WO1993014382A1 - Dispositif et procede pour mesurer des ecoulements multiphases - Google Patents

Dispositif et procede pour mesurer des ecoulements multiphases Download PDF

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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
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WO
WIPO (PCT)
Prior art keywords
pressure
medium
generator
gas
pulse
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PCT/NO1993/000001
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English (en)
Inventor
Jon Steinar Gudmundsson
Original Assignee
Jon Steinar Gudmundsson
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Publication date
Application filed by Jon Steinar Gudmundsson filed Critical Jon Steinar Gudmundsson
Publication of WO1993014382A1 publication Critical patent/WO1993014382A1/fr

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Classifications

    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01P—MEASURING LINEAR OR ANGULAR SPEED, ACCELERATION, DECELERATION, OR SHOCK; INDICATING PRESENCE, ABSENCE, OR DIRECTION, OF MOVEMENT
    • G01P5/00—Measuring speed of fluids, e.g. of air stream; Measuring speed of bodies relative to fluids, e.g. of ship, of aircraft
    • G01P5/18—Measuring 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
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01F—MEASURING VOLUME, VOLUME FLOW, MASS FLOW OR LIQUID LEVEL; METERING BY VOLUME
    • G01F1/00—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow
    • G01F1/66—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow by measuring frequency, phase shift or propagation time of electromagnetic or other waves, e.g. using ultrasonic flowmeters
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01F—MEASURING VOLUME, VOLUME FLOW, MASS FLOW OR LIQUID LEVEL; METERING BY VOLUME
    • G01F1/00—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow
    • G01F1/704—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow using marked regions or existing inhomogeneities within the fluid stream, e.g. statistically occurring variations in a fluid parameter
    • G01F1/708—Measuring the time taken to traverse a fixed distance
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01F—MEASURING VOLUME, VOLUME FLOW, MASS FLOW OR LIQUID LEVEL; METERING BY VOLUME
    • G01F1/00—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow
    • G01F1/704—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow using marked regions or existing inhomogeneities within the fluid stream, e.g. statistically occurring variations in a fluid parameter
    • G01F1/708—Measuring the time taken to traverse a fixed distance
    • G01F1/7082—Measuring the time taken to traverse a fixed distance using acoustic detecting arrangements
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01F—MEASURING VOLUME, VOLUME FLOW, MASS FLOW OR LIQUID LEVEL; METERING BY VOLUME
    • G01F1/00—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow
    • G01F1/74—Devices for measuring flow of a fluid or flow of a fluent solid material in suspension in another fluid
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N29/00—Investigating 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
    • G01N29/02—Analysing fluids
    • G01N29/024—Analysing fluids by measuring propagation velocity or propagation time of acoustic waves
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01P—MEASURING LINEAR OR ANGULAR SPEED, ACCELERATION, DECELERATION, OR SHOCK; INDICATING PRESENCE, ABSENCE, OR DIRECTION, OF MOVEMENT
    • G01P5/00—Measuring speed of fluids, e.g. of air stream; Measuring speed of bodies relative to fluids, e.g. of ship, of aircraft
    • G01P5/24—Measuring 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
    • G01P5/245—Measuring 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
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N2291/00—Indexing codes associated with group G01N29/00
    • G01N2291/02—Indexing codes associated with the analysed material
    • G01N2291/028—Material parameters
    • G01N2291/02818—Density, viscosity
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N2291/00—Indexing codes associated with group G01N29/00
    • G01N2291/02—Indexing codes associated with the analysed material
    • G01N2291/028—Material parameters
    • G01N2291/02836—Flow rate, liquid level
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N2291/00—Indexing codes associated with group G01N29/00
    • G01N2291/02—Indexing codes associated with the analysed material
    • G01N2291/028—Material parameters
    • G01N2291/02872—Pressure

