WO2006062856A1 - Systeme detecteur de debit multi-phase et procede pour determiner les fractions de composants du debit - Google Patents

Systeme detecteur de debit multi-phase et procede pour determiner les fractions de composants du debit Download PDF

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Publication number
WO2006062856A1
WO2006062856A1 PCT/US2005/043791 US2005043791W WO2006062856A1 WO 2006062856 A1 WO2006062856 A1 WO 2006062856A1 US 2005043791 W US2005043791 W US 2005043791W WO 2006062856 A1 WO2006062856 A1 WO 2006062856A1
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WO
WIPO (PCT)
Prior art keywords
flow
fraction
gas
meter
oil
Prior art date
Application number
PCT/US2005/043791
Other languages
English (en)
Inventor
Andrew Timothy Patten
Mark James Bell
Graeme Ralph Duffill
Original Assignee
Micro Motion, Inc.
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
Application filed by Micro Motion, Inc. filed Critical Micro Motion, Inc.
Publication of WO2006062856A1 publication Critical patent/WO2006062856A1/fr

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Classifications

    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01F—MEASURING VOLUME, VOLUME FLOW, MASS FLOW OR LIQUID LEVEL; METERING BY VOLUME
    • G01F15/00—Details of, or accessories for, apparatus of groups G01F1/00 - G01F13/00 insofar as such details or appliances are not adapted to particular types of such apparatus
    • G01F15/02—Compensating or correcting for variations in pressure, density or temperature
    • G01F15/022—Compensating or correcting for variations in pressure, density or temperature using electrical means
    • G01F15/024—Compensating or correcting for variations in pressure, density or temperature using electrical means involving digital counting
    • 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
    • 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
    • G01F1/76—Devices for measuring mass flow of a fluid or a fluent solid material
    • G01F1/78—Direct mass flowmeters
    • G01F1/80—Direct mass flowmeters operating by measuring pressure, force, momentum, or frequency of a fluid flow to which a rotational movement has been imparted
    • G01F1/84—Coriolis or gyroscopic mass flowmeters
    • G01F1/8409—Coriolis or gyroscopic mass flowmeters constructional details
    • G01F1/8413—Coriolis or gyroscopic mass flowmeters constructional details means for influencing the flowmeter's motional or vibrational behaviour, e.g., conduit support or fixing means, or conduit attachments
    • 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
    • G01F1/76—Devices for measuring mass flow of a fluid or a fluent solid material
    • G01F1/78—Direct mass flowmeters
    • G01F1/80—Direct mass flowmeters operating by measuring pressure, force, momentum, or frequency of a fluid flow to which a rotational movement has been imparted
    • G01F1/84—Coriolis or gyroscopic mass flowmeters
    • G01F1/8409—Coriolis or gyroscopic mass flowmeters constructional details
    • G01F1/8436—Coriolis or gyroscopic mass flowmeters constructional details signal processing
    • 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
    • G01F1/76—Devices for measuring mass flow of a fluid or a fluent solid material
    • G01F1/78—Direct mass flowmeters
    • G01F1/80—Direct mass flowmeters operating by measuring pressure, force, momentum, or frequency of a fluid flow to which a rotational movement has been imparted
    • G01F1/84—Coriolis or gyroscopic mass flowmeters
    • G01F1/845—Coriolis or gyroscopic mass flowmeters arrangements of measuring means, e.g., of measuring conduits
    • G01F1/8468—Coriolis or gyroscopic mass flowmeters arrangements of measuring means, e.g., of measuring conduits vibrating measuring conduits
    • G01F1/8472—Coriolis or gyroscopic mass flowmeters arrangements of measuring means, e.g., of measuring conduits vibrating measuring conduits having curved measuring conduits, i.e. whereby the measuring conduits' curved center line lies within a plane
    • G01F1/8477—Coriolis or gyroscopic mass flowmeters arrangements of measuring means, e.g., of measuring conduits vibrating measuring conduits having curved measuring conduits, i.e. whereby the measuring conduits' curved center line lies within a plane with multiple measuring conduits
    • 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
    • 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
    • G01N29/22—Details, e.g. general constructional or apparatus details
    • G01N29/222—Constructional or flow details for analysing fluids
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N9/00—Investigating density or specific gravity of materials; Analysing materials by determining density or specific gravity
    • G01N9/002—Investigating density or specific gravity of materials; Analysing materials by determining density or specific gravity using variation of the resonant frequency of an element vibrating in contact with the material submitted to analysis
    • G01N2009/006—Investigating density or specific gravity of materials; Analysing materials by determining density or specific gravity using variation of the resonant frequency of an element vibrating in contact with the material submitted to analysis vibrating tube, tuning fork
    • 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

