WO1993014382A1 - Device and method for measuring multi phase flow - Google Patents

Device and method for measuring multi phase flow Download PDF

Info

Publication number
WO1993014382A1
WO1993014382A1 PCT/NO1993/000001 NO9300001W WO9314382A1 WO 1993014382 A1 WO1993014382 A1 WO 1993014382A1 NO 9300001 W NO9300001 W NO 9300001W WO 9314382 A1 WO9314382 A1 WO 9314382A1
Authority
WO
Grant status
Application
Patent type
Prior art keywords
pressure
medium
generator
gas
flow
Prior art date
Application number
PCT/NO1993/000001
Other languages
French (fr)
Inventor
Jon Steinar Gudmundsson
Original Assignee
Jon Steinar Gudmundsson
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date

Links

Classifications

    • GPHYSICS
    • G01MEASURING; TESTING
    • G01PMEASURING LINEAR OR ANGULAR SPEED, ACCELERATION, DECELERATION, OR SHOCK; INDICATING PRESENCE, ABSENCE, OR DIRECTION, OF MOVEMENT
    • G01P5/00Measuring speed of fluids, e.g. of air stream; Measuring speed of bodies relative to fluids, e.g. of ship, of aircraft
    • G01P5/18Measuring speed of fluids, e.g. of air stream; Measuring speed of bodies relative to fluids, e.g. of ship, of aircraft by measuring the time taken to traverse a fixed distance
    • GPHYSICS
    • G01MEASURING; TESTING
    • G01FMEASURING VOLUME, VOLUME FLOW, MASS FLOW OR LIQUID LEVEL; METERING BY VOLUME
    • G01F1/00Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through the meter in a continuous flow
    • G01F1/66Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through the meter in a continuous flow by measuring frequency, phaseshift, or propagation time of electromagnetic or other waves, e.g. ultrasonic flowmeters
    • GPHYSICS
    • G01MEASURING; TESTING
    • G01FMEASURING VOLUME, VOLUME FLOW, MASS FLOW OR LIQUID LEVEL; METERING BY VOLUME
    • G01F1/00Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through the meter in a continuous flow
    • G01F1/704Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through the meter in a continuous flow using marked regions or existing inhomogeneities within the fluid stream, e.g. statistically occurring variations in a fluid parameter
    • G01F1/708Measuring the time taken to traverse a fixed distance
    • GPHYSICS
    • G01MEASURING; TESTING
    • G01FMEASURING VOLUME, VOLUME FLOW, MASS FLOW OR LIQUID LEVEL; METERING BY VOLUME
    • G01F1/00Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through the meter in a continuous flow
    • G01F1/704Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through the meter in a continuous flow using marked regions or existing inhomogeneities within the fluid stream, e.g. statistically occurring variations in a fluid parameter
    • G01F1/708Measuring the time taken to traverse a fixed distance
    • G01F1/7082Measuring the time taken to traverse a fixed distance using acoustic detecting arrangements
    • GPHYSICS
    • G01MEASURING; TESTING
    • G01FMEASURING VOLUME, VOLUME FLOW, MASS FLOW OR LIQUID LEVEL; METERING BY VOLUME
    • G01F1/00Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through the meter in a continuous flow
    • G01F1/74Devices for measuring flow of a fluid or flow of a fluent solid material in suspension in another fluid
    • GPHYSICS
    • G01MEASURING; TESTING
    • G01NINVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N29/00Investigating or analysing materials by the use of ultrasonic, sonic or infrasonic waves; Visualisation of the interior of objects by transmitting ultrasonic or sonic waves through the object
    • G01N29/02Analysing fluids
    • G01N29/024Analysing fluids by measuring propagation velocity or propagation time of acoustic waves
    • GPHYSICS
    • G01MEASURING; TESTING
    • G01PMEASURING LINEAR OR ANGULAR SPEED, ACCELERATION, DECELERATION, OR SHOCK; INDICATING PRESENCE, ABSENCE, OR DIRECTION, OF MOVEMENT
    • G01P5/00Measuring speed of fluids, e.g. of air stream; Measuring speed of bodies relative to fluids, e.g. of ship, of aircraft
    • G01P5/24Measuring speed of fluids, e.g. of air stream; Measuring speed of bodies relative to fluids, e.g. of ship, of aircraft by measuring the direct influence of the streaming fluid on the properties of a detecting acoustical wave
    • G01P5/245Measuring speed of fluids, e.g. of air stream; Measuring speed of bodies relative to fluids, e.g. of ship, of aircraft by measuring the direct influence of the streaming fluid on the properties of a detecting acoustical wave by measuring transit time of acoustical waves
    • GPHYSICS
    • G01MEASURING; TESTING
    • G01NINVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N2291/00Indexing codes associated with group G01N29/00
    • G01N2291/02Indexing codes associated with the analysed material
    • G01N2291/028Material parameters
    • G01N2291/02818Density, viscosity
    • GPHYSICS
    • G01MEASURING; TESTING
    • G01NINVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N2291/00Indexing codes associated with group G01N29/00
    • G01N2291/02Indexing codes associated with the analysed material
    • G01N2291/028Material parameters
    • G01N2291/02836Flow rate, liquid level
    • GPHYSICS
    • G01MEASURING; TESTING
    • G01NINVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N2291/00Indexing codes associated with group G01N29/00
    • G01N2291/02Indexing codes associated with the analysed material
    • G01N2291/028Material parameters
    • G01N2291/02872Pressure

Abstract

Device and method for measuring flow rate and gas/liquid fraction in pipes and wells, in which the flowing medium consists of several phases, particularly for two-phase systems of the natural gas/oil type. The device is characterized by a pressure pulse generator (36) to generate pressure pulses having a frequency of maximum 100 Hz into the medium, and two or more pressure sensors (33a; 33c), to register the low frequent pressure pulse generated in the pressure pulse generator (36), in which at least one sensor is located at a known distance down-stream of the pressure pulse generator and a second sensor located up-stream of the pressure pulse generator at a second known distance, the pressure pulse generator and the respective sensors communicating with a control unit (35) that receive and process the generated pressure pulse and the registered pressure pulses to determine the flow rate of the medium and the specific acoustic propagation speed.

Description

Device and method for measuring multi phase flow.

The present invention concerns an apparatus and a method for determining flow rate and gas/liquid ratio in multi-phase flows in pipes and wells, as stated in the introductory of claims 1 and 3, respectively.

Technical background.

US Patent 4,312,234 discloses the use of a twisted tape and a venturi. The pressure loss across each is measured. Mathematical and experimental (calibration) values are used to correlate the measured pressure losses to the mixture flow rate. The twisted tape is located immediately upstream to establish an annular shaped and homogenous flow through the venturi. This method depends on the use of a correct mathematical model with comprehensive calibration values. The method provides the mixture flow rate if the gas-liquid ratio is known. Moreover, this method requires an installation inside the pipe system, while the provision of the large number of required calibration values is very difficult.

US Patent 4,202,230 discloses an comparative filter correlating technique, in which several type of signals can be used: pressure, acoustic, optical, and others. Experimental values are required to identify the characteristic properties of the flowing phases. Two sensors pick up the signal and compare this with the characteristic properties. The propagation time for identical properties results in the flow rate. However, the method provides only the flow rates of individual phases and not the gas-liquid ratio. The present applicant is of the opinion that it is very difficult to obtain values for theses characteristic properties and that these properties are also liable to change between two metering stations.

US Patent 4,884,457 discloses two density meters, such as gamma ray meters. The measurements are correlated and compared with theoretical equations for a two-phase flow. However, such gamma ray meters are not able to provide a reponse that is sufficiently fast to detect the detailed flow properties which are required to cross- correlate the values.

Briefly, a variety of metering techniques for multi-phase systems have been proposed to measure flow rate and gas-liquid ratios. The problem is very complex and has not been solved. A lot of new techiques are being developed, but the details of these are mostly unavailable.

A gamma ray meter can measure the density of a multi-phase mixture provided that the meter have been calibrated. Typically, the pipe is filled with the gas phase and the meter is calibrated, whereupon the pipe is filled with the liquid phase for calibration with respect to the latter. The equipment is then used to measure the reduction of intensity of the radiation that passes through the mixture of the two calibration fluids (gas and liquid). However, the calibration curve is necessarily not linear and thus it is not always possible to predict the calibration curve for mixtures. Experience from experiments with flowing gas-liquid mixtures is used to estimate the shape of the calibration curve. However, a considerable volume of experimental values is requried to obtain sufficiently accurate values for the real mixture density. This method provides only the gas-liquid ratio. For statistical reasons, this gamma ray instrument must measure the reduction of ray intensity during a certain period of time this it is not suited for the provision of momentary values. Several different gamma ray apparatus have been proposed, and such apparatus have been tested to overcome the difficulties connected with this technique. As mentioned above obtaining a sufficient amount of gamma rays to provide significant signals takes time (statistic of nucleous phenomena) and therefore such methods are, for that reason, not readily applicable to cross-correlation techniques.

