Abstract: A system, method and apparatus for measuring fluid properties of a fluid flow having four phases, including a fractional measurement device configured to determine respective fractional measurements of each of four phases of fluids flowing in a fluid flow; and a behavioral modeling device configured to determine, based on the respective fractional measurements of each of the four phases of fluids, respective flow rates for each of the four phases of fluids.

Abstract: A system for determining densities and proportions of phases in a multi-phase fluid flow (MFF) that can include an oil phase, a water phase, and a gas phase from a well. The system includes a first density sensor that senses the MFF at locations where the phases of the MFF are often separated, a second density sensor senses the MFF from the output of a phase mixer-homogenizer, and a third density sensor that senses, in real time, the MFF where the gas phase starts to separate or has separated from the liquid phase but where the liquid phases have not separated. The system also includes one or more processors for executing one or more programs to determine a density of the oil phase, a density of the water phase, a density of the gas phase, and proportions of phases including a water cut and a gas volume fraction based on readings from the first, second, and third density sensors.

Abstract: A system for measuring and monitoring the internal liquid within a three phase separator allows a user to accurately and reliably calculate the volumetric flow rate of the liquids exiting the three phase separator. For each liquid inside of the three phase separator, a differential pressure device is attached to where the extension fitting enters its respective liquid. Once a dump valve is actuated, the extension fitting guides its respective liquid out of the three phase separator, and the differential pressure device creates a differential pressure within the respective liquid. A sensor reads the differential pressure through a pair of sensing lines. The sensor relays the differential pressure reading to an RTU flow computer that calculates the volumetric flow rate of the liquid exiting the three phase separator. The calculation is then sent to a SCADA system, which allows the user to observe the volumetric flow rate in real time.

Abstract: An apparatus and method for down hole gas separation from the multiphase fluid flowing in a wellbore or a pipe, for determining the quantities of the individual components of the liquid and the flow rate of the liquid, and for remixing the component parts of the fluid after which the gas volume may be measured, without affecting the flow stream, are described. Acoustic radiation force is employed to separate gas from the liquid, thereby permitting measurements to be separately made for these two components; the liquid (oil/water) composition is determined from ultrasonic resonances; and the gas volume is determined from capacitance measurements. Since the fluid flows around and through the component parts of the apparatus, there is little pressure difference, and no protection is required from high pressure differentials.

Abstract: The multiphase flow detector detects the different fractions of different phases of fluids, i.e., oil, water, and/or gas, flowing through a pipeline or the like. The detector includes a plurality of capacitive and resistive probes extending radially into an oil delivery pipeline. The probes preferably have various different lengths from one another to detect differences in fluid phases at differing distances from the pipe wall as the fluid flows randomly therethrough. The capacitive and resistive probes are preferably evenly spaced from one another in an alternating circumferential array. Two rings or stations of such probes are preferably installed in the pipe to measure the velocity of flow in the pipe, as well as the fluid fractions flowing therethrough. Appropriate algorithms enable a central controller to determine the fraction differences between oil and water and between oil and gas, and therefore to determine the fraction difference between water and gas.

Abstract: The present invention relates to an apparatus and method for measuring the flow-rate of different fluids present in a plurality of distinct multiphase streams (C), in transit, each through a respective main flow pipe (2). The apparatus (1) comprises a measuring unit (3) for each pipe (2). Each measuring unit (3) comprises a sampling device (4). Each measuring unit (3) comprises first and second measuring means (5) of the differential pressure type situated downstream of the respective sampling device (4). The apparatus (1) comprises a phase separator (8) associated with the measuring unit (3). The apparatus (1) comprises selection means (18) interposed between the measuring unit (3) and the separator (8) for putting the latter in communication with one of the sampling devices (4) envisaged.

Abstract: A system and method for optimizing the gas/liquid separation process for a fluid flowing within a pipe is provided, wherein the method includes receiving a fluid flow having a liquid component and a gas component. The method further includes separating the liquid component from the gas component, wherein the liquid component is separated from the gas component via a separator device. The method also includes generating gas component data and liquid component data, wherein the gas component data is responsive to the liquid carry-over into the gas component and wherein the liquid component data is responsive to the gas carry-under into the liquid component. Furthermore, the method includes processing the gas component data and the liquid component data to generate apparatus optimization data.

