine intermediate flow parameters, and a flow rate generator to determine a flow rate for respective phases in the fluid, and a model selector to select at least one of a physics model or a machine learning model for determining the intermediate flow parameters or the flow rates, the physics model to determine a first value of the intermediate flow parameters or the flow rates, and, in response to an error not being less than a threshold, the machine learning model to determine a second value of the intermediate flow parameters or the flow rates.

Abstract: Systems and methods for analyzing a multiphase production fluid includes a pipeline, a fluidic measurement chamber, a pressure sensor, a temperature sensor, an actuating unit, and a fluidic control unit. The actuating unit is partially disposed in the fluidic measurement chamber and is movable between an expansion stage in the fluidic measurement chamber and a compression stage in the fluidic measurement chamber. The fluidic control unit is in communication with the fluidic measurement chamber, the pressure sensor, the temperature sensor, and the actuating unit. The fluidic control unit is configured to communicate with the pipeline to supply the multiphase production fluid to the fluidic measurement chamber. The fluidic control unit is further configured to communicate with the pressure sensor to detect a first pressure of the multiphase production fluid in the fluidic measurement chamber at the expansion stage.

Abstract: An airflow sensor assembly for an air duct is provided. The airflow sensor assembly includes an air duct having an interior wall and an exterior wall, a high pressure detection device, and a low pressure detection device. The low pressure detection device includes a hollow ring disposed within the interior wall of the air duct. The hollow ring includes an inner periphery portion, an outer periphery portion, and a first set of apertures defined therein. The first set of apertures is spaced around the inner periphery portion of the hollow ring. The airflow sensor assembly further includes a pressure sensor fluidly coupled to the high pressure detection device and the low pressure detection device.

Abstract: System for measuring the composition of a multiphase fluid flow in a pipe, the multiphase flow containing a mixture of gas and liquid. The system comprising a first and a second sensor arrangement, wherein each sensor arrangement is adapted to measuring electrical characteristics (i.e. impedance) of the flow at a predetermined rate. The system also including an analysis unit being adapted to monitor the measured electrical characteristics from said first and second sensor arrangement and to detect occurrences of time periods involving a predetermined relationship between the measured characteristics, and during these periods assuming a liquid rich phase and calculating the composition based on the electrical characteristics.

Abstract: Method and system for well testing under full field production comprising isolating well flow from one of multiple wells and running the well flow through a dedicated test slug suppression and gas removal unit and at least one isolated and dedicated inclined tubular separator for testing.

Abstract: A fan is described, with the aid of which a volume flow and/or a mass flow of a medium moved by the fan (1) can be determined. This fan comprises an electric motor (2) and an impeller (3) driven by the electric motor (2), wherein the impeller (3) moves a gaseous medium in a media flow from an inflow side (5) to an outflow side (7). The fan additionally comprises a pressure sensor system, a speed ascertainment system, and an evaluation unit. The pressure sensor system is designed to ascertain an actual pressure difference (?p*) between a first region (10) and a second region (13), wherein the first region (10) and/or the second region (13) is/are formed in the electric motor (2), wherein a pressure (pA) prevails in the first region (10), which corresponds to a pressure (p1) present on the inflow side, wherein a pressure (pB) prevails in the second region (13), which corresponds to a pressure (p2) present on the outflow side.

Abstract: Embodiments described herein include a system for dynamic real-time water-cut monitoring that includes a plurality of sensors for sensing pressure across a pipe that includes logic that causes the system to determine whether to use a direct approach for determining water-cut. In some embodiments, in response to determining not to use the direct approach, the logic causes the system to determine an initial guess for water-cut, estimate at least one dynamic pressure loss across the distance, estimate at least one potential energy pressure loss across the distance, estimate a value for water-cut from the at least one dynamic pressure loss and the at least one potential energy pressure loss, determine whether the initial guess is within a predetermined threshold of the value for water-cut, and in response to determining that the initial guess is within the predetermined threshold of the value for water-cut, output the value for water-cut.

Abstract: A method of determining an estimated flow rate for at least one phase of a multi-phase fluid flowing from a subsea well; a subsea well; and a system for determining an estimated flow rate for at least one phase of a multi-phase fluid flowing from a subsea well are disclosed.

