CA2103254C - Apparatus and method for measuring two or three phase fluid flow utilizing one or more momentum flow meters and a volumetric flow meter - Google Patents
Apparatus and method for measuring two or three phase fluid flow utilizing one or more momentum flow meters and a volumetric flow meterInfo
- Publication number
- CA2103254C CA2103254C CA002103254A CA2103254A CA2103254C CA 2103254 C CA2103254 C CA 2103254C CA 002103254 A CA002103254 A CA 002103254A CA 2103254 A CA2103254 A CA 2103254A CA 2103254 C CA2103254 C CA 2103254C
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- flow
- pressure drop
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- gas
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- 238000000034 method Methods 0.000 title claims abstract description 38
- 239000012530 fluid Substances 0.000 title claims description 38
- 239000007788 liquid Substances 0.000 claims abstract description 62
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 42
- 230000004907 flux Effects 0.000 claims abstract description 11
- 238000009530 blood pressure measurement Methods 0.000 claims abstract description 4
- 239000000203 mixture Substances 0.000 claims description 12
- 230000006870 function Effects 0.000 claims description 7
- 238000006073 displacement reaction Methods 0.000 claims description 6
- 230000003068 static effect Effects 0.000 claims description 6
- 239000000470 constituent Substances 0.000 claims 24
- 239000007789 gas Substances 0.000 abstract description 33
- 239000003921 oil Substances 0.000 abstract description 11
- 239000012071 phase Substances 0.000 description 29
- 238000005259 measurement Methods 0.000 description 16
- 230000005514 two-phase flow Effects 0.000 description 11
- 238000004458 analytical method Methods 0.000 description 4
- 238000010586 diagram Methods 0.000 description 4
- 239000011800 void material Substances 0.000 description 4
- 230000008901 benefit Effects 0.000 description 3
- 230000008569 process Effects 0.000 description 3
- 230000008859 change Effects 0.000 description 2
- 230000000694 effects Effects 0.000 description 2
- 239000007791 liquid phase Substances 0.000 description 2
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 238000005086 pumping Methods 0.000 description 2
- 239000000126 substance Substances 0.000 description 2
- 230000003466 anti-cipated effect Effects 0.000 description 1
- 238000013459 approach Methods 0.000 description 1
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- 238000013461 design Methods 0.000 description 1
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- SYOKIDBDQMKNDQ-XWTIBIIYSA-N vildagliptin Chemical compound C1C(O)(C2)CC(C3)CC1CC32NCC(=O)N1CCC[C@H]1C#N SYOKIDBDQMKNDQ-XWTIBIIYSA-N 0.000 description 1
Classifications
-
- 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
- G01F1/05—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 using mechanical effects
- G01F1/34—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 using mechanical effects by measuring pressure or differential pressure
- G01F1/36—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 using mechanical effects by measuring pressure or differential pressure the pressure or differential pressure being created by the use of flow constriction
-
- 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
Abstract
An apparatus and method for measuring the flow rates of each component of two-phase now consisting of a gas and a liquid or three-phase flow consisting of water, oil and gas, including a first volumetric flow meter stage, and second and third momentum flow meter stages coupled in a series flow path with the volumetric flow meter stage and in which a velocity ratio between the gas and the liquid in the series flow path is maintained to be one. A processor calculates flow rates of the components of flow by solving volumetric flow and momentum or energy equations defining flow through the first through third stages utilizing a volumetric flow output from the first stage and momentum flux outputs from said second and third stages, and an indicator displays flow of liquid and gas or oil, water and gas components of the flow. To measure three-phase flow, a water-cut meter is provided to determine the amount of water flow, which is then used by the processor to determine the flow of the rest of the liquid. The second and third momentum flow meter stages can be implemented by two separate momentum flow meters or by a single momentum flow meter, such as a venturi flow meter having a venturi nozzle including pressure taps for obtaining at least two differential pressure measurements. In the event that the density or the liquid component is known, a single momentum flow meter stage is sufficient.
Description
WO93/19~7 PCT/GB93/00516 210325~
TITLE OF THE INVENTION
APPARATUS AND METHOD FOR MEASURING TWO- OR THREE-PHASE FLUID FLOW UTILIZING ONE OR MORE MOMENTUM
FLOW METERS AND A VOLUMETRIC FLOW METER
BACKGROUND OF THE INVENTION
Field of the Invention This invention relates to an apparatus and method for measuring two-phase flow (liquid/gas) or three-phase flow (liquid/liquid/gas) of fluids.
Discussion of Backqround The measurement of oil, water and gas flow finds application in various fields. In oil production, it is required for reservoir control and fiscal reasons. High accuracy of measurement is necessary as well as small instrumentation space requirements. Additional applications exist in petrochemical, nuclear and other industries.
In the past, three principal methods have been utilized for flow measurements.
As disclosed in U.S. Patent 4,760,742, the gas in a liquid is physically separated from-the liquid, and each fluid is measured separately. A water-cut monitor is used to measure the amount of the water and the oil in the liquid phase. Two conventional single-phase flow meters are used to measure the gas and the liauid flow rates. This method can ~UB!~ UTE SHE:ET
W093/19~7 PCT/GB93/~516 21 0325~ -2-yield high accuracy, but requires gas-separating devices which are either very large or are very sensitive to flow rates and the liquid's viscosity, surface tension, etc.
A second approach is described in U.S. Patents 4,168,624 and 4,050,896, wherein the total- flow is measured at two different flow conditions (for example: different temperatures and different pressures along the pipeline). The changing of the gas volume during the change of this condition makes it possible to calculate the flow rates of the gas and the liquid. To achieve high accuracy in this method, a large difference in flow conditions between the two flow meters is required. This requires a large pressure drop, which is costly in terms of pumping energy.
A third techni~ue as described by Baker, "Measuring Multi-Phase Flow", Chemical Enqineer, No. 453, pp. 39-45, October, 1988, and Reimann et al, "Measurement of Two-Phase Mass Flow Rate: A Comparison of Different Techniques", Int.
J. of Multi-Phase Flows, Vol. 8, No. l, pp. 33-46, 1982, measures the total momentum flux, total density, total volumetric flow rate, and the water cut. All are required to calculate the amount of gas, oil and water. One such device uses the combination of a turbine flow meter, a venturi flow meter, a gamma ray densitometer or void fraction meter and a water-cut monitor. The advantage of this method is that it enables the use of venturies which have low pressure drops.
The weak link in this technique is the densitometer, which is W093/19~7 PCT/GB93/~516 - ", 2la32s~
sensitive to the flow characteristics and the fluid's contaminants (heavy metals, etc.).
In many multi-phase flow applications it is desirable to predict the pressure drops which will occur in various piping apparata with different combinations of multi-phase fluids.
This information is critical to piping design, pump sizing, etc. While information has been compiled on the pressure drops of a two-phase fluid comprising of water and air, it has not been possible to predict the pressure drops for other, more unique multi-phase fluids.
SUMMARY OF THE INVENTION
Accordingly, one object of the invention is to provide a new and improved apparatus and method for measuring multi-phase flow by means of simple, low cost, compact equipment which has high flow rate measuring accuracy.
Another object is to provide a novel apparatus and method for measuring multi-phase flow and which entails small pressure drops and therefore requires little pumping energy.
Yet a further object is to provide a novel apparatus and method as above noted, which does not need gas separating devices or densitometers or measurement of a void fraction to perform the flow measurement.
Still a further object of this invention is to provide a novel apparatus and method capable of developing a table W093/19~7 PCT/GB93/~516 2 1 ~ 4 predicting the pressure drops which will occur in piplng apparata for different multi-phase fluids.