Definitions

  • 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.
  • 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.
  • a gamma ray meter can measure the density of a multi-phase mixture provided that the meter have been calibrated.
  • 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).
  • 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.
  • 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.
  • 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-co ⁇ elation 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.
  • such method is sensitive to water; i.e., the method measures the water flow rate, and assumes that the remaining flow is hydrocarbons.
  • 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.
  • 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.
  • 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.
  • metering equipment consisting of two meters: 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.
  • none of these are able to provide the flow rate in a multi-phase system.
  • gamma ray 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).
  • 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.
  • 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 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.
  • 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.
  • 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.
  • 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.
  • 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.
  • 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.
  • the medium flow rate is determined according to the following formula:
  • t B 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.
  • an apparatus in connection with a piping system, 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.
  • an oscillating gas such as nitrogen
  • 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.
  • 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.
  • 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.
  • 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.
  • the frequencies can be altered.
  • pulse speed across the same pipe segment can be measured continously.
  • the data basis for the determination of flow rate and gas/liquid fraction will be very good.
  • Figure 1 illustrates a metering arrangement according to the present invention
  • Figure 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
  • 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.
  • 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.
  • 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.
  • a valve 14b At the diametrical opposite side of the pipe 11
  • 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.
  • 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.
  • 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.
  • 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.
  • 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.
  • FIG. 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.
  • 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.
  • 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.
  • 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 m 3 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.
  • 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 cm 3 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.
  • the present invention can be used for the metering of volume fractions of the respective phases in a two-phase flow.
  • 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.
  • 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.
  • FFT-routine Fast Fourier Transform
  • 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.
  • the frequency analysis contains much other information which can be utilized for determining characteristics for a two-phase flow.

Abstract

L'invention se rapporte à un dispositif et à un procédé pour mesurer des débits et des fractions gaz/liquide dans des canalisations et des puits, dans lesquels le milieu en écoulement est constitué par plusieurs phases, en particulier par des systèmes à deux phases du type pétrole/gaz naturel. Le dispositif décrit se caractérise par un générateur d'impulsions de pression (36) qui génère dans le milieu en écoulement des impulsions de pression ayant une fréquence de 100 Hz au maximum, et par au moins deux capteurs de pression (33a; 33c), pour enregistrer l'impulsion de pression basse fréquence générée dans le générateur d'impulsions (36). Dans ce dispositif, au moins un des capteurs est disposé à une distance connue en aval du générateur d'impulsions de pression et un second capteur est disposé en amont du générateur d'impulsions de pression à une seconde distance connue, le générateur d'impulsions de pression et les capteurs correspondants étant placés en communication avec une unité de commande (35) qui reçoit et traite l'impulsion générée et les impulsions de pression enregistrées, afin de déterminer le débit du milieu en écoulement et la vitesse de propagation acoustique spécifique.
PCT/NO1993/000001 1992-01-13 1993-01-05 Dispositif et procede pour mesurer des ecoulements multiphases WO1993014382A1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
NO920155A NO174643C (no) 1992-01-13 1992-01-13 Apparat og framgangsmåte for bestemmelse av strömningshastighet og gass/væske-forhold i flerefase-strömmer
NO920155 1992-01-13

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WO1993014382A1 true WO1993014382A1 (fr) 1993-07-22

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Cited By (78)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
FR2717573A1 (fr) * 1994-03-15 1995-09-22 Total Sa Procédé et dispositif pour la mesure et l'asservissement du débit d'un fluide polyphasique dans une canalisation de transport.
FR2721398A1 (fr) * 1994-06-21 1995-12-22 Inst Francais Du Petrole Procédé et dispositif pour surveiller par excitation périodique un flux de particules dans un conduit.
WO1996015427A1 (fr) * 1994-11-09 1996-05-23 Jon Steinar Gudmundsson Procede de determination du debit d'un fluide
WO1998054550A1 (fr) * 1997-05-28 1998-12-03 Degussa-Hüls Aktiengesellschaft Procede pour mesurer une densite et un flux massique
WO2000000793A1 (fr) * 1998-06-26 2000-01-06 Cidra Corporation Mesure de parametre de fluide dans des canalisations a l'aide de pressions acoustiques
FR2781565A1 (fr) * 1998-07-24 2000-01-28 Inst Francais Du Petrole Procede et dispositif pour mesurer la vitesse d'ecoulement d'une veine fluide
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NO920155D0 (no) 1992-01-13
NO174643B (no) 1994-02-28
NO174643C (no) 1994-06-08

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