The cross-correlation technique is used in several of the proposed multi-phase methods. The cross-correlation technique is based upon the measurement of a signal at two locations. These two signals are compared to obtain information about the propagation time between the two positions. Natural fluctuations form the basis of most of the cross-coπelation techniques. These natural fluctuations are difficult to detect.

Capacitance methods are being developed to detect the mass flow of hydrocarbons and water in a pipe. However, such method is sensitive to water; i.e., the method measures the water flow rate, and assumes that the remaining flow is hydrocarbons. However, one can not distinguish between liquid hydrocarbons and gaseous hydrocarbons. Moreover, the capacitance method is influenced by the gas-liquid ration, thus claiming for a correction of the metering results in view of an independent measurement for gas/liquid fraction, provided from e.g. a gamma ray meter.

Techniques using microwaves are being developed, and this is the latest contribution to this art. Microwaves are absorbed by water, and like the capacitance meter, one assumes that the remaining medium consists of hydrocarbons. The microwave technique (and the capacitance method) are also influenced by the gas/liquid ratio, accordingly a calibration is required. On the other hand, the microwave technique may be used for cross-correlation, but since the technique involves a large metering volume, only particular features of the multi-phase flow in a large scale are detectable.

The capacitance method and the microwave technique have substantially the same field of use, but do also have the same limitations.

In connection with research and in commercial applications, metering equipment consisting of two meters are being developed: a gamma ray meter and a capacitance or microwave meter. One of the meters provides the gas/liquid ratio and the other provides the amount of water. However, none of these are able to provide the flow rate in a multi-phase system.

Meters based upon the principle of gamma rays can be used to measure gas and volumetric liquid flowrates in a pipe. However, the accuracy of such metering is questionable as mentioned above. A substantial degree of calibration must be done to obtain good results. The gamma ray equipment can be used in the laboratory with accesories to calibrate the regularity of the equipment, but the application of such technique off-shore and with subsea installations has practical limitations. The gamma ray meter is not applicable to cross-correlation. A capacitance meter is said to be applicable to the metering of water volume flowing with hydrocarbons in a pipe. The central question is the applicability of the capacitance meter to cross-correlation. The meter is said to be adjustable for such applications but, from the present inventor's point of view,. this will become difficult. The technique is based upon a large metering volume; i.e. a pipe length that is several times longer than the pipe diameter. In such volume, it will be difficult to register anything other than the general properties of the flow (the flow characteristics). Thus, the capacitance method is applicable to cross-correlation in flows having a coarse flow regime, such as liquid plugs. The technique can not be used for cross-correlation in a uniform bubble flow, and not with an annular shaped flow. Many methods exist for determining the parameters of multi-phase systems, and at the present many are being developed.

Object.

The object of the present invention is to provide a single apparatus and a method to measure flow rate and/or liquid or gas fraction in multi-phase mixtures.

The invention.

The object above is achieved as stated in the characterizing part of claim 1 and 2. Further features of the invention appear from the dependent claims 3-8. The present invention is based upon a principle of measuring propagation speed of a low frequency pressure pulse through the medium. The flow rate and the gas/liquid ratio in a multi-phase flow is, in accordance with the invention, provided by measuring the pulse propagation speed to a location up-stream of the pressure pulse source and to a second location down-stream of the pressure pulse source. The mixture flow rate can be determined directly by measuring the difference in pulse propagation speed between the pulse source and a metering point down-stream and upstream, respectively, in relation to the source, provided that the distance between the respective points are known. The gas/liquid ratio in a multi-phase stream is, in accordance with the present invention, determined indirectly from the real pulse propagation speed in the medium by subtracting the medium flow rate from the measured pulse speed. By providing information about the medium acoustic properties in advance, the measured pulse speed can be used to determine e.g. the liquid volume fraction in the multi-phase flow.

The propagation speed of a pressure pulse will vary in accordance with the compressibility of the medium. With respect to gas and liquid, the difference between their compressibilities is large. This difference also exsists in water/hydrocarbon systems. Accordingly, the present invention is also applicable to the metering of water volume in the hydrocarbon flow. The propagation speed of a pressure pulse in a multi-phase system is typically in the range from 20 to 100 m/s; i.e., a measurement can be effected in a simple manner, such as with ordinary pressure transducers. The flow rate of multi-phase systems in a pipe is typically fom 1 to 10 m/s, and accordingly, metering results with great accuracy are in priciple achievable.

However, the present invention is not limited to systems of the gas/liquid type. The principle can also be used with other multi-component systems that exhibit different phases having different compressibilities, such as water/oil, emulsions and solids in liquid. Accordingly, the present invention has large potential and a broad field of use compared with known metering systems.

Experiments carried out in connection with the present invention have illustrated that if a pressure pulse is to be sufficiently propagated in such media the frequency has to be low. Pressure pulses having a frequency below 100 Hz are observed to be far less absorbed in the medium than at higher frequencies. The preferred frequency range will depend on the specific medium, but frequencies below 20 Hz are preferred, so that measurement across larger distances can be effected. If the pressure pulses are generated by expanding a small gas volume into the two-phase flow (e.g. with an injection pressure of about 10 bars), with e.g. a water/air system at a pressure close to atmospheric, measurement could be effected at a distance from 2 to 4 meters from the pulse source. Since such low frequent pressure pulses are not greatly absorbed in a flowing medium of this type, the metering method according to the invention is not substantially influenced by the flow pattern. This is a great advantage since the flow pattern can vary to a large extent in multi-phase systems. As described above, determination of the medium flow rate can be done directly by subtracting the propagation speed from the pulse generator to a point up-stream of the generator and to a point down-stream of the generator. The pressure pulse will move down-stream with a speed equal to the specific acoustic propagation speed of the medium plus the medium flow rate. On the other hand, the pressure pulse will move up-stream of the pulse generator with a speed equal to the specific acoustic propagation speed of the flowing medium minus the flow rate of the medium. On the basis that the distance Lβ and Lc from the pressure pulse generator to the respective metering locations (B) and (C), down-stream and up-stream of the pulse generator, respectively, are known, the medium flow rate is determined according to the following formula:

~B ~ C

^_ _ = 0 • 5

in which tB is the pressure pulse propagation speed from the generator to the down¬ stream metering station B and tc represents the pressure pulse propagation speed from the generator to an up-stream metering station C.

A determination of the phase fractions of the medium can be effected from a knowledge of the acoustic nature of the medium. If a metering principle according to the present invention is used with oil installations, numerical data for acoustic propagation speed of the respective phases must be provided. Numerical data for the speed of sound in natural gas is well known and is convenient to calculate for different process conditions, i.e. pressure, temperature and gas density. Acoustic propagation speed in the oil fraction can be correlated in view of pressure, temperature and pressure. In an adaptation to specific fields of use, making high demands on accuracy, it will be appropriate to carry out laboratory tests to establish a mathematical model. By metering pressure and temperature of the medium in addition to determination of the specific speed of sound, as stated above, the phase fractions can be calculated. In other situations it may be sufficient to apply available base values to establish a coarser reference with respect to the speed of sound. Even though the acoustic propagation speed will vary with pressure and temperature, the process conditions will, in most cases, be constant in the metering interval as described in further detail below.

The equipment.

In connection with a piping system, an apparatus according to the present invention can, for example, be provided as a pipe section having standard connections. This section is provided with a pressure pulse generator and at least two pressure recorders. A simple form of a pressure generator is based upon the principle of expanding a small gas volume into the flowing gas-liquid mixture to be measured. This gas must have a pressure above the pressure in the medium to be measured. Such pressure pulse generator can, for example, comprise a gas tank, filled with a gas at a relatively high pressure, the gas tank being in flow connection with the pipe in which the metering occurs and separated from the pipe by a fast opening valve. By opening the fast opening valve the small gas volume will expand into the main pipe and generate a pressure pulse.