These and other objects are achieved according to the present invention by providing a novel apparatus for measuring the flow rates of each component-~f two-phase flow consisting of a gas and a liquid, including a first volumetric flow meter stage, second and third momentum flow meter stages coupled in a series flow path with the volumetric flow meter stage, wherein a velocity ratio between the gas and the liquid in the series flow path is maintained at a known value, e.g., one, and a processor for calculating flow rates of the components of flow by solving volumetric flow and momentum or energy equations defining flow through the first through third stages utilizing a volumetric flow output from the first stage and momentum flux outputs from said second and third stages, and an indicator for displaying flow rates of the liquid and gas components of the two-phase flow.
The second and third momentum flow meter stages can be implemented by two separate momentum flow meters or by a single momentum flow meter having a venturi nozzle including at least three pressure taps for obtaining at least two differential pressure measurements. In the event that the density of the liquid component is known, a single momentum flux measurement from a single momentum flow meter stage is sufficient to measure two-phase flow.
WO93/19~7 210 3 2 5 ~ PCT/GB93/00516 To measure three-phase (oil, water, gas) flow a water-cut meter is provided to determine the amount of water flow, which is then used by the processor to determine the amount of oil flow. The flow rates of oil, water and gas are then displayed.
To enable prediction of multi-phase fluid pressure drops in various flow apparata, a differential pressure measurement is taken across the first through third (and optionally fourth) stages, and means are provided to calculate and display ratios of the pressure drops of multi-phase fluids relative to the known pressure drops of fluids comprising water and air.
BRIEF DESCRIPTION OF THE DRAWINGS
A more complete appreciation of the invention and many of the attendant advantages thereof will be readily obtained as the same becomes better understood by reference to the following detailed description when considered in connection with the accompanying drawings, wherein:
Figure l is a block diagram of an apparatus for two-phase flow measurement according to the present invention;
Figure 2 is a schematic diagram of an apparatus for two-phase flow measurement according to the present invention, utilizing two venturi tubes and an ultra-sonic flow meter;
Figure 3 is a schematic of a preferred embodiment for measuring two-phase flow, using a combination of a single W093/19~7 PCT/GB93/~516 21032~4 ~
modified venturi meter with a positive displacement flow meter;
Figure 4 is a schematic diagram of an embodiment of the present invention for three-phase flow wlth the flow meter shown in Figure 3 and a water-cut--monitor;
~ igure 5 is a schematic diagram illustrating how the flow meter shown in Figure 4 can be used to measure the relative pressure drop of a three-phase fluid: and Figure 6 is a flow chart of the overall process of the present invention for measuring three-phase flow and determining pressure drop ratios, according to the apparata described in relation to Figs. 2-5.
DESCRIPTION OF THE PREFERRED EMBODIMENTS
Referring now to the drawings, wherein like reference numerals designate identical or corresponding parts throughout the several views, and more particularly to Figure l thereof, there is shown schematically an embodiment of the apparatus of the invention, including a volumetric flowmeter lO serving as a first stage in which a mixture of gas and liquid flows through the volumetric flow meter lO. This flow meter lO
measures the total flow rate for the mixture. The mixture then flows through second and third stages, consisting of two momentum flow meters 12 and 14 with different dimensions tfor example, two venturi flow meters with different throat diameters). Momentum flow meters are flow meters that measure WO93/19~7 PCT/GB93/00516 the momentum flux of the fluid (M = mv). In order to avoid using a void fraction meter, the present invention forces the velocity ratio between the gas and the liquid (slip ratio) inside the apparatus to be a known value, a slip ratio of one being conveniently enforced. Th-is is achieved through using either static or dynamic mixers or a positive displacement meter. In each stage the absolute pressure and temperature are measured by means of temperature transducers 16 and pressure transducers 18. one momentum flow meter can also be used by itself, in the instance that the liquid component's density is known. The data from Stages 1, 2 and 3 is transferred to a computer 20 that calculates the flow rates of the liquid and the gas components by solving equations presented hereinafter.
Figure 2 shows an example of a more concrete embodiment of the invention for two-phase flow measurement. Stage 1 is an ultra-sonic flow meter 10l installed between two static mixers 22 and 24. The ultrasonic flow meter measures volumetric flow. Other volumetric flow meters can also be used, such as turbine, vortex shedding, magnetic, heat transfer, variable area, paddle and Coriolis volumetric flow meter. In this modification the static mixers 22, 2~ are used to force a unitary velocity ratio between the phases. Instead of measuring the absolute pressure independently in each stage, the absolute pressure is measured with a pressure WO93/19~7 PCT/GB93/00516 ~, . , ~
2 1~ 3 2 5 ~ -a--transducer 18 in stage 1, and is calculated using differential pressure transducers 26 and 28 in stages 2 and 3.
The two momentum flow meters shown in Figures 1 and 2 can be reduced to one, by drilling one more pressure tap along the venturi nozzle, as shown in Figu~re 3. Such a modified venturi flowmeter is designated by numeral 31 in Fig. 3. Here the volumetric flow meter lO2 is a positive displacement (P.D.) type. The advantage of using a P.D. flow meter is that it provides an exact measurement of the sum of the liquid and gas flow rates, with no slip between the gas and liquid phases inside the meter or immediately after the meter. Thus, the P.D. flow meter forces the slip ratio to a known amount, i.e., unity, and permits dispensing with the static mixers of the Fig. 2 embodiment.
The embodiments shown in Figure 1-3 are above-descri~ed using one or two venturi-type momentum flow meters. However, it should be understood that other momentum flow meters can be used to practice the present invention. For example, a target or drag-disk-type flow meter having different paddle dimensions can also be utilized to obtain sufficient parametric data to solve the energy and momentum equations of the fluids. For more detail about particular instrumentation described herein, see Hewitt, G.F., "Measurement of Two Phase Flow Parameters", Whitstable Litho Ltd., Whitstable, Kent, Great Britain, 1978, and Holman, J.P., "Experimental Methods for Engineers", McGraw-Hill Book Company, 1978.
WO93/19~7 PCT/GB93/00516 _ G _ The differential pressure transducers 26 and 28 measure the pressure difference alcng the venturi nozzle. A three-phase flowmeter in which a mixture of oil, water and gas can be measured is constructed with the addition of a fourth stage water-cut meter. Figure ~ shows-a water-cut meter 32 (such as described in U.S. Patents 4,503,383 and 4,771,680) that measures the water concentration c of the mixture. Absolute pressure and temperature are measured in this stage by transducers 16 and 34, respectively. Reference numeral 31 designates the modified venturi flowmeter having the pressure taps 1-3 and associated transducers shown in Fig. 3. Because of the change in the specific volume of the gas (v = p/RT), measurement of the absolute pressure and temperature at all stages is necessary.
Next described is the analytical basis by which the present invention performs flow measurements utilizing momentum equations. In the following analysis, the following English and Greek letters and subscripts are used and have the noted meanings:
Enqlish letters A - cross sectional area c - percent of water d - longitude differential g - gravity constant m - total mass flux M - momentum flux WO93/19~7 PCT/GB93/00516 210 32S4 -io-p - pressure P - circumference Q - volumetric flow rate R - gas constant s - velocity ratio between the gas and the liquid t''slip~) T - absolute temperature v - specific volume x - quality Greek letters ~ - void fraction B - slope of the instrumentation p - density r - wall shear Subscripts G - gas o - oil PD - positive displacement TOTAL - sum of all the fluid components TP - two-phase W - water In performing a two-phase flow measurement, QL and QG are unknowns, but not the only unknowns.