Abstract: A flow meter apparatus and method are presented for measuring a flow rate of a multiphase fluid mixture comprising at least one gas phase and one liquid phase. The flow meter comprises a pipe section and measurement section through which the mixture flows. The flow meter also comprises a fraction measurement device adapted to estimate a representative fraction of the gas phase and/or liquid phase of the mixture passing at the measurement section. Moreover, the flow meter preferably comprises at least one ultrasonic sensor arranged to estimate a characteristic, such as liquid film thickness or velocity, of a portion of the liquid phase flowing as liquid film along a wall of the pipe section.

Abstract: The multi-phase flow metering system facilitates the measurement of the flow of oil, gas, and/or other materials from one or more producing petroleum wells. The system has an expansion chamber to separate liquid and as phases. The gas rises through a pipe extending from the top of the expansion chamber. Liquids flow from the bottom of the expansion chamber through a generally U-shaped line having a sediment trap therein. Separate metering devices are provided in the gas outflow line and in the liquid line for accurately measuring the flow of each phase, and in the inlet line for measuring temperature, pressure, and flow at that point. The system includes float valves at the inlet to the gas outflow line and at the liquid phase outlet to control flow through the system. The gas outflow line may continue as a separate line, or reconnect to the liquid outflow line.

Abstract: Properties of a multiphase mixture flow are measured in a blind-tee. The measured properties include the permittivity and/or the conductivity of the multiphase mixture flowing through a conduit. The permittivity and/or conductivity are measured at liquid-rich region(s) in a blind-tee section of the conduit and are used to determine properties of a liquid phase of the multiphase fluid flow, including one of the water conductivity, water in liquid ratio and water volume fraction. One or more electromagnetic sensors may be used in the blind-tee to measure the permittivity and/or conductivity. The sensors may be in contact with the multiphase flow or be disposed behind a dielectric window.

Abstract: An apparatus (1) for measuring at least one characteristic value of a multiphase fluid mixture (13) comprises: a pipe section (20) having a main flow path through which the multiphase fluid mixture (13) flows, the main flow path comprising a throat (22) between an upstream part (21) and a downstream part (23) of the main flow path such as to generate a pressure drop between the upstream part (21) and the downstream part (23); a first sensing arrangement (28, 33, 29, 34, 35, 36) to measure a first characteristic value of the multiphase fluid mixture (13) flowing into the main flow path; -a channel (25) being positioned within the wall of the pipe section (20) such as to maintain similar operating conditions as in the main flow path, the channel (25) being coupled to the main flow path by an inlet (24) at the up-stream part (21), or the throat (22), and by an outlet (26) at the downstream part (23), or the throat (22), such that the pressure drop generates an aspiration effect diverting a sample of the multipha

Abstract: An analysis method using an analysis apparatus are described herein. By way of an example, the analysis method includes a first step of driving a pressurizing pump and a pressure-reduction pump, and of filling a liquid from a supply piping in an interior of a resistive body through which a sample passes, a second step of discharging, from a discharging piping, some of the liquid filled in the interior of the resistive body, and of securing a space in the interior of the resistive body for filling the sample, a third step of supplying the sample into the space, a fourth step of causing the sample to travel in the interior of the resistive body, and a fifth step of measuring a travel time of the sample in the interior of the resistive body by using the flow rate sensor.

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 multiphase flow rate measurement device including a gas-liquid separator (100) that includes a container (10) having a top section (11), a bottom section (12) and a hollow body section (13), an inlet section (20) that is provided in the body section (13), a liquid outlet section (21) that is provided in the bottom section (12), a gas outlet section (22) that is provided in the top section (11), an inner pipe (30) that is connected to the top section (11), and a lower end of the inner pipe (30) being open at a position lower than a lower end of the inlet section (20), and a guide plate lower section (42) that is provided on an outer side surface of the inner pipe (30), a space (90) being formed in at least part of an area between a guide plate lower section (42) and the body section (13).