Abstract: Systems, methods, apparatus, and articles of manufacture are disclosed to measure a multiphase flow. An example system includes a flowmeter including a mixer to homogenize a fluid received at an inlet of the flowmeter, a differential pressure sensor to measure a differential pressure of the fluid across an inlet and an outlet of the mixer, a Doppler probe to transmit a microwave or an ultrasonic wave into the fluid to generate Doppler frequency shift data, and a flowmeter manager to calculate a velocity of the fluid based on the Doppler frequency shift data, and calculate a density of the fluid based on the differential pressure and the velocity.

Abstract: System and methods for analyzing a multiphase production fluid, calculating production fluid phase flow rates, and calculating an oil/gas and oil/gas/water volume fractions of the multiphase production fluid, are provided. Contemplated systems and method may utilize fluidic piping, a production fluid supply valve, a fluidic separation chamber, an inert gas exhaust valve, a separation chamber pressure sensor, a fluidic separation detector, and a fluidic supply and analysis unit.

Abstract: System and methods for analyzing a multiphase production fluid include a fluidic supply and analysis unit configured to transition the fluidic separation chamber to a static state after a complete gaseous phase column and a complete oil phase column are formed within the fluidic separation chamber; communicate with the fluidic separation detector to measure the absolute or relative sizes of the complete gaseous phase column and the complete oil phase column; and calculate an oil/gas volume fraction as a function of the measured sizes of the gaseous phase and oil phase columns in the fluidic separation chamber.

Abstract: Multiphase flowmeters and related methods are disclosed herein. An example apparatus includes a flowmeter and a fluid conduit to provide a flow path for a fluid relative to the flowmeter. The example apparatus includes a sensor coupled to the fluid conduit to generate data indicative of at least one of a presence, an absence, or a mass flow rate of solids in the fluid during flow of the fluid through the fluid conduit. The example apparatus includes a processor. The sensor is to be communicatively coupled to the processor. The processor is to selectively determine flow rates for one or more phases of the fluid based on data generated by the flowmeter and a first algorithmic mode or a second algorithmic mode selected based on the sensor data.

Abstract: Disclosed is a measurement pickup for determining the mass flow rate of a liquid comprising: at least one measurement tube for carrying the liquid having an inlet-side end section and an outlet-side end section; a support body on which the measurement tube is mounted an exciter for exciting vibrations of the measurement tube; at least one vibration sensor for detecting vibrations of the measurement tube; an operating and evaluation circuit for driving the exciter, for receiving the signals of the vibration sensor, and for ascertaining a measured value representing the mass flow rate. The operating and evaluation circuit comprises an adaptive low-pass filter for filtering the sequence of measured values representing the mass flow rate, wherein the low-pass filter has at least one filter parameter dependent on at least one adaptive controlled variable that, for its part, is dependent on the gas content of the test medium.

Abstract: An experimental method for determining flow patterns in vertical wellbore of gas wells at high-pressure conditions, which falls within the technical field of deliquification for gas reservoirs. The method comprises: collecting target block parameters; Developing physical simulation experiment to measure the liquid holdup of vertical wellbore; Constructing similarity dimension number to characterize gas density and change with liquid holdup to represent flow similarity of different gas velocities at different pressures; Utilizing equal liquid holdup to represent flow similarity, fitting similarity dimension coefficient, normalizing flow under different pressure conditions to same similarity dimension number, realizing coincidence of change cure of liquid holdup of normal pressure and medium pressure with similarity dimension number.

Abstract: A controller for an economizer that provides outdoor air to a conditioned space. The controller includes an error calculator configured determine an indoor air quality (IAQ) setpoint error based on an actual IAQ and an IAQ setpoint, an outdoor air flow (OAF) setpoint adjuster configured to determine an adjusted OAF setpoint based on at least one of the IAQ setpoint error, an initial OAF setpoint, and an OAF setpoint upper limit, and a proportional variable deadband controller (PVDC) configured to adjust an operational deadband of the economizer and adjust an operation of at least one of an actuator and a damper of the economizer to achieve the adjusted OAF based on at least one of an actual OAF and the adjusted OAF setpoint. Achieving the adjusted OAF drives the actual IAQ to the IAQ setpoint.