W093/19~7 210 3 2 5 ~ PCT/GB93/~516 _l The density of the 'iquid is also unknown (other unknown ~roperties of the liquid and the gas have only a minor effect on the present method, and are therefore ignored here). The three equations that need to be solved for the three unknowns are the following:
l) The volumetric flow meter equation for stage l:
QPD Q~ + QG ( 1 ) QPD is derived from the volumetric flow meter output.
2) The momentum eouation for stage 2 (for example the venturi meter sAown in Figure 3 from tap l to tap 2):
P1 P2 f1 (QL~ Q5~ PL) (2) where p~ - P2 is the differential pressure derived from transducer 28 in Figure 3.
TITLE OF THE INVENTION
APPARATUS AND METHOD FOR MEASURING TWO- OR THREE-PHASE FLUID FLOW UTILIZING ONE OR MORE MOMENTUM
FLOW METERS AND A VOLUMETRIC FLOW METER
BACKGROUND OF THE INVENTION
Field of the Invention This invention relates to an apparatus and method for measuring two-phase flow (liquid/gas) or three-phase flow (liquid/liquid/gas) of fluids.
Discussion of Backqround The measurement of oil, water and gas flow finds application in various fields. In oil production, it is required for reservoir control and fiscal reasons. High accuracy of measurement is necessary as well as small instrumentation space requirements. Additional applications exist in petrochemical, nuclear and other industries.
In the past, three principal methods have been utilized for flow measurements.
As disclosed in U.S. Patent 4,760,742, the gas in a liquid is physically separated from-the liquid, and each fluid is measured separately. A water-cut monitor is used to measure the amount of the water and the oil in the liquid phase. Two conventional single-phase flow meters are used to measure the gas and the liauid flow rates. This method can ~UB!~ UTE SHE:ET
W093/19~7 PCT/GB93/~516 21 0325~ -2-yield high accuracy, but requires gas-separating devices which are either very large or are very sensitive to flow rates and the liquid's viscosity, surface tension, etc.
A second approach is described in U.S. Patents 4,168,624 and 4,050,896, wherein the total- flow is measured at two different flow conditions (for example: different temperatures and different pressures along the pipeline). The changing of the gas volume during the change of this condition makes it possible to calculate the flow rates of the gas and the liquid. To achieve high accuracy in this method, a large difference in flow conditions between the two flow meters is required. This requires a large pressure drop, which is costly in terms of pumping energy.
A third techni~ue as described by Baker, "Measuring Multi-Phase Flow", Chemical Enqineer, No. 453, pp. 39-45, October, 1988, and Reimann et al, "Measurement of Two-Phase Mass Flow Rate: A Comparison of Different Techniques", Int.
J. of Multi-Phase Flows, Vol. 8, No. l, pp. 33-46, 1982, measures the total momentum flux, total density, total volumetric flow rate, and the water cut. All are required to calculate the amount of gas, oil and water. One such device uses the combination of a turbine flow meter, a venturi flow meter, a gamma ray densitometer or void fraction meter and a water-cut monitor. The advantage of this method is that it enables the use of venturies which have low pressure drops.
The weak link in this technique is the densitometer, which is W093/19~7 PCT/GB93/~516 - ", 2la32s~
sensitive to the flow characteristics and the fluid's contaminants (heavy metals, etc.).
In many multi-phase flow applications it is desirable to predict the pressure drops which will occur in various piping apparata with different combinations of multi-phase fluids.
This information is critical to piping design, pump sizing, etc. While information has been compiled on the pressure drops of a two-phase fluid comprising of water and air, it has not been possible to predict the pressure drops for other, more unique multi-phase fluids.
SUMMARY OF THE INVENTION
Accordingly, one object of the invention is to provide a new and improved apparatus and method for measuring multi-phase flow by means of simple, low cost, compact equipment which has high flow rate measuring accuracy.
Another object is to provide a novel apparatus and method for measuring multi-phase flow and which entails small pressure drops and therefore requires little pumping energy.
Yet a further object is to provide a novel apparatus and method as above noted, which does not need gas separating devices or densitometers or measurement of a void fraction to perform the flow measurement.
Still a further object of this invention is to provide a novel apparatus and method capable of developing a table W093/19~7 PCT/GB93/~516 2 1 ~ 4 predicting the pressure drops which will occur in piplng apparata for different multi-phase fluids.
These and other objects are achieved according to the present invention by providing a novel apparatus for measuring the flow rates of each component-~f two-phase flow consisting of a gas and a liquid, including a first volumetric flow meter stage, second and third momentum flow meter stages coupled in a series flow path with the volumetric flow meter stage, wherein a velocity ratio between the gas and the liquid in the series flow path is maintained at a known value, e.g., one, and a processor for calculating flow rates of the components of flow by solving volumetric flow and momentum or energy equations defining flow through the first through third stages utilizing a volumetric flow output from the first stage and momentum flux outputs from said second and third stages, and an indicator for displaying flow rates of the liquid and gas components of the two-phase flow.
The second and third momentum flow meter stages can be implemented by two separate momentum flow meters or by a single momentum flow meter having a venturi nozzle including at least three pressure taps for obtaining at least two differential pressure measurements. In the event that the density of the liquid component is known, a single momentum flux measurement from a single momentum flow meter stage is sufficient to measure two-phase flow.
WO93/19~7 210 3 2 5 ~ PCT/GB93/00516 To measure three-phase (oil, water, gas) flow a water-cut meter is provided to determine the amount of water flow, which is then used by the processor to determine the amount of oil flow. The flow rates of oil, water and gas are then displayed.
To enable prediction of multi-phase fluid pressure drops in various flow apparata, a differential pressure measurement is taken across the first through third (and optionally fourth) stages, and means are provided to calculate and display ratios of the pressure drops of multi-phase fluids relative to the known pressure drops of fluids comprising water and air.
BRIEF DESCRIPTION OF THE DRAWINGS
A more complete appreciation of the invention and many of the attendant advantages thereof will be readily obtained as the same becomes better understood by reference to the following detailed description when considered in connection with the accompanying drawings, wherein:
Figure l is a block diagram of an apparatus for two-phase flow measurement according to the present invention;
Figure 2 is a schematic diagram of an apparatus for two-phase flow measurement according to the present invention, utilizing two venturi tubes and an ultra-sonic flow meter;
Figure 3 is a schematic of a preferred embodiment for measuring two-phase flow, using a combination of a single W093/19~7 PCT/GB93/~516 21032~4 ~
modified venturi meter with a positive displacement flow meter;
Figure 4 is a schematic diagram of an embodiment of the present invention for three-phase flow wlth the flow meter shown in Figure 3 and a water-cut--monitor;
~ igure 5 is a schematic diagram illustrating how the flow meter shown in Figure 4 can be used to measure the relative pressure drop of a three-phase fluid: and Figure 6 is a flow chart of the overall process of the present invention for measuring three-phase flow and determining pressure drop ratios, according to the apparata described in relation to Figs. 2-5.