Abstract: The present disclosure provides a flowmeter including a vibrating element configured to be inserted in a measured fluid; a driver circuit to vibrate the vibrating element in its natural frequency of oscillation; one or more additional technology flow meters configured to measure an additional property of the fluid; a data acquisition circuit configured to measure signals effected by the flow of a multi-phase fluid; and a computer suitable to solve non-linear simultaneous equations. The fluid may include gas, oil and/or water. The fluid may also include solids.

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: A method and system is provided for measuring a flow rate of a gas/liquid flow. The method and system for measuring the flow rate include flowing a swirling gas/liquid flow separated into a gas core and a liquid outer layer through a conduit containing a constriction having a reduced conduit cross-section, measuring the differential gas core static pressure between a position upstream of the constriction and a position at the constriction, measuring a further quantity which provides the flow rate of the gas, the flow rate of the liquid, or a correlation between the flow rate of the gas and the flow rate of the liquid, and determining the flow rates of the gas and the liquid from the differential gas core static pressure and said measured further quantity.

Abstract: A magnet module for a nuclear magnetic flow meter including at least one permanent magnet and a jacket. The jacket protects the at least one permanent magnet against peeling of magnet material by mechanical loads when the magnet module is introduced into a magnet receiver of the flow meter, simplifies introduction of the permanent magnets into the magnet receivers by reduced friction between the magnet module and the magnet receivers, and influences the magnetic field which generated by the permanent magnets.

Abstract: Both a flow meter system and method are provided for accurately measuring the percentage amounts of liquid and gas phases in a multiphase flow through a conduit when the liquid phase constitutes a small minority portion (e.g., less than about 20%) of the multiphase flow. The system includes a flow meter that includes a differential pressure sensor connected across a Venturi in the conduit, and a dual energy fraction meter, each of which is operably connected to a digital processor. The system further includes a pump connected to the conduit upstream of the flow meter that introduces at least one pulse of a known quantity of liquid, the pulse being sufficient in volume to temporarily increase the liquid phase by a detectable amount.

Abstract: A method of evaluating a property of a physiological fluid suspension comprises measuring a value of the property of a liquid portion of the physiological fluid suspension via light scattering, and comparing the measured value with a reference value to evaluate the property of the liquid portion of the physiological fluid suspension.

Abstract: In one aspect, a method of estimating fluid flow contribution from each producing zone of multi-zone production well is provided, which method may include: defining a wellhead pressure; determining a first inflow performance relation (IPR1) between pressure and fluid inflow rate at a first producing zone and a second inflow performance relation (IPR2) between pressure and fluid inflow rate at a second producing zone; determining a combined performance relation (IPRc) between pressure and fluid inflow rate at a commingle point; defining an initial fluid flow rate into the well from the first zone and an initial fluid flow rate from the second zone; generating a first fluid lift performance relation (TPR1) between pressure and total fluid flow corresponding to the commingle point using the initial fluid flow rates from the first and second production zones and at least one fluid property; and determining contribution of the fluid from the first zone and the second zone at the commingle point using IPRc and TPR1

Abstract: A method and apparatus for mitigating slug formation in a multiphase fluid stream that is flowing through a conduit wherein the conduit comprises a first portion and a second portion which is upwardly inclined to the first portion and wherein the multiphase fluid stream comprises a gaseous phase and a liquid phase, the method comprising the steps of: (a) determining the pressure in the conduit upstream of a slugging zone; (b) determining the pressure in the conduit downstream of the slugging zone; (c) determining the actual pressure difference across the slugging zone by subtracting the downstream pressure from step (b) from the upstream pressure from step (a); (d) determining the error between a target pressure difference and the actual pressure difference; (e) producing a signal comprising a first component which is proportional to the error and a second component which is proportional to the rate of change of the error over time; and (f) using the signal produced in step (e) to control the position of an a

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: An apparatus for use in determining a plurality of characteristics of a multiphase flow within a pipe is disclosed. In one exemplary embodiment, the apparatus comprises first and second constrictions, a sheltered zone between the first and second constrictions, a sensing device coupled to an interior wall of the pipe, and a sheltered device coupled to the interior wall of the pipe and located within the sheltered zone. A first characteristic of the plurality of characteristics is determinable from data generated by the sensing device. A second characteristic of the plurality of characteristics is determinable from data generated by the sheltered device. In one exemplary embodiment, the first characteristic is a gas fraction, and the sensing device is a plurality of pressure sensors. In another exemplary embodiment, the second characteristic is a phase fraction, and the sheltered device is a plurality of electrical impedance spectroscopy (EIS) electrodes.