Abstract: A system and a method for measuring a void fraction of an inside of a heat conduction member are provided. The system is used to measure the heat conduction member and includes: a heating device configured as a heat source to heat an evaporation end of the heat conduction member; a cooling device configured for cooling a condensation end of the heat conduction member; at least one pair of electrode pads respectively attached to two opposite surfaces of the heat conduction member; and an LCR meter electrically connected to the at least one pair of the electrode pads for measuring impedances of the heat conduction member. Each of the impedances is converted into the void fraction that corresponds to a measured position of the heat conduction member.

Abstract: Disclosed is a method and a device for detecting a non-condensable portion of a medium, which has at least one condensable portion and is present at least partially in gaseous form, wherein in a first method step a temperature measuring device measures a temperature of the medium and a pressure measuring device measures a pressure of the medium, wherein in a second method step a ratio of the pressure to temperature is formed by means of an electronic measuring/operating circuit and this ratio is compared with a desired ratio of a desired pressure and a desired temperature, and wherein in a third method step the electronic measuring/operating circuit outputs a report in case of a minimum deviation of the ratio from the desired ratio.

Abstract: A system and method for transporting cool fresh outside air into an occupied quarters which has an interface member, input connectors, output connectors, switches, and a microcontroller controllably coupled to the plurality of switches. When the thermostat controller system is operating during a heating period, the switches are closed by the microcontroller such that the thermostat controller system controls the operation of the remote air-handling unit that heats air provided to an occupied quarters. When the thermostat controller system is operating during a cooling period, the switches are opened by the microcontroller such that the thermostat controller system no longer controls the operation of the remote air-handling unit when a temperature of outside air is at least less than a cooling set point. The microcontroller operates a remote fan to draw the outside air into the occupied quarters when the outdoor air temperature is less than the cooling set point.

Abstract: A method and system may be used to measure the fluid flow rate of fluid in a pipeline. In the method and system, a signal may be transmitted by a transducer into the pipeline. The signal may be reflected by the contents of the pipeline and received by a receive transducer. Operations may be performed on the received signal to determine the fluid flow rate.

Abstract: The present invention provides a connector (18) for use in a beverage dispense system (1), the connector (18) defining a conduit for connecting a beverage line (2) to a beverage supply (4). The connector (18) comprises an electrical sensor (21) (e.g. a capacitive sensor) for measuring an electrical parameter of a beverage within the connector conduit. The electrical parameter and/or changes in the electrical parameter can be used to detect bubbles in the beverage and/or identify the type/brand of beverage.

Abstract: Vibratory meters (5), and methods for their use measuring a fluid are provided. Each vibratory meter includes a multichannel flow tube (300) comprising two or more fluid channels (302), a pickoff (170), a driver (180), and meter electronics (20) configured to apply a drive signal to the driver at a drive frequency ?, and measure a deflection of the multichannel flow tube with the pickoff. In examples, at least one fluid channel has an effective diameter that is related to velocity of sound and drive velocity. In further examples, the driver may apply a drive signal to the driver having a drive frequency proportional to the velocity of sound and effective diameter.

Abstract: Methods for noninvasive determination of acoustical properties of flowing in pipes having a large ratio (>10) of pipe diameter to wall thickness, and in highly attenuating fluids are described. When vibrations are excited on the outer surface of the wall of a pipe, the resulting vibrations propagate directly through the wall in a normal direction and through the pipe wall as guided waves, appearing on the opposite side of the pipe. This dual path propagation through pipes, where guided waves take the circumferential path in the wall of the pipe and may interfere with the time of-flight measurement obtained from the direct path through the fluid, is at least in part resolved by subtracting the signal from the guided wave from the combined signal, thereby permitting improved observation of the direct path propagation through the fluid.

Abstract: A method for determining an estimated flow rate of fluid flow in a pump comprises: obtaining measurements of the pressure and temperature of fluid at the intake to the pump, the pressure and temperature of the fluid at the discharge from the pump, and the electrical power supplied to the pump; determining values representing either the density of the fluid and the specific heat capacity of the fluid, or the specific fluid enthalpy based on measurements and/or historical data; and calculating an estimated efficiency of the pump and an estimated flow rate of the fluid based on the measured electrical power, the measured temperatures, the measured pressures, the determined value for density and the determined value for specific heat capacity or the determined value for specific fluid enthalpy.