The pressure pulse is initialized when the valve is opened. Without any wish to be bound by a particular theory, the base mechanism behind the pressure pulse principle can, in general, be described as follow: At ideal conditions in a homogeous and stationary medium, an oscillating gas (such as nitrogen) bubble will be produced. When the bubble escapes into the homogenous medium, the pressure inside the bubble will be higher than of the environment. Because of this gauge pressure, the bubble will expand to neutralize the pressure difference between the bubble and the environments. This pressure equalization is a dynamic process, and accordingly, the bubble will oscillate with a decreasing amplitude until equilibrium is realised. However, in reality, a lot of different media, as stated above, exist locally in a multi-phase medium, so that an injected gas bubble will generate pulses with a spectrum of frequencies that propagate in the bulk phase. In a metering system according to the present invention, pulses having the desired frequency, preferably as low as possible, are filtered away by means of a metering and control unit. In an alternative way of generating pressure pulses, a bendable ferritic membrane can be provided in the pipe wall in a main plane substantially parallel with the longitudinal axis of the pipe. A coil, located adjacent to the membrane, can produce a short duration magnet field to effect a temporary bending of the membrane. In this way, a pressure pulse can be created directly into the medium to be metered. An alternative mode of generating pressure pulses is to apply a vibrator means, e.g. of the type used in seismologic research.

A person skilled in the art will naturally find the appropriate method to establish such pressure pulses and the present invention should not be regarded as being limited to either high pressure gas injection nor ferritic membranes, as suggested above.

The pressure recorders can for example be based upon a simple pressure metering apparatus, such as a pressure transducer. The general requirement of the pressure recorders is that they have to exhibit as short response time as possible and that they are adapted to a metering pressure range in conformity with the metering systems in question. A metering apparatus according to the present invention can altemativly be formed as a probe to be inserted and fixedly mounted by, for example, logging tools of known type, inside a pipe or a well. The metering apparatus can consist of two membranes and two pressure recorders mounted on a, e.g. two meter long, probe in the form of a rod or the like. Preferably, a membrane and a recorder are mounted at each side of the respective ends of the probe. The membranes can be adapted to vibrate at different frequencies, such as 8 Hz and 16 Hz, and the recorders can register the pressure continously. The pressure data can then be filtered to provide signals only from the membrane at the other side of the probe as input values for the calculation of pulse speed. The pulse speed can be measured continously by alternating between 8 Hz and 16 Hz for the two membranes. When the signal from the membrane at the other side of the probe has ben received, the frequencies can be altered. By alternating between 8Hz/16Hz and 16Hz/8Hz, respectively, pulse speed across the same pipe segment can be measured continously. By continously measuring down-stream and up-stream pulse speed across the same pipe segment, the data basis for the determination of flow rate and gas/liquid fraction will be very good.

Brief description of the Dra ings.

In the following, the present invention is described in further detail with reference to drawings, in which Figure 1 illustrates a metering arrangement according to the present invention, Figur 2 is a diagram showing the time lag between generated pressure pulse and measured pressure pulse,

Figure 3 illustrates an alternative metering arrangement according to the present invention, Figur 4 is a diagram showing the pressure pulse-response with respect to the pulse frequency in a water-air system provided in accordance with the present invention, Figure 5 is a diagram illustrating theoretical variation in pressure. pulse speed with respect to the mass fraction of air in a two-phase system comprising water and air, Figure 6 shows pressure pulse response with respect to pulse frequency in a two phase system consisting of water and air, and Figure 7 illustrates schematically an alternative metering arrangement according to 5 the invention in the form of a probe to be inserted into a pipe section or a well.

Detailed description of the invention.

Figure 1 shows an example of a metering arrangment consisting of a pipe 11 in which the flow direction of the two phase flow is indicated by the arrow 12. The

10 pulse generator is, in this embodiment illustrated, as a gas tank 16 that contains e.g. nitrogen at a pressure higher than the pressure of the medium inside the pipe 11. The gas tank 16 communicates with the pipe 11 via a control valve 14a and is provided with a pressure sensor 13 to detect the gas pressure in the tank 16. Refilling of gas is regulated by means of a valve 14b. At the diametrical opposite side of the pipe 11

15 (in this example), a pressure sensor 13a is provided to register the generated pressure pulse from a relatively small gas volume being expanded into the pipe 11 from the gas tank 16 via control valve 14a. However, the pressure sensor 13a can be located at angle of e.g. 45° from the pressure pulse generator with respect to the pipe cross section, provided that it is located in the vicinty of the origin of the pressure pulse.

20 A corresponding pressure sensor 13b is located down-stream of the pulse generator and the sensor 13a. A metering and control unit 15 communicates with the pressure sensors 13, 13a and 13b including the control valves 14a and 14b. The metering and control unit 15 initiates a pressure pulse in the pipe 11 by injencting a small gas volume at relatively high pressure by a quick and short opening of the control valve 25 14a. The generated pressure pulse is sensed at the pressure sensors 13a and 13b which send a signal to the metering and control unit 15. By means of this arrangment, specific speed of sound in the two-phase flow can be measured by using the propagation speed from the pulse generator to the sensor 13a as reference point. Figure 2 shows generally the loss of intensity and time lag of the generated 30 pressure pulse (solid line) and the measured pressure pulse (stippled line). The propagation speed of the pressure pulse from the generator to the sensor can me measured at several locations, e.g. at the pulse maxmimum or the wave front. If the distance between the pulse generator and sensor is known the pulse propagation speed can be found directly. This speed will naturally vary with, among other things, the flow rate of the medium. As appears from the diagram, the measured pressure pulse has a lower intensity than the generated one. This absorption increase with increasing pulse frequency is discussed in further detail below with reference to Figure 4. Moreover, the pulse maxima are rounded off. This is because the pressure pulse disperses to a certain degree in the medium, in which the pulse propagates faster in the liquid phase compared with the gas phase. Figure 3 shows an alternative metering arrangement according to the present invention for the metering of void fraction and flow rate in a two-phase flow. The pulse generator is in this embodiment denoted generally at 36 and can, for example, comprise either a gas injection system as indicated in Figure 1 or a vibrating membrane as discussed above. The directon of flow of the two-phase medium is indicated by arrow 32. Three pressure sensors 33a, 33b and 33c are located up- stream, opposite and down-stream of the pulse generator 36, respectively. The pulse generator 36 and the respective pressure sensors all communicate with a metering and control unit 35. As discussed above, the flow rate of the medium can be determined directly by subtracting the pressure pulse propagation speed up-stream, i.e. from the pulse generator 36 to the pressure sensor 33a up-stream, from the pressure pulse propagation speed down-stream, i.e. from the pulse generator 36 to the pressure sensor 33c down-stream, provided, of course, that the distance between the respective locations are known.

In Figure 7, a probe is indicated as being inserted into a pipe section 71 as described above. The probe, here generally denoted by 72, comprises pulse generators 73a and 73b located at opposite ends of the probe, and two pressure sensors 74a and 74b located in the opposite ends of the probe and adjacent to the respective pulse generators. The pulse generators are preferably ferritic membranes that vibrate continously at a desired frequency, induced by means of an electromagnetic coil. The probe length can be adapted to the actual need, but typically, the length may vary from 2 to 4 meters. The membrane can, as mentioned above, be adapted to vibrate at different frequencies, for example alternating between 8 and 16 Hz. By filtering the registered pressure data, thus using only the signals from the membrane at the opposite end of the probe as input values for the calculation of pulse speed, a metering of both up-stream and down-stream pulse speed across the same pipe segment can be effected, thus providing a good basis to determine both gas-liquid fraction and flow rate. This alternative configuration is particularly suited for well bore installations, in which the probe is simply inserted into the well bore and located at a desired position by means of ordinary available tools, optionally together with other tools that is commonly used with well logging. Communication with the surface can be done e.g. by means of an ordinary electric logging cable

Example 1.

In order to illustrate the invention in further detail, experiments were carried out with a two-phase system consisting of water and air. The appratus consisted of a plastic pipe, a pulse generator, pressure sensors and a PC. The main element of the appratus was a ca. 50 meter long pipe circuit, of which 25 meter in each direction, having an inner diameter of 4.26 cm. The pipe circuit was constructed of transparent PVC plastic to be able to monitor the flow regime in the two-phase flow. The fluid mixture flowing through the pipe was transported by means of a compressor and a water pump respectively for air and water separately. The water was circulated from a 2 m3 water vessel via a mixing unit and a stabilizing unit through the pipe circuit via a separator and back to the water vessel. The rate was controlled by means of a manual butterfly valve. The air was supplied by a compressor. The air pressure could be controlled by a reduction valve, and the rate could be controlled by means of three manual butterfly valves; one for small, one for medium, and one for large rates.