Abstract: The mass flow rate of bulk solids in a pneumatic transport system is measured in real time. At least two pressure gauges (P1, P2) are provided in a pipe section of the transport system. The pressure drop ?P between the pressure gauges is determined during a gas-solids flow of air and bulk solids through the pipe section. The suspension density ?sus of the flowing mixture of air and bulk solids is calculated. The bulk solids mass flow rate Ms at a given location along a given length of a pipeline is estimated based at least on the suspension density ?sus of the flowing mixture.

Abstract: At least one physical property of exhaust gas produced by a cylinder of an internal combustion engine may be determined by determining a temperature, TEOC, a pressure, PEOC, and a clearance volume, VEOC, of the cylinder at an end of combustion of an engine cycle, determining a temperature TEVO, a pressure, PEVO, and a clearance volume, VEVO, of the cylinder at an opening of an exhaust valve of the cylinder following the end of combustion of the engine cycle as a function of TEOC, PEOC, and VEOC, determining a value of the at least one physical property of the exhaust gas produced by the cylinder during the engine cycle as a function of TEOC, PEOC, and VEOC, and storing the value of the at least one physical property of the exhaust gas during the engine cycle in memory.

Abstract: Systems and methods are provided that relate to determining the phase compositions of a multiphase fluid flow in a fluid line, including determining a flow velocity parameter which is related to the flow velocity of the fluid flow in the fluid line using a flow sensor and obtaining a vibration signal from the fluid flow using a vibration sensor comprising a target disposed in the fluid flow which vibrates in response to fluid flow in the fluid line. The signal may be analysed to determine an energy parameter which is related to the energy of the vibration signal within a frequency band, and a phase composition parameter, such as a dryness parameter, relating to the phase compositions of the fluid flow is determined using the flow velocity parameter and the energy parameter. An apparatus for determining the phase compositions of a multiphase fluid flow in a fluid line is disclosed.

Abstract: The invention relates to an means and method for monitoring the flow of a fluid. The invention relates to an electromagnetic flow meter and method for measuring the axial velocity profile of a conducting fluid. The conducting fluid may be a conducting single phase fluid or a conducting continuous phase of a multiphase fluid. The conducting fluid may have a uniform flow profile or a non-uniform flow profile. The electromagnetic flow meter and method measure the axial velocity profile of a conducting fluid by dividing the flow cross section into multiple pixels and determining the axial velocity of the conducting fluid in each pixel. Having. derived the axial velocity profile, the electromagnetic flow meter and method may further derive the volumetric flow rate of the conducting fluid. The electromagnetic flow meter and method may be suitable for measuring the axial velocity profile and optionally the volumetric flow rates of each phase of a multiphase fluid.

Abstract: A method of detecting one or more blocked sampling holes in a pipe of an aspirated smoke detector system. The method includes ascertaining the base flow of fluid through a particle detector using a flow sensor; monitoring subsequent flow through the particle detector; comparing the subsequent flow with the base flow; and indicating a fault if the difference between the base flow and the subsequent flow exceeds a predetermined threshold.

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 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: Disclosed is a positive displacement gas-liquid two-phase flowmeter and a multi phase flow rate measurement system, and more specifically to a positive displacement gas-liquid two-phase flowmeter capable of measuring a flow rate of each of a gas and a liquid of a gas-liquid two-phase flow including the liquid and the gas flowing in a pipe line and a multiphase flow rate measurement system that includes the flowmeter.