Abstract: A fluid metering system includes a first and a second fluidic pipe section disposed in parallel between a fluidic pipe inlet and outlet. The first fluidic pipe section includes a first flow control device and a first flow metering device each connected in fluidic series. The second fluidic pipe section includes a second flow metering device connected in fluidic series. The fluidic pipe inlet and the fluidic pipe outlet have the same cross-sectional area and/or flow rate capacity. The first fluidic pipe section has an equal or smaller cross-sectional area and/or flow rate capacity in comparison to the fluidic pipe inlet and outlet. The second fluidic pipe section has a smaller cross-sectional area and/or flow rate capacity in comparison to the cross-sectional area and/or flow rate capacity of the first fluidic pipe section. Alternatively, the second fluidic pipe section may include a second flow control device connected in fluidic series.

Abstract: A method of electronically deriving a conclusion of a condition of slurry flow in a non-vertical conduit having a conduit wall and which contains a slurry to flow or flowing along the conduit is provided.

Abstract: An apparatus for testing of downhole multiphase fluid handling systems used in oil and gas production allows test personnel to visually observe the testing. The apparatus is constructed from housings and/or casings made partly or entirely of a see-through material. The see-through material allows for unaided visual observation of the flow regime of the fluid flowing through fluid handling equipment. This eliminates most all of the assumptions that typically need to be made about how well the equipment operates. The ability to clearly observe the flow regimes unassisted allows for accurate study of individual equipment effects, vortices interactions and formation, the effects of different velocities of fluid flow, the optimization of flow paths, remixing and flow regimes external of a system, slug creation, and other parameters known to those skilled in the art.

Abstract: A method and system for separating oil well substances by using a separator system comprising inclined tubular oil and water separators for separating the respective fluid components mixed in fluids from oil wells, combined with providing a liquid lock upstream the inclined tubular oil and water separators, as well as establishing and maintaining water-wetted entrance to the inclined tubular oil and water separators.

Abstract: Systems and methods include a system for processing health information for multiphase flow meters (MPFMs) of different types and at one or more different locations. Multiphase flow meter (MPFM) readings of different MPFM types are received in real-time from MPFMs at different locations. For each MPFM, an MPFM health rule that corresponds to the MPFM readings is determined using the MPFM readings and logic of MPFM health rules. A recommendation is determined for each MPFM based on the MPFM health rule. A health status and an alarm priority are determined for each MPFM using the MPFM readings and the logic of MPFM health rules. A dashboard is presented to a user that includes, for each MPFM, the MPFM readings, the recommendation, the health status, and the alarm priority.

Abstract: Various embodiments of the present technology may provide methods and apparatus for water detection using a capacitive sensor. A door handle apparatus may include a first sensor and a second sensor positioned to detect water flowing across the sensors. Each sensor may comprise a first electrode, a second electrode, wherein each sensor operates independently.

Abstract: A flow meter well tool includes a volumetric well flow meter to be positioned in a wellbore. The volumetric well flow meter includes a hollow cylindrical tubing to be positioned in the wellbore. The tubing splits well fluid through the wellbore into an internal fluid through the volumetric well flow meter and an external fluid through an annulus between the wellbore and the volumetric well flow meter. The hollow cylindrical tubing includes an internal portion, where an internal cross-sectional area of the internal portion is less than an internal cross-sectional area of the hollow cylindrical tubing.

Abstract: Apparatus and methods for the measurement of gas volume fraction of produced oil are described. A first method measures the response of a pipe containing the produced oil excited by a source of vibration in the form of an acoustic frequency chirp containing a linearly varying range of frequencies in the tens of kilohertz range encompassing at least one resonant mode of the pipe. As the gas volume fraction increases, the location of the peak maximum of the measured frequency spectrum responsive to the excitation increases in frequency, and the height of the peak maximum increases, thereby permitting a linear calibration curve to be obtained. A second method measures the response of a pipe containing the produced oil to excitation by a continuous source of vibration having a chosen frequency above those which excite flexural vibrations in the pipe and simultaneously excite acoustic waves in the fluid contained in the pipe, known as the coincidence frequency.

Abstract: A downhole tool for measuring flow properties of a multiphase fluid flow at a location within a subterranean borehole includes at least one ultrasonic probe with a transducer unit having an ultrasound transmission/receiving surface which, in use, interfaces with the multiphase fluid flow. At the surface, the transducer unit transmits ultrasonic acoustic waves into the multiphase fluid flow and receives reflections of the acoustic waves from the multiphase fluid flow. At least one piezoelectric element of the transducer unit produces the acoustic waves. The transducer unit focuses the transmitted acoustic waves into a focus volume in the multiphase fluid flow, which focus volume contains a position of maximum intensity of the transmitted acoustic waves that is spaced a distance of 50 mm or less from the surface. An electronic controller operates the transducer unit, and a signal processor measures properties of the fluid flow from the received reflected acoustic waves.