Magnetic flow meters and rotameters were used to measure the in-flowing fluids. The flow rate of water was measured with a magnetic flow meter and three rotameters. The magnetic flow meters were directly connected with a PC, whereas the rotameters could only be read manually. The air rate could be measured by means of three magnetic flow meters and four rotameters. The air pressure of the in¬ flowing air was measured by means of an oil-filled manometer. After the separately in-flowing phases were measured, the phases were intermixed to form a two-phase fluid in a V-fitting and transported through the horizontal pipe section.

To effect the necessary measurements, a 5 meter long pipe section was removed fro the circuit and replaced by a new section that was, in principle, formed as shown in Figure 3. However, the metering station consisted of a pulse generator and pressure sensors that could be selectively located in the 9 sensor holds. The pressurized air container consisted of a ca. 8 cm long 16 bar PVC pipe having an inner diameter of 4 cm, that was adapted to inject a pulse creating nitrogen volume of about 5 cm3 into the main pipe. The pressurized air vessel was connected with a nitrogen tank via a valve, thus enabeling pressure regulation from 1 to 16 bar. The pressure valve of the pressure pulse generator, cf. the valve 14a of Figure 1, was a solenoid valve having a bore diameter of 10 mm. Two types of pressure sensors were used: 1 bar and 5 bar sensors. The output signals from the pressure sensors were guided via a amplifier and a digitalisating unit, and registered in a PC. The pressure was registered with a sampling rate of 300 Hz. The metering section was located as far down-stream from the mixing unit as possible so that the two-phase fluid obtained the longest possible flow path prior to metering. The flow pattern was thus fully developed prior to the metering station.

Measurements were carried out for different gas/liquid conditions and different flow rates by injecting 5 cm3 nitrogen volumes into the main pipe, in which the nitrogen pressure was varied from 6 to 12 bar. The pressure of the two-phase flow was close to atmospheric. The results of these experiments are illustrated in Figure 4, that shows the pulse speed in m/s in view of mass fraction air based upon counter current metering. Figure 5 shows theoretical values corresponding to Figure 4 calculated according to Kieffers model (Kieffer S.W., 1977; Sound Speed in a Liquid-Gas mixture; Water- Air and Water-Steam. Dep. of Geol., Univ. of Ca , LA). The values in Figure 4 measured according to the present invention exhibit surprisingly good correspondance with the theoretical values. This illustrates that the present invention can be used for the metering of volume fractions of the respective phases in a two-phase flow. Likewise, the medium flow rate can be calculated, as dicussed above, by substracting down-stream pulse speed from up-stream pulse speed. The measurements should be carried out simultaneously across both (or more) of the pressure sensors up-stream and down-stream the pulse generator and across the same pipe segment.

Example 2

In order to illustrate the influence of the frequency range for the pressure pulse, a test corresponding to Example 1 was conducted. Fig. 6 discloses a summary of these tests for an air dominant flow regime having a pulse response as a function of pulse frequency. These values originated from a FFT-routine (Fast Fourier Transform). As seen in the Figure, the pulse response declines to a practically non-detectable signal at a pulse frequency of approximately 50 Hz. This emphazises the importance of using correct pulse frequency to obtain results that are useful.

Furthermore, the pulse response for a fluid dominated flow regime has a tendency to exhibit a positive shift. This means that the measuring sensor registers a higher main frequency than the reference sensor. On the other hand for air dominated flow regimes a negative response shift is observed. This means that the measuring sensor registers a lower main frequency than the reference sensor. The response shift within the frequency range is also to a great extent a fluid characteristic for a two-phase fluid. In other words, this characteristic can determine the fraction composition of the two-phase medium.

In addition, the frequency analysis contains much other information which can be utilized for determining characteristics for a two-phase flow.

Claims

Claims:
1. Method for determining flow rate and quantity ratio between different phases in pipes and wells; the flowing medium comprises two or more phases, particularily for two-phase systems of the natural gas/oil type, wherein a sound wave is generated at a location (36) in or in the vicinity of the pipe or the well; the sound wave is registered at a first location (33c) in the flow direction from the location (36) for the generated sound wave, and the sound wave is registered at a second location (33a) opposite the flow direction from the location (36) for the generated sound wave, wherein the distances between the locations (36) where the sound wave is generated and the respective measuring first and second locaions (33c and 33a) are denoted by lengths Lc and L,; the time difference between the propagation time of the pressue pulse, ti and t2, respectively, through the medium from the location (36) to the first and second location (33c) and (33a), respectively, is used for determining the flow velocity of the medium according to following formula:
* = 0.5 * *>B _ LC
wherein v ..____ denotes the flow velocity of the composition; c h a r a c t e r i z e d by the sound wave transmitted from location (36) into the flowing medium in the pipe or the well is generated with a frequency less than or equal to 100 Hz, and optionally determining the gas/fluid ratio in the medium by subtracting the absolute flow velocity of the medium from the measured propagation velocity, whereafter comparison is made with the true propagation velocity using theoretical or experimental values.
2. Method according to claim 1, c h a r a c t e r i z e d by the sound wave is generated as discrete pressure pulses.
3. Device for determining flow rate and gas/fluid ratio in pipes and wells where the flowing medium comprises two or more phases, particularily for two-phase systems of the natural gas/oil type, comprising a generator (36) for generating sound waves into the medium, and two or more sensors (33a;33c) for registering sound waves generated in the generator (36), at least one of the sensors being located at a known distance in the flow direction from the generator, and a second sensors being located at a second known distance opposite the flow direction from the generator, and the respective sensors (33a;33c) are all connected to a control unit (35) which 5 can receive and process the generated sound wave and the registered sound waves for determining the flow velocity of the medium and the specific acoustic propagation velocity, characterized by the generator (36) and associated sensors (33a; 33c) being adapted to respectively generate and register sound waves having a frequency
10 less than or equal to 100 Hz.
4. Device according to claim 3, characterized by the generator (36) and associated sensors (33a;33c) are adapted to respectively generate and register sound waves in the form of discrete pulses.
15 5. Device according to claim 4, characterized by the generator comprising a gas tank (16) containing a gas at a pressure higher than the pressure of the medium to be measured, the tank being in fluid communication with the flow duct housing the medium to be measured, the gas tank and the duct being separated by a fast opening valve that,
20 when opened, expands gas into the medium to be measured, thus establishing a pressure pulse in the same.
6. Device according to claim 4, characterized by the generator (36) comprising a bendable ferritic membrane located in the duct wall in a main plane being substantially in parallel 25 with the longitudinal axis of the duct, and an associated coil located adjacent to the membrane to create a short duration magnet field to provide a temorarily bending of the membrane, thus creating a pressure pulse directly into the medium to be measured.
7. Device according to one of claims 3 to 6,
30. characterized by the generator (36) being adapted to generate pressure pulses having a frequency below 20 Hz.
8. Device according to one of claims 5 to 7, characterized by the generators (73a;73b) being integrated in a probe (72) in the form of a pipe or the like, each generator being located at opposite ends of the probe (72), in which two pressure sensors (74a,74b) are located at opposite ends of the probe and adjacent to the respective generators.
9. Device according to claim 8, characterized by the generators (73a, 73b) is adapted to operate at mutually different frequencies.
10. Device according to claim 9, characterized by the respective generators (73a,73b) being adapted to generate pressure pulses at two mutually different and alternating frequencies.
PCT/NO1993/000001 1992-01-13 1993-01-05 Device and method for measuring multi phase flow WO1993014382A1 (en)

Priority Applications (2)

Application Number Priority Date Filing Date Title
NO920155 1992-01-13
NO920155 1992-01-13

Publications (1)

Publication Number Publication Date
WO1993014382A1 true true WO1993014382A1 (en) 1993-07-22

Family

ID=19894774

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/NO1993/000001 WO1993014382A1 (en) 1992-01-13 1993-01-05 Device and method for measuring multi phase flow

Country Status (1)

Country Link
WO (1) WO1993014382A1 (en)