DESCRIPTION OF THE PREFERRED EMBODIMENTS
Referring now to the drawings, wherein like reference numerals designate identical or corresponding parts throughout the several views, and more particularly to Figure l thereof, there is shown schematically an embodiment of the apparatus of the invention, including a volumetric flowmeter lO serving as a first stage in which a mixture of gas and liquid flows through the volumetric flow meter lO. This flow meter lO
measures the total flow rate for the mixture. The mixture then flows through second and third stages, consisting of two momentum flow meters 12 and 14 with different dimensions tfor example, two venturi flow meters with different throat diameters). Momentum flow meters are flow meters that measure WO93/19~7 PCT/GB93/00516 the momentum flux of the fluid (M = mv). In order to avoid using a void fraction meter, the present invention forces the velocity ratio between the gas and the liquid (slip ratio) inside the apparatus to be a known value, a slip ratio of one being conveniently enforced. Th-is is achieved through using either static or dynamic mixers or a positive displacement meter. In each stage the absolute pressure and temperature are measured by means of temperature transducers 16 and pressure transducers 18. one momentum flow meter can also be used by itself, in the instance that the liquid component's density is known. The data from Stages 1, 2 and 3 is transferred to a computer 20 that calculates the flow rates of the liquid and the gas components by solving equations presented hereinafter.
Figure 2 shows an example of a more concrete embodiment of the invention for two-phase flow measurement. Stage 1 is an ultra-sonic flow meter 10l installed between two static mixers 22 and 24. The ultrasonic flow meter measures volumetric flow. Other volumetric flow meters can also be used, such as turbine, vortex shedding, magnetic, heat transfer, variable area, paddle and Coriolis volumetric flow meter. In this modification the static mixers 22, 2~ are used to force a unitary velocity ratio between the phases. Instead of measuring the absolute pressure independently in each stage, the absolute pressure is measured with a pressure WO93/19~7 PCT/GB93/00516 ~, . , ~
2 1~ 3 2 5 ~ -a--transducer 18 in stage 1, and is calculated using differential pressure transducers 26 and 28 in stages 2 and 3.
The two momentum flow meters shown in Figures 1 and 2 can be reduced to one, by drilling one more pressure tap along the venturi nozzle, as shown in Figu~re 3. Such a modified venturi flowmeter is designated by numeral 31 in Fig. 3. Here the volumetric flow meter lO2 is a positive displacement (P.D.) type. The advantage of using a P.D. flow meter is that it provides an exact measurement of the sum of the liquid and gas flow rates, with no slip between the gas and liquid phases inside the meter or immediately after the meter. Thus, the P.D. flow meter forces the slip ratio to a known amount, i.e., unity, and permits dispensing with the static mixers of the Fig. 2 embodiment.
The embodiments shown in Figure 1-3 are above-descri~ed using one or two venturi-type momentum flow meters. However, it should be understood that other momentum flow meters can be used to practice the present invention. For example, a target or drag-disk-type flow meter having different paddle dimensions can also be utilized to obtain sufficient parametric data to solve the energy and momentum equations of the fluids. For more detail about particular instrumentation described herein, see Hewitt, G.F., "Measurement of Two Phase Flow Parameters", Whitstable Litho Ltd., Whitstable, Kent, Great Britain, 1978, and Holman, J.P., "Experimental Methods for Engineers", McGraw-Hill Book Company, 1978.
WO93/19~7 PCT/GB93/00516 _ G _ The differential pressure transducers 26 and 28 measure the pressure difference alcng the venturi nozzle. A three-phase flowmeter in which a mixture of oil, water and gas can be measured is constructed with the addition of a fourth stage water-cut meter. Figure ~ shows-a water-cut meter 32 (such as described in U.S. Patents 4,503,383 and 4,771,680) that measures the water concentration c of the mixture. Absolute pressure and temperature are measured in this stage by transducers 16 and 34, respectively. Reference numeral 31 designates the modified venturi flowmeter having the pressure taps 1-3 and associated transducers shown in Fig. 3. Because of the change in the specific volume of the gas (v = p/RT), measurement of the absolute pressure and temperature at all stages is necessary.
Next described is the analytical basis by which the present invention performs flow measurements utilizing momentum equations. In the following analysis, the following English and Greek letters and subscripts are used and have the noted meanings:
Enqlish letters A - cross sectional area c - percent of water d - longitude differential g - gravity constant m - total mass flux M - momentum flux WO93/19~7 PCT/GB93/00516 210 32S4 -io-p - pressure P - circumference Q - volumetric flow rate R - gas constant s - velocity ratio between the gas and the liquid t''slip~) T - absolute temperature v - specific volume x - quality Greek letters ~ - void fraction B - slope of the instrumentation p - density r - wall shear Subscripts G - gas o - oil PD - positive displacement TOTAL - sum of all the fluid components TP - two-phase W - water In performing a two-phase flow measurement, QL and QG are unknowns, but not the only unknowns.
W093/19~7 210 3 2 5 ~ PCT/GB93/~516 _l The density of the 'iquid is also unknown (other unknown ~roperties of the liquid and the gas have only a minor effect on the present method, and are therefore ignored here). The three equations that need to be solved for the three unknowns are the following:
l) The volumetric flow meter equation for stage l:
QPD Q~ + QG ( 1 ) QPD is derived from the volumetric flow meter output.
2) The momentum eouation for stage 2 (for example the venturi meter sAown in Figure 3 from tap l to tap 2):
P1 P2 f1 (QL~ Q5~ PL) (2) where p~ - P2 is the differential pressure derived from transducer 28 in Figure 3.
3) The momentum equation for stage 3 (for example the venturi meter shown in Figure 3 from tap l to tap 3):
P1 P3 f2(QL~ QG~ PL) (3) where p~ - P3 is the differential pressure derived from transducer 30 in Figure 3.
Certain assumptions must be made for the equations to be solvable:
1) The expansion of the gas along the venturi nozzle is isothermal.
2) Evaporation and dissolution of vapor and gas are negligible.
3) The ideal gas equation holds, and the liquid is incompressible.
W093/19~7 PCT/GB93/~516 21032~4 4) The velocity ratio between the gas and the liquid =
l, or can be found experimentally as a function of the liquid and the gas flow rates.
Equations 2 and 3, shown here in general form, are in fact integral equations derived from the full expression of the momentum equation (see Hetsroni, G., "Handbook of Multi-Phase Systems", Chaps. l.2, 2.l, 2.3, Hemisphere Publishing Corporation, U.S.A., 1982).
The momentum equation can be simplified to a model for one-dimensional, steady-s~ate flow based on the Separated Two-Phase Flow model (see Hetsroni, G., supra) and can integrate from the first tap of the venturi to the second tap:
P1 ~ P2 = ~(gPTpsin~ ~ + m2 d (l _ x)2 X2])d and from the first tap of the venturi to the third tap:
p - p = l(gpTpsin~ + A m az [ PL~1 ~ ~) PG~ ) In equations 4 and 5 PTP~ m, x and ~ are functions of QG~
QL and P L:
PTP = (1 ~) P~ + crpG (6) 2 ~ ~ ~ 2 ~ 4 " ,, .
Q' PL Q5PG ( 7 ) QG + SQL ( 8 ) X =QGPG
Q~ PL QGPG
Substituting equations 6, 7, 8 and 9 into equations 4 and 5, and then solving with equation 1, provides solutions for QL
QG and p~ since we have three equations and three unknowns.
Equations 4 and 5 are solved using known numerical analysis techniques. The selection of a particular numerical analysis technique is based on a trade-off between accuracy and speed of execution, and is a function also of the availability of fast and economic computation devices. The relative merits of some techniques are discussed in Scheid, "Theory and Problems of Numerical Analysis", Schaum's Outline Series, McGraw-Hill Book Co., 1968. The technique most appropriate for equations 4 and 5, today, is the Runge-Kutta method described in Chapter 19 of Scheid, supra. It is anticipated, however, that the development of cheaper and faster computation devices, or more efficient or more accurate W093/19~7 PCT/GB93/~516 ~ . _ 2103254 - ~
melhods of solving integral equations, will suggest other techniques to be utilized in the future. Similarly, a method well suited for solving the set of equations l, 4 and 5 is the Newton method described in Chapter 25 of Scheid.