Definitions

  • the present invention relates to a multi-phase flow meter system and methods for determining flow component fractions in a multi-phase flow meter system.
  • Coriolis mass flow meters to measure mass flow and other information of materials flowing through a pipeline as disclosed in U.S. Patent No. 4,491,025 issued to J.E. Smith, et al. of January 1, 1985 and Re. 31,450 to J.E. Smith of February 11, 1982.
  • These flow meters have one or more flow tubes of different configurations.
  • Each conduit configuration may be viewed as having a set of natural vibration modes including, for example, simple bending, torsional, radial and coupled modes.
  • a conduit configuration is excited in one or more vibration modes as a material flows through the conduit, and motion of the conduit is measured at points spaced along the conduit.
  • the vibrational modes of the material filled systems are defined in part by the combined mass of the flow tubes and the material within the flow tubes. Material flows into the flow meter from a connected pipeline on the inlet side of the flow meter. The material is then directed through the flow tube or flow tubes and exits the flow meter to a pipeline connected on the outlet side.
  • a driver applies a force to the flow tube.
  • the force causes the flow tube to oscillate.
  • all points along a flow tube oscillate with an identical phase.
  • Coriolis accelerations cause each point along the flow tube to have a different phase with respect to other points along the flow tube.
  • the phase on the inlet side of the flow tube lags the driver, while the phase on the outlet side leads the driver.
  • Sensors are placed at different points on the flow tube to produce sinusoidal signals representative of the motion of the flow tube at the different points. The phase difference between the two sensor signals is proportional to the mass flow rate and density of the material flowing through the flow tube or flow tubes.
  • Flow meters are used in many density applications where the composition of the liquid product is required. Net oil measurement is one example, where the liquid contains both water and oil.
  • One area in which mass flow rate and density measurements are widely used is in oilfield production measurements, for example.
  • a mass flow meter is commonly used to measure the mass flow rate of liquid from an oil well. Preferably, oil from a well is measured as it is produced. Tracking of oil well production enables tracking of satisfactory and unsatisfactory wells and aids in decision making about drilling new wells, pumping existing wells, processing of the pumped oil, etc.
  • Net oil computers To accurately determine the amount of crude oil traveling through the pipe, well operators commonly utilize a "net oil computer" to ascertain the amount of crude oil (on a percentage and/or volumetric basis) of the total oil- water flow stream that is pumped from the well. Net oil computers often utilize density measurements in calculating the measure of crude oil. Given the large quantities of crude oil that are usually involved, any small inaccuracies in measuring density can disadvantageous ⁇ accumulate to a large error over a relatively short interval of time. Unfortunately, presently available densimeters do not provide a sufficiently accurate density reading for accurately and reliably measuring a multi-phase flow material.
  • the density of each component is known, then by accurately measuring the density of the composite mixture it is possible to determine the mass (or volume) fraction of each component can be calculated.
  • the liquid includes entrained gas (for instance a small amount of gas carry-under that has not been removed by a liquid/gas separator), then the fraction of the two liquid components can no longer be accurately and reliably determined.
  • entrained gas for instance a small amount of gas carry-under that has not been removed by a liquid/gas separator
  • the fraction of the two liquid components can no longer be accurately and reliably determined.
  • a single measurement can be used to solve an equation with one variable.
  • the gas is also in the fluid stream, there are two unknown factors but just one applicable descriptive equation, and the uncertainty cannot be resolved. Consequently, air (or other gases) entrained in the flow material can significantly alter the accuracy of the flow measurements. This is due to the compressibility of the entrained air. Liquids, such as water and oil, are substantially incompressible, while gases are substantially compressible. The ent
  • a multi-phase flow meter system is provided according to an embodiment of the invention.
  • the multi-phase flow meter system comprises a flow sensor configured to generate a flow measurement signal that indicates a density of a flow material and a gas sensor configured to generate a gas measurement signal that indicates a gas void fraction in the flow material.
  • the multi-phase flow meter system further comprises a processing system in communication with the flow sensor and the gas sensor.
  • the processing system is configured to receive the gas measurement signal from the gas sensor, receive the flow measurement signal from the flow sensor, determine a gas void fraction in the flow material from the gas measurement signal, calibrate the density using the gas void fraction in order to generate a calibrated flow liquid density, and determine at least a first flow liquid fraction and a second flow liquid fraction from the calibrated flow liquid density.