Cited By (78)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
FR2717573A1 (en) * 1994-03-15 1995-09-22 Total Sa Method and apparatus for the measurement and servo-control the flow of a multiphase fluid in a conveying line.
FR2721398A1 (en) * 1994-06-21 1995-12-22 Inst Francais Du Petrole Method and device for monitoring a periodic excitation particle flow in a conduit.
WO1996015427A1 (en) * 1994-11-09 1996-05-23 Jon Steinar Gudmundsson Method for determination of flow rate in a fluid
WO1998054550A1 (en) * 1997-05-28 1998-12-03 Degussa-Hüls Aktiengesellschaft Method for measuring density and mass flux
WO2000000793A1 (en) * 1998-06-26 2000-01-06 Cidra Corporation Fluid parameter measurement in pipes using acoustic pressures
FR2781565A1 (en) * 1998-07-24 2000-01-28 Inst Francais Du Petrole Fluid flow velocity determination method
EP0984250A1 (en) * 1998-09-02 2000-03-08 Daniel Industries, Inc., Ultrasonic 2-phase flow apparatus and method
US6151958A (en) * 1996-03-11 2000-11-28 Daniel Industries, Inc. Ultrasonic fraction and flow rate apparatus and method
US6354147B1 (en) 1998-06-26 2002-03-12 Cidra Corporation Fluid parameter measurement in pipes using acoustic pressures
WO2002023136A1 (en) * 2000-09-18 2002-03-21 ABB Fläkt AB A device and a method for measuring the flow in a fluid
WO2002025062A1 (en) * 2000-09-22 2002-03-28 Jon Steinar Gudmundsson Method for determining pressure profiles in wellbores, flowlines and pipelines, and use of such method
US6386018B1 (en) 1996-03-11 2002-05-14 Daniel Industries, Inc. Ultrasonic 2-phase flow apparatus and stratified level detector
DE10062875A1 (en) * 2000-12-16 2002-07-04 Hydrometer Gmbh Measurement of mass flow rate of liquids or gases using an ultrasonic transducer, with use of additional pressure gauges enabling determination of fluid density, temperature or viscosity
US6463813B1 (en) 1999-06-25 2002-10-15 Weatherford/Lamb, Inc. Displacement based pressure sensor measuring unsteady pressure in a pipe
WO2002088658A2 (en) * 2001-05-02 2002-11-07 Progenitive Services Limited Apparatus for and method of flooding and/or pressure testing pipelines
US6536291B1 (en) 1999-07-02 2003-03-25 Weatherford/Lamb, Inc. Optical flow rate measurement using unsteady pressures
US6550345B1 (en) 2000-09-11 2003-04-22 Daniel Industries, Inc. Technique for measurement of gas and liquid flow velocities, and liquid holdup in a pipe with stratified flow
WO2003062759A1 (en) * 2002-01-23 2003-07-31 Cidra Corporation Apparatus and method for measuring parameters of a mixture having solid particles suspended in a fluid flowing in a pipe
US6601458B1 (en) 2000-03-07 2003-08-05 Weatherford/Lamb, Inc. Distributed sound speed measurements for multiphase flow measurement
WO2003073047A1 (en) * 2002-02-26 2003-09-04 Cidra Corporation Apparatus and method for measuring parameters of a mixture having liquid droplets suspended in a vapor flowing in a pipe
WO2003087735A1 (en) * 2002-04-10 2003-10-23 Cidra Corporation Probe for measuring parameters of a flowing fluid and/or multiphase mixture
WO2003091671A1 (en) * 2002-04-24 2003-11-06 Cidra Corporation Apparatus and method for measuring parameters of a mixture having solid particles suspended in a fluid flowing in a pipe
US6691584B2 (en) 1999-07-02 2004-02-17 Weatherford/Lamb, Inc. Flow rate measurement using unsteady pressures
US6698297B2 (en) 2002-06-28 2004-03-02 Weatherford/Lamb, Inc. Venturi augmented flow meter
WO2004044532A2 (en) * 2002-11-12 2004-05-27 Cidra Corporation An apparatus having an array of piezoelectric film sensors for measuring parameters of a process flow within a pipe
WO2004048906A2 (en) * 2002-11-22 2004-06-10 Cidra Corporation Method for calibrating a flow meter having an array of sensors
US6782150B2 (en) 2000-11-29 2004-08-24 Weatherford/Lamb, Inc. Apparatus for sensing fluid in a pipe
US6813962B2 (en) 2000-03-07 2004-11-09 Weatherford/Lamb, Inc. Distributed sound speed measurements for multiphase flow measurement
US6837098B2 (en) 2003-03-19 2005-01-04 Weatherford/Lamb, Inc. Sand monitoring within wells using acoustic arrays
EP1515124A2 (en) * 1994-11-02 2005-03-16 Foster-Miller, Inc. Method and system for analyzing a two-phase flow
US6986276B2 (en) 2003-03-07 2006-01-17 Weatherford/Lamb, Inc. Deployable mandrel for downhole measurements
US7058549B2 (en) 2003-01-21 2006-06-06 C1Dra Corporation Apparatus and method for measuring unsteady pressures within a large diameter pipe
US7062976B2 (en) 2003-01-21 2006-06-20 Cidra Corporation Apparatus and method of measuring gas volume fraction of a fluid flowing within a pipe
US7086278B2 (en) 2003-01-21 2006-08-08 Cidra Corporation Measurement of entrained and dissolved gases in process flow lines
US7096719B2 (en) 2003-01-13 2006-08-29 Cidra Corporation Apparatus for measuring parameters of a flowing multiphase mixture
US7110893B2 (en) 2003-10-09 2006-09-19 Cidra Corporation Method and apparatus for measuring a parameter of a fluid flowing within a pipe using an array of sensors
US7121152B2 (en) 2003-06-06 2006-10-17 Cidra Corporation Portable flow measurement apparatus having an array of sensors
US7146864B2 (en) 2003-03-04 2006-12-12 Cidra Corporation Apparatus having a multi-band sensor assembly for measuring a parameter of a fluid flow flowing within a pipe
US7150202B2 (en) 2003-07-08 2006-12-19 Cidra Corporation Method and apparatus for measuring characteristics of core-annular flow
US7152003B2 (en) 2003-12-11 2006-12-19 Cidra Corporation Method and apparatus for determining a quality metric of a measurement of a fluid parameter
WO2006134221A2 (en) * 2005-06-16 2006-12-21 Justiflow Oy Ultrasound flowmeter arrangement for determining speed of sound
US7165464B2 (en) 2002-11-15 2007-01-23 Cidra Corporation Apparatus and method for providing a flow measurement compensated for entrained gas
US7171315B2 (en) 2003-11-25 2007-01-30 Cidra Corporation Method and apparatus for measuring a parameter of a fluid flowing within a pipe using sub-array processing
US7197942B2 (en) 2003-06-05 2007-04-03 Cidra Corporation Apparatus for measuring velocity and flow rate of a fluid having a non-negligible axial mach number using an array of sensors
US7197938B2 (en) 2003-06-24 2007-04-03 Cidra Corporation Contact-based transducers for characterizing unsteady pressures in pipes
US7245385B2 (en) 2003-06-24 2007-07-17 Cidra Corporation Characterizing unsteady pressures in pipes using optical measurement devices
US7253742B2 (en) 2003-08-01 2007-08-07 Cidra Corporation Method and apparatus for measuring parameters of a fluid flowing within a pipe using a configurable array of sensors
US7275421B2 (en) 2002-01-23 2007-10-02 Cidra Corporation Apparatus and method for measuring parameters of a mixture having solid particles suspended in a fluid flowing in a pipe
GB2438533A (en) * 2004-04-08 2007-11-28 Welldynamics Inc Downhole time of flight flow measurement
US7308820B2 (en) 2003-08-08 2007-12-18 Cidra Corporation Piezocable based sensor for measuring unsteady pressures inside a pipe
US7322251B2 (en) 2003-08-01 2008-01-29 Cidra Corporation Method and apparatus for measuring a parameter of a high temperature fluid flowing within a pipe using an array of piezoelectric based flow sensors
US7328624B2 (en) 2002-01-23 2008-02-12 Cidra Corporation Probe for measuring parameters of a flowing fluid and/or multiphase mixture
US7330797B2 (en) 2004-03-10 2008-02-12 Cidra Corporation Apparatus and method for measuring settlement of solids in a multiphase flow
US7340353B2 (en) 2003-07-15 2008-03-04 Cidra Corporation Dual function flow measurement apparatus having an array of sensors
US7343818B2 (en) 2003-01-21 2008-03-18 Cidra Corporation Apparatus and method of measuring gas volume fraction of a fluid flowing within a pipe
US7343820B2 (en) 2005-05-27 2008-03-18 Cidra Corporation Apparatus and method for fiscal measuring of an aerated fluid
US7363800B2 (en) 2004-05-17 2008-04-29 Cidra Corporation Apparatus and method for measuring compositional parameters of a mixture
US7367239B2 (en) 2004-03-23 2008-05-06 Cidra Corporation Piezocable based sensor for measuring unsteady pressures inside a pipe
US7418877B2 (en) 2005-07-07 2008-09-02 Expro Meters, Inc. Wet gas metering using a differential pressure based flow meter with a sonar based flow meter
US7440873B2 (en) 2005-03-17 2008-10-21 Expro Meters, Inc. Apparatus and method of processing data to improve the performance of a flow monitoring system
US7454981B2 (en) 2006-05-16 2008-11-25 Expro Meters. Inc. Apparatus and method for determining a parameter in a wet gas flow
US7516024B2 (en) 2004-03-10 2009-04-07 Expro Meters. Inc. Method and apparatus for measuring parameters of a stratified flow
WO2009071960A1 (en) * 2007-12-05 2009-06-11 Thormed Kft. Method and apparatus for determining the flow parameters of a streaming medium
US7603916B2 (en) 2005-07-07 2009-10-20 Expro Meters, Inc. Wet gas metering using a differential pressure and a sonar based flow meter
US7617716B2 (en) 2003-01-21 2009-11-17 Cidra Corporate Services, Inc. Total gas meter using speed of sound and velocity measurements
US7623976B2 (en) 2003-06-24 2009-11-24 Cidra Corporate Services, Inc. System of distributed configurable flowmeters
US7657392B2 (en) 2005-05-16 2010-02-02 Cidra Corporate Services, Inc. Method and apparatus for detecting and characterizing particles in a multiphase fluid
US7831398B2 (en) 2007-12-20 2010-11-09 Expro Meters, Inc. Method for quantifying varying propagation characteristics of normal incident ultrasonic signals as used in correlation based flow measurement
WO2011010108A1 (en) * 2009-07-24 2011-01-27 Wayne Rudd A method for determining speed of a signal species in a medium and associated apparatus
US7882750B2 (en) 2003-08-01 2011-02-08 Cidra Corporate Services, Inc. Method and apparatus for measuring parameters of a fluid flowing within a pipe using a configurable array of sensors
US7962293B2 (en) 2005-03-10 2011-06-14 Expro Meters, Inc. Apparatus and method for providing a stratification metric of a multiphase fluid flowing within a pipe
US7963177B2 (en) 2008-04-10 2011-06-21 Expro Meters, Inc. Apparatus for attenuating ultrasonic waves propagating within a pipe wall
US7975559B2 (en) 2008-07-03 2011-07-12 Expro Meters, Inc. Apparatus for attenuating ultrasonic waves propagating within a pipe wall
US8229686B2 (en) 2007-06-28 2012-07-24 Expro Meters, Inc. Apparatus and method for measuring liquid and gas flow rates in a stratified multi-phase flow
US8286466B2 (en) 2008-06-05 2012-10-16 Expro Meters, Inc. Method and apparatus for making a water cut determination using a sequestered liquid-continuous stream
US8346491B2 (en) 2007-02-23 2013-01-01 Expro Meters, Inc. Sonar-based flow meter operable to provide product identification
US8862411B2 (en) 2007-08-24 2014-10-14 Expro Meters, Inc. Velocity and impingement method for determining parameters of a particle/fluid flow
CN105891538A (en) * 2016-04-05 2016-08-24 广东欧珀移动通信有限公司 Mobile terminal capable of testing water flow velocity and usage method thereof

Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2151203A (en) * 1935-12-23 1939-03-21 Hugh B Wilcox Fluid meter and method of measuring the rate of flow of fluids
US3469445A (en) * 1967-07-20 1969-09-30 United Aircraft Corp Gas flow measuring system
US3496771A (en) * 1968-03-04 1970-02-24 United Aircraft Corp Mass flow measuring device for a gaseous medium
US3514071A (en) * 1967-04-14 1970-05-26 United Aircraft Corp Shock pulse generator
FI76885B (en) * 1987-01-16 1988-08-31 Valtion Teknillinen Akustiskt stroemningsmaetningsfoerfarande and the arrangement of the Foer tillaempning ratio.

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2151203A (en) * 1935-12-23 1939-03-21 Hugh B Wilcox Fluid meter and method of measuring the rate of flow of fluids
US3514071A (en) * 1967-04-14 1970-05-26 United Aircraft Corp Shock pulse generator
US3469445A (en) * 1967-07-20 1969-09-30 United Aircraft Corp Gas flow measuring system
US3496771A (en) * 1968-03-04 1970-02-24 United Aircraft Corp Mass flow measuring device for a gaseous medium
FI76885B (en) * 1987-01-16 1988-08-31 Valtion Teknillinen Akustiskt stroemningsmaetningsfoerfarande and the arrangement of the Foer tillaempning ratio.