More or less detailed, and different types of models can be written as well, depending on the required accuracy of the meter. Applying the momentum equations provides a much more accurate solution than the energy equations, since the momentum equations only have to take into account the friction on the wall (easy to estimate), as compared with the energy equa~ions which have to take into account the energy losses (very difficult to estimate). Generally, it is considered that the present invention utilizes conservation equations, which can be either momentum or energy equations (see Hetsroni, supra).
The equation for deriving three-phase flow (oii/water/gas) by the addition of a water-cut meter in stage - l S:
QW (10) QW -- QO t QG
The liquid flow rate is the sum of~the water and the oil flow rates:
Q- = Qo + Qu (11) Therefore, the equation for determining the water flow rate can be written as:
W093/19~7 PCT/GB93/~516 21032~
QU (Q! T QG) C ( 12 ) and then Q~ can be derived from equation 12 once Q~ s known.
Figure 5 shows how the multi-phase flow meter can also be used to predict pressure drops for different multi-phase fluids in different piping devices. The addition of differential pressure transducer (36) provides measurement of the pressure drop across the meter. In the calibration process a look-up table is generated, which contains the measured pressure drop across the meter when different proportions and rates of water and air are flowed through it.
In effect the look-up table is a matrix of values of ~P~ater/ajr for different values of Qair and Q~ater-When a multi-phase fluid consisting of different components than water and air flows through the meter, stages 1, Z and 3 measure QG and QL, while stage 5 measures the differential pressure across the meter (~PflUid)- ~he ~P~ater/air that corresponds to the equivalent air and water values for the measured QG and QL of the working fluid is then looked up in the above-noted look-up table, and the pressure drop ratio is calculated.
The equation for the pressure drop ratio of the working multi-phase fluid relative to an equivalent water/air mixture is:
= const I same f ' ow conai~ons ( 1 3 ) Once this ratio has been calculated, it can be applied to obtain an accurate prediction of the pressure drop of multi-phase fluids in other devices in the line, where the pressure drop of an equivalent water/air mixture is known.
For example, to obtain the pressure drop in a vertical pipe in a field pipe line where crude oil, water and natural gas are flowing, a priori knowledge of the pressure drop for an air/water mixture in the same vertical pipe at the same flow rate is needed. This can be found in field handbooks (see Perry et al, "Chemical Engineer's Handbook", McGraw-Hill Book Co., 1973, pp. 5.40-5.47). Multiplication of this number with the pressure drop ratio calculated according to the present invention provides an accurate prediction of the pressure drop across the vertical pipe for the working fluid.
Figure 6 shows a flow chart that summarizes the process of the present invention.
In Figure 6, in step 100, the output of the volumetric flow meter 10, QPDI iS measured. In step 110, differential pressure P1-P2~ is measured. In step 120, the differential pressure P1-P3 is measured. In step 130, the water-cut, c, is measured. The outputs of the steps 100, 110 and 120 are fed to the computer 20 which then, in step 140, calculates QLI QG
and PLI solving equations 1, 4 and 5 and utilizing equations 6-9. In step 150, Qwater and Qoil are calculated utilizing equations 10-12, and in step 160, the results of the various calculations r .~ ~
WO93/19~7 PCT/GB93/~516 ~ 2103251 performed as thus far described, QG' Q~a~er and Qoj~ are displayed.
Figure 6 also illustrates steps by which the ratio ~PfluiJ~P~ater~air is determined. In step 170, ~PflUid is measured by means of the sensor 36 shown in Figure ~. In step 180, a look-up table is utilized to determine ~P~a~er~air ~ based on the values of Q~ and Q5 determined in step 140. In step 190 the ratio of ~PflUid~ determined in step 170 and ap~ater/ajr, determined in step 180, is determined and likewise displayed in step--160.
Obviously, numerous modifications and variations of the present invention are possible in light of the above teachings. It is therefore to be understood that within the scope of the appended claims, the invention may be practiced otherwise than as specifically described herein.
P1 P3 f2(QL~ QG~ PL) (3) where p~ - P3 is the differential pressure derived from transducer 30 in Figure 3.
Certain assumptions must be made for the equations to be solvable:
1) The expansion of the gas along the venturi nozzle is isothermal.
2) Evaporation and dissolution of vapor and gas are negligible.
3) The ideal gas equation holds, and the liquid is incompressible.
W093/19~7 PCT/GB93/~516 21032~4 4) The velocity ratio between the gas and the liquid =
l, or can be found experimentally as a function of the liquid and the gas flow rates.
Equations 2 and 3, shown here in general form, are in fact integral equations derived from the full expression of the momentum equation (see Hetsroni, G., "Handbook of Multi-Phase Systems", Chaps. l.2, 2.l, 2.3, Hemisphere Publishing Corporation, U.S.A., 1982).
The momentum equation can be simplified to a model for one-dimensional, steady-s~ate flow based on the Separated Two-Phase Flow model (see Hetsroni, G., supra) and can integrate from the first tap of the venturi to the second tap:
P1 ~ P2 = ~(gPTpsin~ ~ + m2 d (l _ x)2 X2])d and from the first tap of the venturi to the third tap:
p - p = l(gpTpsin~ + A m az [ PL~1 ~ ~) PG~ ) In equations 4 and 5 PTP~ m, x and ~ are functions of QG~
QL and P L:
PTP = (1 ~) P~ + crpG (6) 2 ~ ~ ~ 2 ~ 4 " ,, .
Q' PL Q5PG ( 7 ) QG + SQL ( 8 ) X =QGPG
Q~ PL QGPG
Substituting equations 6, 7, 8 and 9 into equations 4 and 5, and then solving with equation 1, provides solutions for QL
QG and p~ since we have three equations and three unknowns.
Equations 4 and 5 are solved using known numerical analysis techniques. The selection of a particular numerical analysis technique is based on a trade-off between accuracy and speed of execution, and is a function also of the availability of fast and economic computation devices. The relative merits of some techniques are discussed in Scheid, "Theory and Problems of Numerical Analysis", Schaum's Outline Series, McGraw-Hill Book Co., 1968. The technique most appropriate for equations 4 and 5, today, is the Runge-Kutta method described in Chapter 19 of Scheid, supra. It is anticipated, however, that the development of cheaper and faster computation devices, or more efficient or more accurate W093/19~7 PCT/GB93/~516 ~ . _ 2103254 - ~
melhods of solving integral equations, will suggest other techniques to be utilized in the future. Similarly, a method well suited for solving the set of equations l, 4 and 5 is the Newton method described in Chapter 25 of Scheid.
More or less detailed, and different types of models can be written as well, depending on the required accuracy of the meter. Applying the momentum equations provides a much more accurate solution than the energy equations, since the momentum equations only have to take into account the friction on the wall (easy to estimate), as compared with the energy equa~ions which have to take into account the energy losses (very difficult to estimate). Generally, it is considered that the present invention utilizes conservation equations, which can be either momentum or energy equations (see Hetsroni, supra).
The equation for deriving three-phase flow (oii/water/gas) by the addition of a water-cut meter in stage - l S:
QW (10) QW -- QO t QG
The liquid flow rate is the sum of~the water and the oil flow rates:
Q- = Qo + Qu (11) Therefore, the equation for determining the water flow rate can be written as:
W093/19~7 PCT/GB93/~516 21032~
QU (Q! T QG) C ( 12 ) and then Q~ can be derived from equation 12 once Q~ s known.