Abstract: An apparatus for measuring a multiphase fluid stream which flows in a pipe (2) comprising: a measuring unit (11), coaxial to the pipe, consisting of an isokinetic sampling device (1) suitably configured for allowing the equidistribution of the flow at the inlet in n channels (6) having an area A, of which m are sampling channels and a flow restriction (13) both equipped with differential pressure measuring means (12, 14), a phase separator (15), connected to the sampling device, measurers and regulation means downstream of said separator. A method in accordance with said apparatus which comprises: the isokinetic sampling of a portion q of the multiphase flow Q at the inlet, measuring the flowrates of the liquid qL and gas qG of the portion sampled and calculating the liquid and gas flow-rates (QL and Q0) from the sampling sections according to the equations QG=n/tn qG and QL=n/m qL. The method provides isokinetic sampling for portions of flow removed ranging from 5% to 20%.

Abstract: A multi-phase process fluid is passed through a vibratable flowtube. Motion is induced in the vibratable flowtube. A first apparent property of the multi-phase process fluid based on the motion of the vibratable flowtube is determined, and an apparent intermediate value associated with the multi-phase process fluid based on the first apparent property is determined. A corrected intermediate value is determined based on a mapping between the intermediate value and the corrected intermediate value. A phase-specific property of a phase of the multi-phase process fluid is determined based on the corrected intermediate value.

Abstract: A system, method and apparatus for measuring fluid properties of a fluid flow having four phases, including a fractional measurement device configured to determine respective fractional measurements of each of four phases of fluids flowing in a fluid flow; and a behavioral modeling device configured to determine, based on the respective fractional measurements of each of the four phases of fluids, respective flow rates for each of the four phases of fluids.

Abstract: The device for measuring the mass flow of a foaming fluid, in particular of milk during milking, comprises a housing having an inlet and an outlet, and a measuring device for determining the mass flow. The housing is structured such that mixing the foam portion with the liquid portion of the fluid can be achieved. To this end, the inlet runs substantially tangentially into the housing interior.

Abstract: A method and apparatus for determining a volume of a phase of a multiphase fluid flowing in a production tubular is provided. A magnetic field is imparted on the fluid to align nuclei of the multiphase fluid along a direction of the magnetic field. A radio frequency signal is transmitted into the multiphase fluid to excite the nuclei, and a signal is detected from the nuclei responsive to the transmitted radio frequency signal. An amplitude of the detected signal is determined and the volume of the phase flowing in the production tubular is determined using the determined amplitude and an amplitude of a calibration signal.

Abstract: A capacitive sensor for measuring flow parameters of a two-phase flow, a device for measuring phase concentration of a two-phase flow, and a system and method for measuring flow parameters of a two-phase flow is disclosed. In the capacitive sensor, at least one pair of electrodes is twisted by 180° in a common direction into a spiral shape. Edge guard electrodes are twisted in the common direction and are formed between adjacent electrode edges. Problems of non-homogeneous sensitivity distribution of a measuring field and soft field effect can be effectively addressed, thereby allowing reliable and accurate measurement of phase concentration of a two-phase flow. The system for measuring flow parameters of the two-phase flow can output signals with a current of 4˜20 mA to a PLC system or communicate with an industrial process control computer or with a remote control computer system in a operating room.

Abstract: A method and device includes measuring a multiple-phase fluid flowing through a pipe. The inventive method includes the following steps in which: a fluid is illuminated using a first coaxial probe placed in contact with the liquid phase of the fluid, and a first electromagnetic wave is emitted at a high frequency. The admittance at the interface between the first probe and the fluid is measured, and the fractions of at least two constituents of the liquid phase are calculated in order to obtain the effective permittivity (?1) of the phase. The method also includes the following steps in which: the fluid is illuminated using a second coaxial probe and a second electromagnetic wave is emitted at a low frequency. The admittance at the interface between the second probe and the liquid is measured, and the thickness (e) of the liquid is measured. The aforementioned calculation is performed on the basis of the calculated effective permittivity (?1) and the admittance measured by the second probe.

Abstract: Methods and systems are disclosed for interpreting multi-phase fluid flow in a conduit, such as a pipe in a wellbore. The method involves curve fitting holdup data sets and velocity data sets together wherein the second curve comprises a shape mutual to the first curve with an independent gain and an independent offset, and determining flow rates through the pipe.