Cited By (115)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
FR2717573A1 (en) * 1994-03-15 1995-09-22 Total Sa Method and apparatus for the measurement and servo-control the flow of a multiphase fluid in a conveying line.
EP0674155A1 (en) * 1994-03-15 1995-09-27 TOTAL Société anonyme dite : Method and apparatus for the non-intrusive measurement and for the regulation of flow rates of different phases of a multiphase fluid flowing within a conduit
US5661248A (en) * 1994-03-15 1997-08-26 Total Method and apparatus for non-intrusive measurement and control of the flow rates of the different phases of a multiphase fluid in a pipeline
FR2721398A1 (en) * 1994-06-21 1995-12-22 Inst Francais Du Petrole Method and device for monitoring a periodic excitation particle flow in a conduit.
US5639667A (en) * 1994-06-21 1997-06-17 Institut Francais Du Petrole Process and device for monitoring by periodic excitation a flow of particles in a pipe
DE19521786B4 (en) * 1994-06-21 2007-02-01 Institut Français du Pétrole, Rueil-Malmaison Method and apparatus for monitoring a particle flow in a conduit by periodic excitation
EP1515124A3 (en) * 1994-11-02 2005-04-27 Foster-Miller, Inc. Method and system for analyzing a two-phase flow
EP1515124A2 (en) * 1994-11-02 2005-03-16 Foster-Miller, Inc. Method and system for analyzing a two-phase flow
WO1996015427A1 (en) * 1994-11-09 1996-05-23 Jon Steinar Gudmundsson Method for determination of flow rate in a fluid
US6386018B1 (en) 1996-03-11 2002-05-14 Daniel Industries, Inc. Ultrasonic 2-phase flow apparatus and stratified level detector
US6151958A (en) * 1996-03-11 2000-11-28 Daniel Industries, Inc. Ultrasonic fraction and flow rate apparatus and method
US6209388B1 (en) 1996-03-11 2001-04-03 Daniel Industries, Inc. Ultrasonic 2-phase flow apparatus and method
US6202494B1 (en) 1997-05-28 2001-03-20 Degussa-Huls Aktiengesellschaft Process and apparatus for measuring density and mass flow
DE19722274A1 (en) * 1997-05-28 1998-12-03 Degussa A method for measuring density and mass flow
WO1998054550A1 (en) * 1997-05-28 1998-12-03 Degussa-Hüls Aktiengesellschaft Method for measuring density and mass flux
US6862920B2 (en) 1998-06-26 2005-03-08 Weatherford/Lamb, Inc. Fluid parameter measurement in pipes using acoustic pressures
US6354147B1 (en) 1998-06-26 2002-03-12 Cidra Corporation Fluid parameter measurement in pipes using acoustic pressures
WO2000000793A1 (en) * 1998-06-26 2000-01-06 Cidra Corporation Fluid parameter measurement in pipes using acoustic pressures
FR2781565A1 (en) * 1998-07-24 2000-01-28 Inst Francais Du Petrole Fluid flow velocity determination method
DE19934212B4 (en) * 1998-07-24 2004-09-02 Institut Français du Pétrole, Rueil-Malmaison Method and apparatus for measuring the flow rate of a fluid stream
US6546810B1 (en) 1998-07-24 2003-04-15 Institut Francais Du Petrole Process and device for measuring the velocity of flow of a fluid stream
EP0984250A1 (en) * 1998-09-02 2000-03-08 Daniel Industries, Inc., Ultrasonic 2-phase flow apparatus and method
US6463813B1 (en) 1999-06-25 2002-10-15 Weatherford/Lamb, Inc. Displacement based pressure sensor measuring unsteady pressure in a pipe
US6691584B2 (en) 1999-07-02 2004-02-17 Weatherford/Lamb, Inc. Flow rate measurement using unsteady pressures
US6536291B1 (en) 1999-07-02 2003-03-25 Weatherford/Lamb, Inc. Optical flow rate measurement using unsteady pressures
US6601458B1 (en) 2000-03-07 2003-08-05 Weatherford/Lamb, Inc. Distributed sound speed measurements for multiphase flow measurement
US6813962B2 (en) 2000-03-07 2004-11-09 Weatherford/Lamb, Inc. Distributed sound speed measurements for multiphase flow measurement
US6550345B1 (en) 2000-09-11 2003-04-22 Daniel Industries, Inc. Technique for measurement of gas and liquid flow velocities, and liquid holdup in a pipe with stratified flow
WO2002023136A1 (en) * 2000-09-18 2002-03-21 ABB Fläkt AB A device and a method for measuring the flow in a fluid
WO2002025062A1 (en) * 2000-09-22 2002-03-28 Jon Steinar Gudmundsson Method for determining pressure profiles in wellbores, flowlines and pipelines, and use of such method
US6782150B2 (en) 2000-11-29 2004-08-24 Weatherford/Lamb, Inc. Apparatus for sensing fluid in a pipe
DE10062875A1 (en) * 2000-12-16 2002-07-04 Hydrometer Gmbh Measurement of mass flow rate of liquids or gases using an ultrasonic transducer, with use of additional pressure gauges enabling determination of fluid density, temperature or viscosity
DE10062875B4 (en) * 2000-12-16 2007-02-08 Hydrometer Gmbh Flowmeter
WO2002088658A3 (en) * 2001-05-02 2003-12-31 Progenitive Services Ltd Apparatus for and method of flooding and/or pressure testing pipelines
GB2390435B (en) * 2001-05-02 2005-09-14 Progenitive Services Ltd Apparatus for and method of flooding and/or pressure testing pipelines
WO2002088658A2 (en) * 2001-05-02 2002-11-07 Progenitive Services Limited Apparatus for and method of flooding and/or pressure testing pipelines
US7359803B2 (en) 2002-01-23 2008-04-15 Cidra Corporation Apparatus and method for measuring parameters of a mixture having solid particles suspended in a fluid flowing in a pipe
WO2003062759A1 (en) * 2002-01-23 2003-07-31 Cidra Corporation Apparatus and method for measuring parameters of a mixture having solid particles suspended in a fluid flowing in a pipe
US7337075B2 (en) 2002-01-23 2008-02-26 Cidra Corporation Apparatus and method for measuring parameters of a mixture having liquid droplets suspended in a vapor flowing in a pipe
US7328624B2 (en) 2002-01-23 2008-02-12 Cidra Corporation Probe for measuring parameters of a flowing fluid and/or multiphase mixture
US7032432B2 (en) 2002-01-23 2006-04-25 Cidra Corporation Apparatus and method for measuring parameters of a mixture having liquid droplets suspended in a vapor flowing in a pipe
US7275421B2 (en) 2002-01-23 2007-10-02 Cidra Corporation Apparatus and method for measuring parameters of a mixture having solid particles suspended in a fluid flowing in a pipe
WO2003073047A1 (en) * 2002-02-26 2003-09-04 Cidra Corporation Apparatus and method for measuring parameters of a mixture having liquid droplets suspended in a vapor flowing in a pipe
WO2003087735A1 (en) * 2002-04-10 2003-10-23 Cidra Corporation Probe for measuring parameters of a flowing fluid and/or multiphase mixture
WO2003091671A1 (en) * 2002-04-24 2003-11-06 Cidra Corporation Apparatus and method for measuring parameters of a mixture having solid particles suspended in a fluid flowing in a pipe
US6698297B2 (en) 2002-06-28 2004-03-02 Weatherford/Lamb, Inc. Venturi augmented flow meter
WO2004044532A2 (en) * 2002-11-12 2004-05-27 Cidra Corporation An apparatus having an array of piezoelectric film sensors for measuring parameters of a process flow within a pipe
WO2004044531A2 (en) * 2002-11-12 2004-05-27 Cidra Corporation An apparatus having an array of clamp on piezoelectric film sensors for measuring parameters of a process flow within a pipe
US7400985B2 (en) 2002-11-12 2008-07-15 Cidra Corporation Apparatus having an array of clamp on piezoelectric film sensors for measuring parameters of a process flow within a pipe
WO2004044531A3 (en) * 2002-11-12 2004-11-25 Cidra Corp An apparatus having an array of clamp on piezoelectric film sensors for measuring parameters of a process flow within a pipe
WO2004044532A3 (en) * 2002-11-12 2004-10-28 Cidra Corp An apparatus having an array of piezoelectric film sensors for measuring parameters of a process flow within a pipe
US7367240B2 (en) 2002-11-15 2008-05-06 Cidra Corporation Apparatus and method for providing a flow measurement compensated for entrained gas
US7165464B2 (en) 2002-11-15 2007-01-23 Cidra Corporation Apparatus and method for providing a flow measurement compensated for entrained gas
US7328113B2 (en) 2002-11-22 2008-02-05 Cidra Corporation Method for calibrating a volumetric flow meter having an array of sensors
WO2004048906A2 (en) * 2002-11-22 2004-06-10 Cidra Corporation Method for calibrating a flow meter having an array of sensors
US7139667B2 (en) 2002-11-22 2006-11-21 Cidra Corporation Method for calibrating a volumetric flow meter having an array of sensors
WO2004048906A3 (en) * 2002-11-22 2004-09-23 Cidra Corp Method for calibrating a flow meter having an array of sensors
US7096719B2 (en) 2003-01-13 2006-08-29 Cidra Corporation Apparatus for measuring parameters of a flowing multiphase mixture
US7343818B2 (en) 2003-01-21 2008-03-18 Cidra Corporation Apparatus and method of measuring gas volume fraction of a fluid flowing within a pipe
US7617716B2 (en) 2003-01-21 2009-11-17 Cidra Corporate Services, Inc. Total gas meter using speed of sound and velocity measurements
US7571633B2 (en) 2003-01-21 2009-08-11 Cidra Corporate Services, Inc. Measurement of entrained and dissolved gases in process flow lines
US7062976B2 (en) 2003-01-21 2006-06-20 Cidra Corporation Apparatus and method of measuring gas volume fraction of a fluid flowing within a pipe
US7058549B2 (en) 2003-01-21 2006-06-06 C1Dra Corporation Apparatus and method for measuring unsteady pressures within a large diameter pipe
US8109127B2 (en) 2003-01-21 2012-02-07 Cidra Corporate Services, Inc. Measurement of entrained and dissolved gases in process flow lines
US7086278B2 (en) 2003-01-21 2006-08-08 Cidra Corporation Measurement of entrained and dissolved gases in process flow lines
US7146864B2 (en) 2003-03-04 2006-12-12 Cidra Corporation Apparatus having a multi-band sensor assembly for measuring a parameter of a fluid flow flowing within a pipe
US6986276B2 (en) 2003-03-07 2006-01-17 Weatherford/Lamb, Inc. Deployable mandrel for downhole measurements
US6837098B2 (en) 2003-03-19 2005-01-04 Weatherford/Lamb, Inc. Sand monitoring within wells using acoustic arrays
US7028538B2 (en) 2003-03-19 2006-04-18 Weatherford/Lamb, Inc. Sand monitoring within wells using acoustic arrays
US7197942B2 (en) 2003-06-05 2007-04-03 Cidra Corporation Apparatus for measuring velocity and flow rate of a fluid having a non-negligible axial mach number using an array of sensors
US7121152B2 (en) 2003-06-06 2006-10-17 Cidra Corporation Portable flow measurement apparatus having an array of sensors
US7302861B2 (en) 2003-06-06 2007-12-04 Cidra Corporation Portable flow measurement apparatus having an array of sensors
US7197938B2 (en) 2003-06-24 2007-04-03 Cidra Corporation Contact-based transducers for characterizing unsteady pressures in pipes
US7623976B2 (en) 2003-06-24 2009-11-24 Cidra Corporate Services, Inc. System of distributed configurable flowmeters
US7245385B2 (en) 2003-06-24 2007-07-17 Cidra Corporation Characterizing unsteady pressures in pipes using optical measurement devices
US7150202B2 (en) 2003-07-08 2006-12-19 Cidra Corporation Method and apparatus for measuring characteristics of core-annular flow
US7340353B2 (en) 2003-07-15 2008-03-04 Cidra Corporation Dual function flow measurement apparatus having an array of sensors
US7253742B2 (en) 2003-08-01 2007-08-07 Cidra Corporation Method and apparatus for measuring parameters of a fluid flowing within a pipe using a configurable array of sensors
US8336393B2 (en) 2003-08-01 2012-12-25 Cidra Corporate Services Inc. Method and apparatus for measuring parameters of a fluid flowing within a pipe using a configurable array of sensors
US7882750B2 (en) 2003-08-01 2011-02-08 Cidra Corporate Services, Inc. Method and apparatus for measuring parameters of a fluid flowing within a pipe using a configurable array of sensors
US7322251B2 (en) 2003-08-01 2008-01-29 Cidra Corporation Method and apparatus for measuring a parameter of a high temperature fluid flowing within a pipe using an array of piezoelectric based flow sensors
US7308820B2 (en) 2003-08-08 2007-12-18 Cidra Corporation Piezocable based sensor for measuring unsteady pressures inside a pipe
US7110893B2 (en) 2003-10-09 2006-09-19 Cidra Corporation Method and apparatus for measuring a parameter of a fluid flowing within a pipe using an array of sensors
US7171315B2 (en) 2003-11-25 2007-01-30 Cidra Corporation Method and apparatus for measuring a parameter of a fluid flowing within a pipe using sub-array processing
US7379828B2 (en) 2003-12-11 2008-05-27 Cidra Corporation Method and apparatus for determining a quality metric of a measurement of a fluid parameter
US7152003B2 (en) 2003-12-11 2006-12-19 Cidra Corporation Method and apparatus for determining a quality metric of a measurement of a fluid parameter
US7516024B2 (en) 2004-03-10 2009-04-07 Expro Meters. Inc. Method and apparatus for measuring parameters of a stratified flow
US7330797B2 (en) 2004-03-10 2008-02-12 Cidra Corporation Apparatus and method for measuring settlement of solids in a multiphase flow
US7367239B2 (en) 2004-03-23 2008-05-06 Cidra Corporation Piezocable based sensor for measuring unsteady pressures inside a pipe
GB2438533B (en) * 2004-04-08 2008-05-28 Welldynamics Inc Methods of monitoring downhole conditions
US7357021B2 (en) 2004-04-08 2008-04-15 Welldynamics, Inc. Methods of monitoring downhole conditions
GB2438533A (en) * 2004-04-08 2007-11-28 Welldynamics Inc Downhole time of flight flow measurement
US7363800B2 (en) 2004-05-17 2008-04-29 Cidra Corporation Apparatus and method for measuring compositional parameters of a mixture
US7962293B2 (en) 2005-03-10 2011-06-14 Expro Meters, Inc. Apparatus and method for providing a stratification metric of a multiphase fluid flowing within a pipe
US7440873B2 (en) 2005-03-17 2008-10-21 Expro Meters, Inc. Apparatus and method of processing data to improve the performance of a flow monitoring system
US7657392B2 (en) 2005-05-16 2010-02-02 Cidra Corporate Services, Inc. Method and apparatus for detecting and characterizing particles in a multiphase fluid
US7343820B2 (en) 2005-05-27 2008-03-18 Cidra Corporation Apparatus and method for fiscal measuring of an aerated fluid
WO2006134221A2 (en) * 2005-06-16 2006-12-21 Justiflow Oy Ultrasound flowmeter arrangement for determining speed of sound
WO2006134221A3 (en) * 2005-06-16 2007-04-19 Justiflow Oy Ultrasound flowmeter arrangement for determining speed of sound
US7418877B2 (en) 2005-07-07 2008-09-02 Expro Meters, Inc. Wet gas metering using a differential pressure based flow meter with a sonar based flow meter
US7603916B2 (en) 2005-07-07 2009-10-20 Expro Meters, Inc. Wet gas metering using a differential pressure and a sonar based flow meter
US7454981B2 (en) 2006-05-16 2008-11-25 Expro Meters. Inc. Apparatus and method for determining a parameter in a wet gas flow
US8346491B2 (en) 2007-02-23 2013-01-01 Expro Meters, Inc. Sonar-based flow meter operable to provide product identification
US8229686B2 (en) 2007-06-28 2012-07-24 Expro Meters, Inc. Apparatus and method for measuring liquid and gas flow rates in a stratified multi-phase flow
US8862411B2 (en) 2007-08-24 2014-10-14 Expro Meters, Inc. Velocity and impingement method for determining parameters of a particle/fluid flow
WO2009071960A1 (en) * 2007-12-05 2009-06-11 Thormed Kft. Method and apparatus for determining the flow parameters of a streaming medium
US10031011B2 (en) 2007-12-05 2018-07-24 Uscom Limited Ultrasonic flow meter including a single transmitting transducer and a pair of receiving transducers
US7831398B2 (en) 2007-12-20 2010-11-09 Expro Meters, Inc. Method for quantifying varying propagation characteristics of normal incident ultrasonic signals as used in correlation based flow measurement
US7963177B2 (en) 2008-04-10 2011-06-21 Expro Meters, Inc. Apparatus for attenuating ultrasonic waves propagating within a pipe wall
US8286466B2 (en) 2008-06-05 2012-10-16 Expro Meters, Inc. Method and apparatus for making a water cut determination using a sequestered liquid-continuous stream
US7975559B2 (en) 2008-07-03 2011-07-12 Expro Meters, Inc. Apparatus for attenuating ultrasonic waves propagating within a pipe wall
GB2472081B (en) * 2009-07-24 2014-03-05 Bios Developments Ltd A method for determining speed of a signal species in a medium and associated apparatus
WO2011010108A1 (en) * 2009-07-24 2011-01-27 Wayne Rudd A method for determining speed of a signal species in a medium and associated apparatus
US8991256B2 (en) 2009-07-24 2015-03-31 Bios Developments Limited Method for determining speed of a signal species in a medium and associated apparatus
CN105891538A (en) * 2016-04-05 2016-08-24 广东欧珀移动通信有限公司 Mobile terminal capable of testing water flow velocity and usage method thereof