Figure 5 shows how the multi-phase flow meter can also be used to predict pressure drops for different multi-phase fluids in different piping devices. The addition of differential pressure transducer (36) provides measurement of the pressure drop across the meter. In the calibration process a look-up table is generated, which contains the measured pressure drop across the meter when different proportions and rates of water and air are flowed through it.
In effect the look-up table is a matrix of values of ~P~ater/ajr for different values of Qair and Q~ater-When a multi-phase fluid consisting of different components than water and air flows through the meter, stages 1, Z and 3 measure QG and QL, while stage 5 measures the differential pressure across the meter (~PflUid)- ~he ~P~ater/air that corresponds to the equivalent air and water values for the measured QG and QL of the working fluid is then looked up in the above-noted look-up table, and the pressure drop ratio is calculated.
The equation for the pressure drop ratio of the working multi-phase fluid relative to an equivalent water/air mixture is:
= const I same f ' ow conai~ons ( 1 3 ) Once this ratio has been calculated, it can be applied to obtain an accurate prediction of the pressure drop of multi-phase fluids in other devices in the line, where the pressure drop of an equivalent water/air mixture is known.
For example, to obtain the pressure drop in a vertical pipe in a field pipe line where crude oil, water and natural gas are flowing, a priori knowledge of the pressure drop for an air/water mixture in the same vertical pipe at the same flow rate is needed. This can be found in field handbooks (see Perry et al, "Chemical Engineer's Handbook", McGraw-Hill Book Co., 1973, pp. 5.40-5.47). Multiplication of this number with the pressure drop ratio calculated according to the present invention provides an accurate prediction of the pressure drop across the vertical pipe for the working fluid.
Figure 6 shows a flow chart that summarizes the process of the present invention.
In Figure 6, in step 100, the output of the volumetric flow meter 10, QPDI iS measured. In step 110, differential pressure P1-P2~ is measured. In step 120, the differential pressure P1-P3 is measured. In step 130, the water-cut, c, is measured. The outputs of the steps 100, 110 and 120 are fed to the computer 20 which then, in step 140, calculates QLI QG
and PLI solving equations 1, 4 and 5 and utilizing equations 6-9. In step 150, Qwater and Qoil are calculated utilizing equations 10-12, and in step 160, the results of the various calculations r .~ ~
WO93/19~7 PCT/GB93/~516 ~ 2103251 performed as thus far described, QG' Q~a~er and Qoj~ are displayed.
Figure 6 also illustrates steps by which the ratio ~PfluiJ~P~ater~air is determined. In step 170, ~PflUid is measured by means of the sensor 36 shown in Figure ~. In step 180, a look-up table is utilized to determine ~P~a~er~air ~ based on the values of Q~ and Q5 determined in step 140. In step 190 the ratio of ~PflUid~ determined in step 170 and ap~ater/ajr, determined in step 180, is determined and likewise displayed in step--160.
Obviously, numerous modifications and variations of the present invention are possible in light of the above teachings. It is therefore to be understood that within the scope of the appended claims, the invention may be practiced otherwise than as specifically described herein.
Claims (29)
1. An apparatus for measuring flow rates of gas and liquid components in a fluid flowing in a flow path, comprising:
volumetric flow meter means arranged to measure a total flow rate for said fluid and to output a corresponding total flow rate signal;
momentum flow meter means coupled in series in said flow path with said volumetric flow meter means for measuring the momentum flux of said fluid at first and second points in said flow path and for outputting respective first and second momentum signals;
processor means coupled to said volumetric flow meter means and said momentum flow meter means arranged to determine the flow rate of said gas component and the flow rate of said liquid component by solving predetermined equations for total flow and momentum or energy utilizing said total flow rate signal and said first and second momentum signals;
said processor being capable of outputting a signal indicative of said determined flow rates.
volumetric flow meter means arranged to measure a total flow rate for said fluid and to output a corresponding total flow rate signal;
momentum flow meter means coupled in series in said flow path with said volumetric flow meter means for measuring the momentum flux of said fluid at first and second points in said flow path and for outputting respective first and second momentum signals;
processor means coupled to said volumetric flow meter means and said momentum flow meter means arranged to determine the flow rate of said gas component and the flow rate of said liquid component by solving predetermined equations for total flow and momentum or energy utilizing said total flow rate signal and said first and second momentum signals;
said processor being capable of outputting a signal indicative of said determined flow rates.
2. An apparatus as claimed in claim 1, further comprising forcing means arranged to force a known velocity ratio between said gas component and said liquid component in said flow path.
3. An apparatus as claimed in claim 2, wherein said forcing means comprises one or more static mixer and/or dynamic mixer.
4. An apparatus as claimed in claim 3, wherein said forcing means comprises first and second mixers respectively coupled in series at an input and an output of said volumetric flow meter means.
5. An apparatus as claimed in claim 2, wherein said volumetric flow meter means and said forcing means comprise a positive displacement flow meter.
6. An apparatus as claimed in any preceding claim further including indicator means for displaying the determined flow rates of said gas and liquid components.
7. An apparatus as claimed in any preceding claim, wherein said momentum flow meter means comprises first and second venturi flow meters having different throat dimensions.
8. An apparatus as claimed in any one of claims 1 to 6, wherein said momentum flow meter means comprises a venturi flow meter having a venturi nozzle including plural pressure measuring taps for obtaining at least two differential pressure measurements.
9. An apparatus as claimed in claim 1, wherein said momentum flow meter means comprise drag-disk flow meters having different paddle dimensions.
10. An apparatus as claimed in any preceding claim further comprising:
water-cut meter means for measuring an amount of water in said liquid component and for outputting a corresponding water-cut signal;
said processor means being adapted to determine flow rates of a gas constituent, a water constituent, and a further constituent of said liquid in said fluid component based on said water-cut signal and the determined liquid and gas flow rates.
water-cut meter means for measuring an amount of water in said liquid component and for outputting a corresponding water-cut signal;
said processor means being adapted to determine flow rates of a gas constituent, a water constituent, and a further constituent of said liquid in said fluid component based on said water-cut signal and the determined liquid and gas flow rates.
11. An apparatus as claimed in claim 10 further comprising indicator means for displaying the determined flow rates of said water constituent and said further constituent.
12. An apparatus as claimed in any one of claims 1 to 11, further comprising means for measuring a pressure drop across the series flow path of said volumetric flow meter means and said momentum flow meter means and producing a corresponding pressure drop signal; memory means adapted to store a table of differential pressure drops as a function of plural values of air flow rate and water flow rate through said series flow path; means adapted to select from said table stored in said memory means a corresponding differential pressure drop based on the measured gas and liquid flow rates; means adapted to calculate a pressure drop ratio of said pressure drop signal and the selected differential pressure drop and outputting a corresponding pressure drop ratio signal; and means adapted to multiply said pressure drop ratio signal with a predetermined signal indicative of a pressure drop of an air/water mixture through a different flow path to determine a pressure drop of said fluid in said different flow path.