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: A method for determining a first flow rate of a gas phase and a second flow rate of at least one liquid phase present in a polyphasic fluid circulating in a conduit is presented. The method essentially comprises circulating the polyphasic fluid through the neck of a venturi delimited by the conduit. The method further comprises estimating the first flow rate and the second flow rate by using a measured pressure difference of the fluid through the neck and a property representative of the relative surface occupied by the gas phase relative to a total surface over a cross-section of the neck. The step of estimating the first flow rate and the second flow rate further comprises (a1) calculating an amount representative of the liquid phase present in the gas rich core relative to the total amount of liquid phase in the neck and calculating the first and second flow rate as a function of the amount representative of the liquid phase present in the core calculated during step (a1).

Abstract: A multiphase meter for use in the quantification of the individual phase fractions of a multiphase flow has: a resonant cavity through which, in use, a multiphase fluid flows, a signal generator configured to apply electromagnetic energy at a range of frequencies to the cavity, and an enhancing and/or suppressing facility for enhancing and/or suppressing resonant modes of a signal produced resultant to the application of electromagnetic energy to the cavity.

Abstract: A measurement device is disclosed which includes a structure adapted to be removably coupled to a Christmas tree, a sleeve operatively coupled to the structure and a flowmeter positioned at least partially within the sleeve.

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: An apparatus and method for down hole gas separation from the multiphase fluid flowing in a wellbore or a pipe, for determining the quantities of the individual components of the liquid and the flow rate of the liquid, and for remixing the component parts of the fluid after which the gas volume may be measured, without affecting the flow stream, are described. Acoustic radiation force is employed to separate gas from the liquid, thereby permitting measurements to be separately made for these two components; the liquid (oil/water) composition is determined from ultrasonic resonances; and the gas volume is determined from capacitance measurements. Since the fluid flows around and through the component parts of the apparatus, there is little pressure difference, and no protection is required from high pressure differentials.

Abstract: A device for measuring the physical characteristics of a flow within a pipe is disclosed. In one exemplary embodiment, the device comprises a hollow ring having an outer wall fixably attached to a meter flange that is inserted between two sections of pipe, and an inner wall on which a sensor is mounted to facilitate accurate flow measurements.

Abstract: An apparatus for use in determining a plurality of characteristics of a multiphase flow within a pipe is disclosed. In one exemplary embodiment, the apparatus comprises first and second constrictions, a sheltered zone between the first and second constrictions, a sensing device coupled to an interior wall of the pipe, and a sheltered device coupled to the interior wall of the pipe and located within the sheltered zone. A first characteristic of the plurality of characteristics is determinable from data generated by the sensing device. A second characteristic of the plurality of characteristics is determinable from data generated by the sheltered device. In one exemplary embodiment, the first characteristic is a gas fraction, and the sensing device is a plurality of pressure sensors. In another exemplary embodiment, the second characteristic is a phase fraction, and the sheltered device is a plurality of electrical impedance spectroscopy (EIS) electrodes.

Abstract: The invention relates to a method of determining bed velocity and solids circulation rate in a standpipe experiencing a moving packed bed flow, such as the in the standpipe section of a circulating bed fluidized reactor The method utilizes in-situ measurement of differential pressure over known axial lengths of the standpipe in conjunction with in-situ gas velocity measurement for a novel application of Ergun equations allowing determination of standpipe void fraction and moving packed bed velocity. The method takes advantage of the moving packed bed property of constant void fraction in order to integrate measured parameters into simultaneous solution of Ergun-based equations and conservation of mass equations across multiple sections of the standpipe.

Abstract: An apparatus, method and system providing for calibration and/or control of a liquid dispensing system is disclosed. The hand-held calibration auditing tool includes a flow meter (36-37) with inlets adapted for quick connection to one or more liquid inputs to a liquid dispensing system (10). A sensor (94-95) having a data output of liquid flow information for a liquid input to the dispensing system (10) is operably connected to a controller (12) to receive the liquid flow information for the liquid input. The controller (12) provides a dilution rate and other liquid flow information for a liquid product input to a dispenser.