  • a multi-phase flow meter system is provided according to an embodiment of the invention.
  • the multi-phase flow meter system comprises a flow sensor configured to generate a flow measurement signal that indicates a density of a flow material and a gas sensor configured to generate a gas measurement signal that indicates a gas void fraction in the flow material.
  • the multi-phase flow meter system further comprises a processing system in communication with the flow sensor and the gas sensor.
  • the processing system is configured to receive the gas measurement signal from the gas sensor, receive the flow measurement signal from the flow sensor, determine whether gas is substantially present in the flow material, determine a gas void fraction in the flow material from the gas measurement signal if the gas is determined to be substantially present, with the flow measurement signal indicating a density of the flow material, determine at least a first flow liquid fraction and a second flow liquid fraction of the flow material using the gas void fraction and the density if the gas is determined to be substantially present in the flow material, and determine at least the first flow liquid fraction and the second flow liquid fraction of the flow material using the density if the gas is determined to not be substantially present in the flow material.
  • a method of determining flow component fractions in a multi-phase flow meter system comprises receiving a gas measurement signal from a gas sensor of the multi-phase flow meter system and receiving a flow measurement signal from a flow sensor of the multi-phase flow meter system.
  • the flow measurement signal indicates a density of the flow material.
  • the method further comprises determining a gas void fraction in the flow material from the gas measurement signal, calibrating the density using the gas void fraction in order to generate a calibrated flow liquid density, and determining at least a first flow liquid fraction and a second flow liquid fraction from the calibrated flow liquid density.
  • a method of determining flow component fractions in a multi-phase flow meter system comprises receiving a gas measurement signal from a gas sensor of the multi-phase flow meter system and receiving a flow measurement signal from a flow sensor of the multi-phase flow meter system.
  • the flow measurement signal indicates a density of the flow material.
  • the method further comprises determining whether gas is substantially present in a flow material and determining a gas void fraction in the flow material from the gas measurement signal if the gas is determined to be substantially present.
  • the method further comprises determining at least a first flow liquid fraction and a second flow liquid fraction of the flow material using the gas void fraction and the density if the gas is determined to be substantially present in the flow material.
  • the method further comprises determining at least the first flow liquid fraction and the second flow liquid fraction of the flow material using the density if the gas is determined to not be substantially present in the flow material.
  • the gas sensor comprises a speed of sound measurement device.
  • the gas sensor comprises a differential gas pressure measurement device.
  • the flow sensor comprising a Coriolis flow meter in series with a water cut meter.
  • the first flow liquid fraction comprises an oil fraction and the second flow liquid fraction comprises a water fraction.
  • the first flow liquid fraction comprises an oil fraction and the second flow liquid fraction comprises a water fraction and wherein the flow sensor comprises a Coriolis flow meter in series with a water cut meter, and with the processing system being further configured to determine if the water fraction of the flow material is larger than the oil fraction, calibrate a water cut flow measurement from the water cut meter using the gas void fraction and generate a net oil flow measurement from the water cut flow measurement if the water fraction is greater than the oil fraction, and calibrate a Coriolis flow measurement from the Coriolis flow meter using the gas void fraction and generate the net oil flow measurement from the Coriolis flow measurement if the water fraction is less than the oil fraction.
  • the first flow liquid fraction comprises an oil fraction and the second flow liquid fraction comprises a water fraction and wherein the flow sensor comprises a Coriolis flow meter in series with a water cut meter, and with the determining at least the first flow liquid fraction and the second flow liquid fraction further comprising determining if the water fraction of the flow material is larger than the oil fraction, generating a water cut flow measurement from the water cut meter using the gas void fraction and generating a net oil flow measurement from the water cut flow measurement if the water fraction is greater than the oil fraction, and generating the net oil flow measurement from the Coriolis flow meter using the gas void fraction if the water fraction is less than the oil fraction.
  • the first flow liquid fraction comprises an oil fraction and with the second flow liquid fraction comprising a water fraction.