Abstract: Embodiments of the present disclosure provide an interrogation device that is operable to apply one or more source signals to one or more coils surrounding a volume, where a material is disposed within the volume. Each of the one or more source signals may excite one of the one or more coils, and the behavior of each the one or more coils responsive to the exciting may be monitored. One or more parameters may be determined based on the behavior of each the one or more coils, and the one or more parameters may be utilized to generate a signature for the material within the volume. The signature may be compared to one or more signatures of known materials to identify the material within the volume.

Abstract: A multiphase flow measurement insert for insertion within a pipe includes a first, upstream isolation disc sized and shaped so as to make a fluid tight seal with the interior surface of the pipe. A second, downstream isolation disc is also sized and shaped to make a fluid tight seal with the interior surface of the pipe. The first isolation disc includes a first orifice and the second isolation disc includes a second orifice. The lower edge of the first orifice is positioned vertically higher in the first isolation disc than the lower edge of the second orifice in the second isolation disc. A measurement vessel extends from the first orifice to the second orifice forming a flow channel that is downwardly sloping when the multiphase flow measurement insert is in its operational orientation.

Abstract: The present invention provides a system and method for multi-phase flow decomposition using electrical capacitance imaging techniques. The present invention provides a system and method to obtain permittivity distributions at a plurality of frequency markers using volume tomography image reconstruction to determine volume fraction of each phase and to produce images of the volume fraction for each phase.

Abstract: A water cut measurement tool includes an elongated tubular section configured to flow a multiphase fluid including water and hydrocarbons. The elongated tubular section includes two portions. A first portion has a first diameter. A second portion is axially coupled to the first portion and has a second diameter less than the first diameter. The second portion can receive the multiphase fluid from the first portion. A first electrode is attached to an inner wall of the second portion. A second electrode is attached to the inner wall of the second portion and is positioned diametrically opposite to the first electrode. The two electrodes are configured to measure an impedance of the multiphase fluid flowed through the second portion responsive to a current flowed from the first electrode to the second electrode, and provide the impedance as an output.

Abstract: A method of characterizing gas flow within a housing includes: positioning one or more gas flow sensors in the housing; introducing a gas flow into the housing; using the one or more gas flow sensors to generate two or more gas flow measurements at spaced-apart locations within the housing; and recording the two or more measurements to create a gas flow map.

Abstract: A method for operating a vibratory flowmeter (5) is provided. The method includes placing a process fluid in the vibratory meter (5) and measuring entrained gas in the process fluid. A measurement confidence level is determined for at least one operating variable.

Abstract: An apparatus, system, and method for use in determining at least one property of a flowing multiphase fluid involves comparing an initial signal and a pair of local reference signals with a set of flow characteristics extracted from reference sensor feature maps wherein the signals are related to the flow of the multiphase fluid as it passes through a flow passage which is continuously monitored, adjusted, and calibrated. Based upon the comparison, a decision is made to either resume monitoring of the flowing multiphase fluid by using a pair of local reference signals which are closely positioned and defined, or to adjust the flow passage area significantly in order to improve metering flow conditions. The invention is best suited for determining transport flow velocity and gas void fraction or relative proportions of the gas phase and the liquid phase within the multiphase fluid which subsequently can be used to quantify gas and liquid flowrates.

Abstract: The present disclosure relates to systems and methods for measuring oil/water content in oil-water mixtures, regardless of the salinity of the mixture. The oil content is measured using a dielectric sensor. It is determined whether the oil content is above or below a threshold. If the oil content is above the threshold, the oil content is reported using the measurement from the dielectric sensor. If the oil content is below the threshold, the oil content is reported using the measurement from the eddy current sensor.

Abstract: The present invention refers to a method for the isokinetic sampling of liquids and gases present in streams having many fluid phases, and to an apparatus suitable for achieving it. The method and apparatus have application in particular in the field of oil extraction, wherein, after the extraction of liquid and gaseous hydrocarbons possibly accompanied by water and suspended solids, it is necessary to know the composition of the mixture extracted and also the flow rate of the single phases.