13. A method of measuring flow rates of gas and liquid components in a fluid flowing in a series flow path, comprising the steps of:
measuring a total flow rate in said flow path and outputting a corresponding total flow rate signal;
measuring the momentum flux of said fluid at first and second points in said series flow path and outputting respective first and second momentum signals;
determining the flow rate of said gas component and the flow rate of said liquid component by solving predetermined equations for total flow and momentum or energy utilizing said total flow rate signal and said first and second momentum signals; and outputting a signal indicative of said determined flow rate.
measuring a total flow rate in said flow path and outputting a corresponding total flow rate signal;
measuring the momentum flux of said fluid at first and second points in said series flow path and outputting respective first and second momentum signals;
determining the flow rate of said gas component and the flow rate of said liquid component by solving predetermined equations for total flow and momentum or energy utilizing said total flow rate signal and said first and second momentum signals; and outputting a signal indicative of said determined flow rate.
14. A method as claimed in claim 13 further comprising the steps of displaying the determined flow rates of said liquid and gas components.
15. A method as claimed in claim 13 or 14, including the step of forcing a known velocity ratio between said gas component and said liquid component in said flow path.
16. A method as claimed in any one of claims 13 to 15, further comprising the steps of measuring an amount of water in said liquid component and outputting a corresponding water-cut signal; and determining flow rates of a gas constituent, a water constituent, and a further constituent of said liquid component in said fluid based on said water-cut signal and the determined liquid and gas flow rates.
17. A method as claimed in claim 16 further comprising the step of displaying the determined flow rates of said water constituent and said further constituent.
18. A method as claimed in any one of claims 13 to 16, further comprising the steps of measuring a pressure drop across said series flow path and producing a corresponding pressure drop signal; storing a table of differential pressure drops as a function of plural values of air flow rate and water flow rate through said series flow path; selecting from the stored table a corresponding differential pressure drop based on the measured gas and liquid flow rates; calculating a pressure drop ratio of said pressure drop signal and the selected differential pressure drop and outputting a corresponding pressure drop ratio signal; and multiplying said pressure drop ratio signal with a predetermined signal indicative of a pressure drop of an air/water mixture through a different flow path to determine a pressure drop of said fluid in said different flow path.
19. A method as claimed in any one of claims 13 to 18, further comprising the step of forcing a known velocity ratio between said gas component and said liquid component in said flow path.
20. An apparatus for measuring flow rates of a gas component and a liquid component having a known density in a fluid flowing in a series flow path, comprising:
a. volumetric flow meter means capable of measuring a total flow rate for said fluid and outputting a total flow rate signal indicative of the measured total flow rate;
b. momentum flow meter means coupled in series in said series flow path with said volumetric flow meter, said momentum flow meter capable of measuring the momentum flux of said fluid and outputting a corresponding momentum signal;
c. processor means coupled to said volumetric flow meter and said momentum flow meter, said processor capable of determining the flow rate of said gas component and the flow rate of said liquid component by solving predetermined equations for total flow and momentum or energy utilizing said total flow rate signal and said momentum signal;
d. a pressure differential measuring device installed in said series flow path such that it is capable of measuring the pressure drop across the series flow path of said volumetric flow meter and said momentum flow meter, said measuring device further capable of producing pressure drop signal, indicative of the measured pressure differential;
e. a memory comprising differential drop data stored as a function of plural values of gas flow rate and liquid flow rate through said series flow path;
f. a selection device coupled to said memory, and capable of selecting a corresponding differential pressure drop based on the measured gas and liquid flow rates from said memory;
g. a calculating device coupled to receive a pressure drop signal from said pressure differential measuring device and capable of calculating a pressure drop ratio of said pressure drop signal and the selected differential pressure drop and outputting a corresponding pressure drop ratio signal; and h. a multiplying device coupled to receive a pressure drop ratio signal from said calculating device, said multiplying device capable of multiplying said pressure drop ratio signal with a predetermined signal indicative of a pressure drop of a known mixture through a different flow path to determine a pressure drop of said fluid in said different flow path.
a. volumetric flow meter means capable of measuring a total flow rate for said fluid and outputting a total flow rate signal indicative of the measured total flow rate;
b. momentum flow meter means coupled in series in said series flow path with said volumetric flow meter, said momentum flow meter capable of measuring the momentum flux of said fluid and outputting a corresponding momentum signal;
c. processor means coupled to said volumetric flow meter and said momentum flow meter, said processor capable of determining the flow rate of said gas component and the flow rate of said liquid component by solving predetermined equations for total flow and momentum or energy utilizing said total flow rate signal and said momentum signal;
d. a pressure differential measuring device installed in said series flow path such that it is capable of measuring the pressure drop across the series flow path of said volumetric flow meter and said momentum flow meter, said measuring device further capable of producing pressure drop signal, indicative of the measured pressure differential;
e. a memory comprising differential drop data stored as a function of plural values of gas flow rate and liquid flow rate through said series flow path;
f. a selection device coupled to said memory, and capable of selecting a corresponding differential pressure drop based on the measured gas and liquid flow rates from said memory;
g. a calculating device coupled to receive a pressure drop signal from said pressure differential measuring device and capable of calculating a pressure drop ratio of said pressure drop signal and the selected differential pressure drop and outputting a corresponding pressure drop ratio signal; and h. a multiplying device coupled to receive a pressure drop ratio signal from said calculating device, said multiplying device capable of multiplying said pressure drop ratio signal with a predetermined signal indicative of a pressure drop of a known mixture through a different flow path to determine a pressure drop of said fluid in said different flow path.
21. An apparatus according to claim 20 further comprising at least one of a static mixer or a dynamic mixer capable of forcing a known velocity ratio between said gas component and said liquid component in said series flow path.
22. An apparatus according to claim 20 or claim 21, wherein said volumetric flow meter means comprises a positive displacement flow meter.
23. An apparatus according to claim 20 or claim 21, wherein said momentum flow meter means comprises a venturi flow meter.
24. An apparatus according to any one of claims 20 to 23 further comprising:
a. water-cut meter means coupled to said processor and capable of measuring an amount of water in said liquid component and outputting a corresponding water-cut signal;
b. said processor being capable of determining flow rates of a gas constituent, a water constituent, and a further constituent of said liquid component based on said water-cut signal and the determined liquid and gas flow rates; and c. indicator means coupled to said processor and capable of displaying the determined flow rates of said water constituent and said further constituent.
a. water-cut meter means coupled to said processor and capable of measuring an amount of water in said liquid component and outputting a corresponding water-cut signal;
b. said processor being capable of determining flow rates of a gas constituent, a water constituent, and a further constituent of said liquid component based on said water-cut signal and the determined liquid and gas flow rates; and c. indicator means coupled to said processor and capable of displaying the determined flow rates of said water constituent and said further constituent.
25. An apparatus according to any one of claims 20 to 24 including indicator means for displaying the determined flow rates of said liquid constituent and said gas constituent.