  • determining whether the gas is substantially present comprises determining a speed of sound in the flow material. In yet another aspect, determining whether the gas is substantially present comprises determining a speed of sound in the flow material and with the speed of sound being used to determine a gas void fraction.
  • measuring the density of the flow material comprises using a flow meter to measure the density. In yet another aspect, measuring the density of the flow material comprises using a Coriolis flow meter to measure the density.
  • the flow sensor comprises a Coriolis flow meter in series with a water cut meter.
  • the first flow liquid fraction comprises an oil fraction and the second flow liquid fraction comprises a water fraction and wherein the flow sensor comprises a Coriolis flow meter in series with a water cut meter.
  • the calibrating further comprises determining if the water fraction of the flow material is larger than the oil fraction, calibrating a water cut flow measurement from the water cut meter using the gas void fraction and generating a net oil flow measurement from the water cut flow measurement if the water fraction is greater than the oil fraction, and calibrating a
  • the first flow liquid fraction comprises an oil fraction and the second flow liquid fraction comprises a water fraction and wherein the flow sensor comprises a Coriolis flow meter in series with a water cut meter.
  • the determining at least the first flow liquid fraction and the second flow liquid fraction further comprises determining if the water fraction of the flow material is larger than the oil fraction, generating a water cut flow measurement from the water cut meter using the gas void fraction and generating a net oil flow measurement from the water cut flow measurement if the water fraction is greater than the oil fraction, and generating the net oil flow measurement from the Coriolis flow meter using the gas void fraction if the water fraction is less than the oil fraction.
  • FIG. 1 illustrates a Coriolis flow meter in an example of the invention
  • FIG. 2 shows a multi-phase flow meter system according to an embodiment of the invention.
  • FIG. 3 is a graph showing the relationship between the speed of sound and the void fraction of air in water.
  • FIG. 4 is a flowchart of a method of determining flow components in a multiphase flow meter system according to an embodiment of the invention.
  • FIG. 5 is a flowchart of a method of determining flow components in a multiphase flow meter system according to an embodiment of the invention.
  • FIGS. 1-5 and the following description depict specific examples to teach those skilled in the art how to make and use the best mode of the invention. For the purpose of teaching inventive principles, some conventional aspects have been simplified or omitted. Those skilled in the art will appreciate variations from these examples that fall within the scope of the invention. The examples below have been expressed using two modes for brevity. It is to be understood that more than two modes can be used. Those skilled in the art will appreciate that the features described below can be combined in various ways to form multiple variations of the invention. As a result, the invention is not limited to the specific examples described below, but only by the claims and their equivalents.
  • FIG. 1 shows a Coriolis flow meter 5 comprising a meter assembly 10 and meter electronics 20.
  • Meter assembly 10 responds to mass flow rate and density of a process material.
  • Meter electronics 20 is connected to meter assembly 10 via leads 100 to provide density, mass flow rate, and temperature information over path 26, as well as other information not relevant to the present invention.
  • a Coriolis flow meter structure is described although it is apparent to those skilled in the art that the present invention could be practiced as a vibrating tube densitometer without the additional measurement capability provided by a Coriolis mass flow meter.
  • Meter assembly 10 includes a pair of manifolds 150 and 150', flanges 103 and 103' having flange necks 110 and 110', a pair of parallel flow tubes 130 and 130', drive mechanism 180, temperature sensor 190, and a pair of velocity sensors 170L and 170R.
  • Flow tubes 130 and 130' have two essentially straight inlet legs 131 and 131' and outlet legs 134 and 134' which converge towards each other at flow tube mounting blocks 120 and 120'.
  • Flow tubes 130 and 130' bend at two symmetrical locations along their length and are essentially parallel throughout their length.
  • Brace bars 140 and 140' serve to define the axis W and W about which each flow tube oscillates.
  • the side legs 131, 131' and 134, 134' of flow tubes 130 and 130' are fixedly attached to flow tube mounting blocks 120 and 120' and these blocks, in turn, are fixedly attached to manifolds 150 and 150'. This provides a continuous closed material path through Coriolis meter assembly 10.
  • Flow tubes 130 and 130' are selected and appropriately mounted to the flow tube mounting blocks 120 and 120' so as to have substantially the same mass distribution, moments of inertia and Young's modulus about bending axes W-W and W-- W', respectively. These bending axes go through brace bars 140 and 140'.
  • resistive temperature detector (RTD) 190 is mounted to flow tube 130', to continuously measure the temperature of the flow tube.
  • the temperature of the flow tube and hence the voltage appearing across the RTD for a given current passing therethrough is governed by the temperature of the material passing through the flow tube.