Similar Documents

Publication Publication Date Title
Falcone et al. Multiphase flow metering: principles and applications
US5576974A (en) Method and apparatus for determining watercut fraction and gas fraction in three phase mixtures of oil, water and gas
US6301973B1 (en) Non-intrusive pressure/multipurpose sensor and method
US5679885A (en) Process and device for measuring physical parameters of porous fluid wet samples
US4470294A (en) Method and apparatus for simultaneous determination of fluid mass flow rate, mean velocity and density
US4896540A (en) Aeroacoustic flowmeter
US20070157737A1 (en) Apparatus and method for measuring a parameter of a multiphase flow
US5929342A (en) Method for monitoring three phrase fluid flow in tubulars
US6046587A (en) Measurement of flow fractions, flow velocities, and flow rates of a multiphase fluid using NMR sensing
US6698297B2 (en) Venturi augmented flow meter
US7380438B2 (en) Apparatus and method for providing a fluid cut measurement of a multi-liquid mixture compensated for entrained gas
US5214966A (en) Method and apparatus for measuring mass flow
US7258024B2 (en) Simplified fluid property measurement
US5036710A (en) Multi-phase flowmeter
US7134320B2 (en) Apparatus and method for providing a density measurement augmented for entrained gas
US7389687B2 (en) System for measuring a parameter of an aerated multi-phase mixture flowing in a pipe
US6655221B1 (en) Measuring multiphase flow in a pipe
US4331025A (en) Methods of measuring fluid viscosity and flow rate
US4048854A (en) System for determining the ratio of oil to water in a metered fluid stream
US6971259B2 (en) Fluid density measurement in pipes using acoustic pressures
US5526696A (en) Flow meters
US6575043B1 (en) Method and apparatus for characterizing flows based on attenuation of in-wall propagating wave modes
EP0684458A2 (en) Multiphase flow meter
US20050034535A1 (en) System to measure density, specific gravity, and flow rate of fluids, meter, and related methods
US4574643A (en) Two phase flowmeter

Legal Events

Date Code Title Description
AK Designated states

Kind code of ref document: A1

Designated state(s): CA JP RU US

AL Designated countries for regional patents

Kind code of ref document: A1

Designated state(s): AT BE CH DE DK ES FR GB GR IE IT LU MC NL PT SE

DFPE Request for preliminary examination filed prior to expiration of 19th month from priority date (pct application filed before 20040101)
122 Ep: pct application non-entry in european phase
NENP Non-entry into the national phase in:

Ref country code: CA