26. A method of measuring flow rates of a gas component and a liquid component having a known density in a fluid flowing in a series flow path, the method comprising the steps of:
a. measuring a total flow rate in said series flow path and outputting a corresponding total flow rate signal;
b. measuring the momentum flux of said fluid at a point in said series flow path and outputting a corresponding momentum signal;
c. determining the flow rate of said gas component and the flow rate of said liquid component by solving predetermined equations for total flow and momentum or energy utilising said total flow rate signal and said momentum signal;
d. measuring the pressure drop across the series flow path and producing a pressure drop signal indicative of the measured pressure differential;
e. from a table of differential pressure drops stored as a function of plural values of gas flow rates and liquid flow rates through said series flow path, selecting a corresponding differential pressure drop based on the measured gas and liquid flow rates;
f. calculating a pressure drop ratio of said pressure drop signal and the selected differential pressure drop and outputting a corresponding pressure drop ratio signal; and g. multiplying said pressure drop ratio signal with a predetermined signal indicative of a pressure drop of a known mixture through a different flow path to determine a pressure drop of said fluid in said different flow path.
a. measuring a total flow rate in said series flow path and outputting a corresponding total flow rate signal;
b. measuring the momentum flux of said fluid at a point in said series flow path and outputting a corresponding momentum signal;
c. determining the flow rate of said gas component and the flow rate of said liquid component by solving predetermined equations for total flow and momentum or energy utilising said total flow rate signal and said momentum signal;
d. measuring the pressure drop across the series flow path and producing a pressure drop signal indicative of the measured pressure differential;
e. from a table of differential pressure drops stored as a function of plural values of gas flow rates and liquid flow rates through said series flow path, selecting a corresponding differential pressure drop based on the measured gas and liquid flow rates;
f. calculating a pressure drop ratio of said pressure drop signal and the selected differential pressure drop and outputting a corresponding pressure drop ratio signal; and g. multiplying said pressure drop ratio signal with a predetermined signal indicative of a pressure drop of a known mixture through a different flow path to determine a pressure drop of said fluid in said different flow path.
27. A method according to claim 26 further comprising the step of forcing a known velocity ratio between said gas component and said liquid component in said series flow path.
28. A method according to claim 26 or claim 27 further comprising the steps of:
a. measuring an amount for water in said liquid component and outputting a corresponding water-cut signal;
b. determining flow rates of said gas constituent, said water constituent, and a further constituent of said liquid component based on said water-cut signal and the determined liquid and gas flow rates; and c. displaying the determined flow rates of said water constituent and said further constituent.
a. measuring an amount for water in said liquid component and outputting a corresponding water-cut signal;
b. determining flow rates of said gas constituent, said water constituent, and a further constituent of said liquid component based on said water-cut signal and the determined liquid and gas flow rates; and c. displaying the determined flow rates of said water constituent and said further constituent.
29. A method according to claim 26, 27 or 28 further comprising the step of displaying the determined flow rates of said liquid constituent and said gas constituent.
Applications Claiming Priority (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US852,554 | 1992-03-17 | ||
| US07/852,554 US5461930A (en) | 1992-03-17 | 1992-03-17 | Apparatus and method for measuring two-or three-phase fluid flow utilizing one or more momentum flow meters and a volumetric flow meter |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CA2103254A1 CA2103254A1 (en) | 1993-09-18 |
| CA2103254C true CA2103254C (en) | 1999-02-02 |
Family
ID=25313626
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| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA002103254A Expired - Fee Related CA2103254C (en) | 1992-03-17 | 1993-03-11 | Apparatus and method for measuring two or three phase fluid flow utilizing one or more momentum flow meters and a volumetric flow meter |
Country Status (10)
| Country | Link |
|---|---|
| US (3) | US5461930A (en) |
| EP (2) | EP0738880B1 (en) |
| JP (1) | JP2790260B2 (en) |
| AU (2) | AU668920B2 (en) |
| CA (1) | CA2103254C (en) |
| DE (2) | DE69318775D1 (en) |
| HK (1) | HK1008439A1 (en) |
| NO (1) | NO308015B1 (en) |
| RU (1) | RU2079816C1 (en) |
| WO (1) | WO1993019347A1 (en) |
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| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US5461930A (en) * | 1992-03-17 | 1995-10-31 | Agar Corporation Inc. | Apparatus and method for measuring two-or three-phase fluid flow utilizing one or more momentum flow meters and a volumetric flow meter |
| FR2720498B1 (en) * | 1994-05-27 | 1996-08-09 | Schlumberger Services Petrol | Multiphase flowmeter. |
| WO1995033980A1 (en) * | 1994-06-07 | 1995-12-14 | Atlantic Richfield Company | Multiphase fluid flow rate and density measurement |
| US5597961A (en) * | 1994-06-27 | 1997-01-28 | Texaco, Inc. | Two and three phase flow metering with a water cut monitor and an orifice plate |
| FR2722297B1 (en) * | 1994-07-05 | 1996-08-30 | Inst Francais Du Petrole | DEVICE AND METHOD FOR MEASURING SPEED PROFILE IN A POYPHASIC FLUID |
| US5589642A (en) * | 1994-09-13 | 1996-12-31 | Agar Corporation Inc. | High void fraction multi-phase fluid flow meter |
| US5576495A (en) * | 1995-10-23 | 1996-11-19 | The Babcock & Wilcox Company | Two phase flow meter |
| US6272934B1 (en) | 1996-09-18 | 2001-08-14 | Alberta Research Council Inc. | Multi-phase fluid flow measurement apparatus and method |
| CA2185867C (en) * | 1996-09-18 | 2000-03-21 | Varagur Srinivasa V. Rajan | Multi-phase fluid flow measurement apparatus and method |
| WO1999015862A1 (en) * | 1997-09-24 | 1999-04-01 | Lockheed Martin Idaho Technologies Company | Special configuration differential pressure flow meter |
| CN2349553Y (en) | 1998-07-28 | 1999-11-17 | 窦剑文 | Gas-liquid polyphase flow flowmeter |
| US6164308A (en) | 1998-08-28 | 2000-12-26 | Butler; Bryan V. | System and method for handling multiphase flow |
| US6234030B1 (en) * | 1998-08-28 | 2001-05-22 | Rosewood Equipment Company | Multiphase metering method for multiphase flow |
| US6422092B1 (en) * | 1998-09-10 | 2002-07-23 | The Texas A&M University System | Multiple-phase flow meter |
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-
1992
- 1992-03-17 US US07/852,554 patent/US5461930A/en not_active Ceased
-
1993
- 1993-03-11 AU AU36457/93A patent/AU668920B2/en not_active Ceased
- 1993-03-11 DE DE69318775T patent/DE69318775D1/en not_active Expired - Lifetime
- 1993-03-11 WO PCT/GB1993/000516 patent/WO1993019347A1/en active IP Right Grant
- 1993-03-11 EP EP96201697A patent/EP0738880B1/en not_active Expired - Lifetime
- 1993-03-11 RU RU9393058387A patent/RU2079816C1/en active
- 1993-03-11 EP EP93905570A patent/EP0584329B1/en not_active Expired - Lifetime
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- 1993-03-11 CA CA002103254A patent/CA2103254C/en not_active Expired - Fee Related
- 1993-03-11 JP JP5516347A patent/JP2790260B2/en not_active Expired - Fee Related
- 1993-11-16 NO NO934151A patent/NO308015B1/en not_active IP Right Cessation
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1995
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1996
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1997
- 1997-09-25 US US08/969,619 patent/USRE36597E/en not_active Expired - Lifetime
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1998
- 1998-07-17 HK HK98109235A patent/HK1008439A1/en not_active IP Right Cessation
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| EP0738880A2 (en) | 1996-10-23 |
| AU3645793A (en) | 1993-10-21 |
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| HK1008439A1 (en) | 1999-05-07 |
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| EP0738880B1 (en) | 2002-12-04 |
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| EP0738880A3 (en) | 1997-10-15 |
| EP0584329B1 (en) | 1998-05-27 |
| DE69318775D1 (en) | 1998-07-02 |
| USRE36597E (en) | 2000-03-07 |
| DE69332546D1 (en) | 2003-01-16 |
| NO934151L (en) | 1994-01-17 |
| AU678126B2 (en) | 1997-05-15 |
| US5461930A (en) | 1995-10-31 |
| NO308015B1 (en) | 2000-07-03 |
| CA2103254A1 (en) | 1993-09-18 |
| AU668920B2 (en) | 1996-05-23 |
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