  • the temperature dependent voltage appearing across the RTD is used in a well known method by meter electronics 20 to compensate for the change in elastic modulus of flow tubes 130 and 130' due to any changes in flow tube temperature.
  • the RTD is connected to meter electronics 20 by lead 195.
  • Both flow tubes 130 and 130' are driven by driver 180 in opposite directions about their respective bending axes W and W and at what is termed the first out-of- phase bending mode of the flow meter.
  • This drive mechanism 180 may comprise any one of many well known arrangements, such as a magnet mounted to flow tube 130' and an opposing coil mounted to flow tube 130 and through which an alternating current is passed for vibrating both flow tubes.
  • a suitable drive signal is applied by meter electronics 20, via lead 185, to drive mechanism 180.
  • Meter electronics 20 receives the RTD temperature signal on lead 195, and the left and right velocity signals appearing on leads 165L and 165R, respectively.
  • Meter electronics 20 produces the drive signal appearing on lead 185 to drive element 180 and vibrate tubes 130 and 130'.
  • Meter electronics 20 processes the left and right velocity signals and the RTD signal to compute the mass flow rate and the density of the material passing through meter assembly 10. This information, along with other information, is applied by meter electronics 20 over path 26 to utilization means 29.
  • FIG. 2 shows a multi-phase flow meter system 200 according to an embodiment of the invention.
  • the multi-phase flow meter system 200 can be used to measure multiphase flows that include entrained gas.
  • the multi-phase flows can include liquid/liquid flow fractions plus gas or liquid/solid flow fractions plus gas.
  • the multi-phase flow meter system 200 in one embodiment comprises a net oil computer.
  • the multi-phase flow meter system 200 includes a conduit 202, a flow sensor 210, a gas sensor 220, and a processing system 230.
  • the processing system 203 is coupled to the flow sensor 210 and the gas sensor 220.
  • the multi-phase flow meter system 200 can include additional components not shown in the figure, such as a communication interface, wherein the multi-phase flow meter system 200 can communicate with other devices, such as over a wire or wireless link, for example.
  • the multi-phase flow meter system 200 includes the meter electronics 20 of FIG. 1.
  • the flow sensor 210 generates a flow measurement signal, such as a flow measurement signal that indicates a density, among other things.
  • the flow measurement signal is generated for the entire flow material passing through the multiphase flow meter system 200, and can include at least an air component and two or more liquid components.
  • the flow material can include an oil flow that includes varying amounts of water and air, among other things.
  • the flow measurement signal is received in the processing system 230.
  • the flow sensor 210 can comprise any manner of sensor for measuring a flow of a flow material in the conduit 202.
  • the flow sensor 210 can comprise a flow meter.
  • the flow sensor can comprise a Coriolis flow meter.
  • the flow sensor 210 comprises a Coriolis flow meter in series with a water cut meter.
  • other flow sensors are contemplated and are within the scope of the description and claims.
  • the gas sensor 220 generates a gas measurement signal.
  • the gas measurement signal indicates a presence of gas in the flow material.
  • the gas measurement signal can further indicate a gas void fraction amount that is present in the flow material, i.e., the percentage of the flow material that comprises gas.
  • the gas measurement signal is received in the processing system 230.
  • the gas sensor 220 can comprise any manner of sensor for detecting and/or measuring gas in the flow material.
  • the gas sensor 220 comprises a speed of sound instrument that measures a speed of sound in the flow material in the conduit 202.
  • the speed of sound measurement can be used to determine the presence of air in the flow material.
  • the speed of sound measurement can be used to determine the gas void fraction.
  • the resonant acoustic frequency decreases rapidly with increased levels of entrained air (see FIG. 3 and discussion below).
  • the amount of compression of the gas ⁇ i.e., the gas pressure) does not need to be known.
  • the gas sensor 220 comprises a differential pressure sensor, wherein the flow material is passed through some manner of flow restrictor and pressures of the flow material upstream and downstream of the flow restrictor are measured.
  • a differential pressure sensor wherein the flow material is passed through some manner of flow restrictor and pressures of the flow material upstream and downstream of the flow restrictor are measured.
  • other gas sensors are contemplated and are within the scope of the description and claims.
  • the flow sensor 210 and the gas sensor 220 comprise integral components of the multi-phase flow meter system 200.
  • one or both can be external to the multi-phase flow meter system 200 and the multi-phase flow meter system 200 can receive the flow measurement signal and the gas measurement signal.
  • the processing system 230 conducts operations of the multi-phase flow meter system 200 and executes a net fractions routine 232 in order to determine a net oil amount in the flow material.
  • the processing system 230 can comprise a general purpose computer, a microprocessing system, a logic circuit, or some other general purpose or customized processing device.
  • the processing system 230 can be distributed among multiple processing devices.
  • the processing system 230 can include any manner of integral or independent electronic storage medium, such as the storage system 231.
  • the storage system 231 stores the net fractions routine 232, a gas detection routine 233, a gas void fraction routine 234, a density routine 235, a liquid fraction routine 236, and a flow routine 237.
  • the processing system 230 uses both the flow measurement signal and the gas measurement signal in order to generate mass flow measurements for the liquid fractions in the flow material.
  • the processing system 230 can use both the flow measurement signal and the gas measurement signal in order to generate a net oil mass flow measurement for an oil fraction in the flow material.
  • the processing system 230 uses the gas measurement signal to determine an amount of entrained gas in the flow material and subsequently calibrate the mass flow measurements. This is done because it is known that entrained air (or other gases in the flow material) can significantly alter the accuracy of the flow measurements. This is due to the compressibility of the entrained air. Liquids, such as water and oil, are substantially incompressible, while gases are substantially compressible.
  • the net fractions routine 232 can conduct operations of the multi-phase flow meter system 200 and can receive and process signals for the flow sensor 210 and the gas sensor 220 in order to determine a net oil flow through the conduit 202.
  • the net fractions routine 232 can receive data, execute other routines, and produce a final result, including a net oil mass flow rate representative of a mass flow of oil through the conduit 202.
  • the net fractions routine 232 can produce other measurements, including a calibrated density value for the flow material.
  • the net fractions routine 232 can use a reverse API calculation technique for determining the flow liquid fractions after the gas void fraction is known.
  • the gas detection routine 233 receives and processes the gas measurement signal in order to determine the presence of gas in the flow material. In one embodiment, the gas measurement signal is compared to some manner of threshold or criteria in order to determine if gas is substantially present in the flow material. The gas detection routine 233 generates a gas presence signal that indicates when gas is substantially present.
  • the gas void fraction routine 234 can also receive and process the gas measurement signal in order to quantify the gas void fraction. In one embodiment, the gas void fraction routine 234 automatically determines the gas void fraction.
  • the gas void fraction routine 234 only determines the gas void fraction if the gas detection routine 233 indicates a substantial presence of gas.
  • the gas void fraction routine 234 generates a gas void fraction amount that can be used by any of the other routines of the multi-phase flow meter system 200.
  • the density routine 235 generates a density of the flow material.
  • An initial density value can be produced that may include uncertainty due to an unknown gas void fraction in the flow material.
  • the initial density value can be calibrated by determining a gas void fraction in the flow material, wherein the density can be calibrated by removing or compensating for the gas void fraction.
  • the calibrated density comprises a density value that includes densities of at least a first flow liquid fraction and a second flow liquid fraction, such as water and oil fractions, for example.
  • the calibrated density value is more accurate and reliable than a density value that is not calibrated for a gas void fraction.
  • the calibrated density value can be used to determine the first and second flow liquid fractions for oil and water, given the known densities of both oil and water.
  • the liquid fraction routine 236 receives the calibrated density. As described above, the liquid fraction routine 236 can use the calibrated density in order to determine at least the first and second flow liquid fractions.
  • the flow routine 237 receives the first and second flow liquid fractions.
  • the flow routine 237 uses the first and second flow liquid fractions to calculate a mass flow rate of at least one of the flow liquid fractions.
  • the flow routine 237 uses the first and second flow liquid fractions in order to determine an oil mass flow rate (i.e., net oil).
  • FIG. 3 is a graph showing the relationship between the speed of sound and the void fraction of air in water.
  • the speed of sound in a fluid stream is highly dependent on the mixture of phases. The speed of sound changes dramatically over a small, low range of void fractions. As a result, a high level of measurement resolution is obtained when the void fraction of gas in the fluid is small, such as less than 5% air void fraction, for example. Therefore, a speed of sound measurement can provide an accurate and reliable measure of gas void fraction in an oil production setting, such as after a separator apparatus wherein gross amounts of air in the flow have already been removed.
  • FIG. 4 is a flowchart 400 of a method of determining flow components in a multi-phase flow meter system according to an embodiment of the invention.
  • the processing system 230 receives a gas measurement signal from a gas sensor 220 of the multi-phase flow meter system 200.
  • the gas measurement signal can indicate when gas is present in the flow material and can indicate a gas void fraction.
  • the processing system 230 receives a flow measurement signal from a flow sensor 210 of the multi-phase flow meter system 200.
  • the flow measurement signal indicates a density of the flow material.
  • the flow measurement signal can come from a flow meter or Coriolis flow meter, for example.
  • the flow sensor 210 comprises a Coriolis flow meter in series with a water cut meter.
  • the processing system 230 determines a gas void fraction in the flow material from the gas measurement signal.
  • the gas void fraction indicates an amount of gas entrained in the flow material.
  • the determining comprises determining a speed of sound of the flow material in order to determine the gas void fraction.
  • the processing system 230 calibrates the density using the gas void fraction in order to generate a calibrated flow liquid density.
  • the calibrated flow liquid density takes into account any entrained gas in the flow material.
  • the processing system 230 determines at least a first flow liquid fraction and a second flow liquid fraction from the calibrated flow liquid density.
  • the first flow liquid fraction comprises an oil fraction and the second flow liquid fraction comprises a water fraction.
  • step 406 where the flow sensor 210 comprises a Coriolis flow meter in series with a water cut meter, the processing system 230 determines whether the water fraction is greater than the oil fraction. Because the water cut meter is more accurate for a mass flow measurement when the water fraction is greater and the Coriolis flow meter is more accurate for a mass flow measurement when the oil fraction is greater, the resulting net oil measurement can be improved by selection of one of the two meters. If the water fraction is greater, the method branches to step 407; otherwise, the method branches to step 408.
  • step 407 the water fraction is greater than the oil fraction, and therefore the processing system 230 determines the oil fraction from the water fraction. Because the water cut meter is more accurate when measuring a flow of mostly water than a Coriolis flow meter when measuring the same flow of mostly water, a net oil flow measurement is generated from the water cut flow measurement.
  • FIG. 5 is a flowchart 500 of a method of determining flow components in a multi -phase flow meter system according to an embodiment of the invention.
  • the multi-phase flow meter system 200 receives a gas measurement signal, as previously discussed.
  • step 502 the multi-phase flow meter system 200 receives a flow measurement signal from the flow sensor 210, as previously discussed.
  • step 503 the multi -phase flow meter system 200 determines whether gas is substantially present in the flow material. The determination is performed using the gas measurement signal, as previously discussed. If gas is not substantially present, the method branches to step 504; otherwise, the method branches to step 505.
  • step 504 gas is not substantially present, and the processing system 230 determines flow liquid fractions using the density value obtained from the flow measurement signal.
  • the flow liquid fractions can comprise a water fraction and an oil fraction.
  • the gas in the flow material is minimal or non-existent, and is disregarded in the flow calculations.
  • step 505 the multi-phase flow meter system 200 determines a gas void fraction in the flow material from the gas measurement signal (gas has been determined to be substantially present).
  • the multi-phase flow meter system 200 determines flow liquid fractions using the gas void fraction and the density.
  • the gas void fraction is used to calibrate the density, wherein entrained gas in the flow material is accounted for by the gas void fraction.
  • the multi -phase flow meter system and method of determining flow components according the invention can be implemented according to any of the embodiments in order to obtain several advantages, if desired.
  • the invention can provide a more accurate and reliable multi-phase flow meter system.
  • the invention can provide a multi-phase flow meter system that provides accurate net fractions measurement even in the presence of entrained gas.
  • the invention can provide a multi-phase flow meter system that provides an accurate net oil measurement even in the presence of entrained gas.
  • the invention can provide a multi-phase flow meter system that provides an accurate net fractions measurement even in the presence of varying volumes of entrained gas.
  • the invention can provide a multi-phase flow meter system that provides accurate net fractions measurement even in the presence of varying pressures of entrained gas.
  • the invention can provide a density that is calibrated by determining a gas void fraction in the flow material.
  • the calibrated density comprises a density value that includes densities of at least a first flow liquid fraction and a second flow liquid fraction, such as water and oil fractions, for example.
  • the calibrated density value is more accurate and reliable than a density value that is not calibrated for a gas void fraction.
  • the calibrated density value can be used to determine the first and second flow liquid fractions for oil and water, given the known densities of both oil and water.

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  • General Physics & Mathematics (AREA)
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Abstract

Dans un premier mode de réalisation, l'invention concerne un système (200) détecteur de débit multi-phases. Le système (200) comprend un détecteur de débit (210) configuré pour produire un signal de détection de débit qui indique la densité d'un matériau qui s'écoule et un détecteur de gaz (220) configuré pour produire un signal de détection de gaz qui indique une fraction de vide gazeux. Ledit système (200) comprend, de plus, un système de traitement (230) configuré pour recevoir le signal de détection de gaz, recevoir le signal de détection de débit, déterminer une fraction de vide gazeux dans le matériau qui s'écoule à partir du signal de détection de gaz, calibrer la densité au moyen de la fraction de vide gazeux, ce qui permet la production d'une densité de liquide du flux, et déterminer au moins une première fraction de liquide et une seconde fraction de liquide à partir de la densité du liquide calibrée.
PCT/US2005/043791 2004-12-09 2005-12-05 Systeme detecteur de debit multi-phase et procede pour determiner les fractions de composants du debit WO2006062856A1 (fr)

Applications Claiming Priority (2)

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US63447304P 2004-12-09 2004-12-09
US60/634,473 2004-12-09

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Cited By (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
DE102008050113A1 (de) 2008-10-06 2010-04-08 Endress + Hauser Flowtec Ag In-Line-Meßgerät
DE102008050115A1 (de) 2008-10-06 2010-04-08 Endress + Hauser Flowtec Ag In-Line-Meßgerät
DE102008050116A1 (de) 2008-10-06 2010-04-08 Endress + Hauser Flowtec Ag In-Line-Meßgerät
JP2018507414A (ja) * 2015-03-04 2018-03-15 マイクロ モーション インコーポレイテッド 流量計の測定信頼度を決定するデバイス及び方法

Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5259250A (en) * 1990-05-14 1993-11-09 Atlantic Richfield Company Multi-phase fluid flow mesurement
WO2004072588A2 (fr) * 2003-02-10 2004-08-26 Invensys Systems, Inc. Fluxmetre de coriolis multiphase
WO2005010470A2 (fr) * 2003-07-15 2005-02-03 Cidra Corporation Appareil et procede pour compenser un appareil de mesure a effet coriolis
WO2005116637A2 (fr) * 2004-05-17 2005-12-08 Cidra Corporation Appareil et procede pour mesurer les parametres de composition d'un melange

Patent Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5259250A (en) * 1990-05-14 1993-11-09 Atlantic Richfield Company Multi-phase fluid flow mesurement
WO2004072588A2 (fr) * 2003-02-10 2004-08-26 Invensys Systems, Inc. Fluxmetre de coriolis multiphase
WO2005010470A2 (fr) * 2003-07-15 2005-02-03 Cidra Corporation Appareil et procede pour compenser un appareil de mesure a effet coriolis
WO2005116637A2 (fr) * 2004-05-17 2005-12-08 Cidra Corporation Appareil et procede pour mesurer les parametres de composition d'un melange

Cited By (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
DE102008050113A1 (de) 2008-10-06 2010-04-08 Endress + Hauser Flowtec Ag In-Line-Meßgerät
DE102008050115A1 (de) 2008-10-06 2010-04-08 Endress + Hauser Flowtec Ag In-Line-Meßgerät
DE102008050116A1 (de) 2008-10-06 2010-04-08 Endress + Hauser Flowtec Ag In-Line-Meßgerät
JP2018507414A (ja) * 2015-03-04 2018-03-15 マイクロ モーション インコーポレイテッド 流量計の測定信頼度を決定するデバイス及び方法

Also Published As

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