CA2489944C - Venturi augmented flow meter - Google Patents
Venturi augmented flow meter Download PDFInfo
- Publication number
- CA2489944C CA2489944C CA2489944A CA2489944A CA2489944C CA 2489944 C CA2489944 C CA 2489944C CA 2489944 A CA2489944 A CA 2489944A CA 2489944 A CA2489944 A CA 2489944A CA 2489944 C CA2489944 C CA 2489944C
- Authority
- CA
- Canada
- Prior art keywords
- meter
- fluid mixture
- flow
- conduit
- phase fraction
- Prior art date
- Legal status (The legal status 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 status listed.)
- Expired - Fee Related
Links
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
- G01F1/40—Details of construction of the flow constriction devices
- G01F1/44—Venturi tubes
-
- 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
A venturi-assisted flow meter arrangement is disclosed. The venturi is positioned in a pipe or conduit containing the fluid mixture to be measured upstream of the flow meter. The flow meter is preferably a flow rate meter and/or a phase fraction meter. When the fluid mixture is passed through the venturi, it is homogenized or mixed, which can increase the accuracy of the measurements made by the downstream flow meter. Additionally, the venturi can be used to compute the flow momentum of the fluid mixture, which may be used to calibrate or double check the operation of the flow meter, or allow it to compute the phase fraction for a three phase mixture.
Description
2
3 TECHNICAL FIELD
4 This invention relates to measuring fluid parameters in pipes and more 6 particularly to measuring fluid composition, volumetric flow, or other fluid parameters 7 using a flow meter or meters assisted by a venturi.
11 In many industries it is desirable to measure various parameters of fluids or fluid 12 mixtures in pipes, including the temperature, pressure, composition (i.e., phase fraction, 13 e.g., 10% water, 90% oil), flow rate, and the speed of sound (SOS) in the fluid or 14 mixture. (As used herein, "fluid" may refer to a liquid or gas, and a "fluid mixture" may be mixtures of liquids or gases). Different sensor arrangements, referred to generically as 16 "flow meters," can be used to measure these parameters, such as those that are disclosed 17 in the following U.S. Patents Serial Nos.: 6,782,150, filed Nov. 29, 2000;
6,435,030, 18 filed June 25, 1999; 6,450,037, filed June 25, 1999; 6,536,291, filed July 2, 1999;
19 6,601,458, filed Mar. 7, 2000; 6,354,147, filed June 25, 1999; 6,463,813, filed June 25, 1999 and publicly available 20030084707A1, filed Nov. 7, 2001.
22 A flow meter typically comprises a sensor, a sensor array, or multiple sensor 23 arrays. In any of these flow meters, the sensors may comprise fiber optic sensors, 1 possibly incorporating fiber Bragg gratings (FBGs), which can be mounted or coiled 2 around the pipe containing the fluid to be measured. Other flow meters allow optical 3 devices or other sensing devices to be ported or placed within the pipe to make the 4 required measurements. When one uses a fiber optic based flow meter, the fluid or s mixture parameters may be measured without the need to "tap in" to the pipe, as many of 6 these parameters may be sensed externally to the pipe though the means disclosed in 7 these incorporated references. Often, these externally mounted sensors are "passive"
8 sensors in the sense that they do not require stimulating the fluid or mixture of interest by 9 external means, but instead make the required measurements simply by sensing various io naturally occurring fluid effects.
i i In the oil and gas industry, or comparable industries, it is desirable to measure, in 12 situ, the flow produced from an oil well. Typically the produced fluid may be comprised 13 of three components or phases, such as oil, water, and gas, which may additionally 14 contain other components, such as solids (e.g., rocks or sand) or other liquid phases. In a 15 production environment, it is often useful to determine the phase fraction, or 16 composition, of the fluid being measured, as well as the speed of the flowing mixture.
17 Techniques for measuring fluid or mixture flow rate exist in the prior art.
For is example, elsewhere there is disclosed a flow rate meter which preferably uses fiber 19 optic sensors. These fiber optic sensors are disposed at two different axial locations 20 along the pipe containing the fluid to be measured. Naturally occurring pressure 21 disturbances in the fluid perturb the first sensor through the wall of the pipe, creating a WO 2004/003484 PCT/GB2003/0025]]
1 time-varying pressure signal. When the pressure disturbances, or pressure field, moves 2 from the first sensor to the second sensor, a similar pressure signal is measured. The two 3 signals from the pressure sensor can then be cross-correlated using well-known 4 techniques to determine the time shift in the pressure signals. This time delay, when divided by the axial distance of the sensor, can be used to determine flow rate.
6 Optionally, the sensors may comprise filters capable of filtering out certain undesirable 7 wavelengths, which may constitute a single sensor or multiple sensors.
8 Other flow rate techniques using venturis are also known in the art. For example, 9 U.S. Patent No. 5,591,922, entitled "Method and Apparatus for Measuring Multiphase io Flow," issued Jan. 7, 1997.
11 In the `922 patent, a pair of venturis within a pipe are spaced from one another at an axial 12 distance. As is well known, the venturi causes a pressure difference (OP) at each venturi, 13 which are measured. These differential pressure signals are cross-correlated to determine 14 a time delay, which can then be divided by the axial distance to determine a flow is velocity.
16 Flow meters for determining phase fraction ("phase fraction meter") in a fluid 17 mixture are also known in the art. For example, referring to U.S. Patent 6,354,147, entitled 18 "Fluid Parameter Measurement in Pipes Using Acoustic Pressures," issued March 12, 2002 a 19 spatial array of pressure sensors, preferably fiber optic sensors, are coupled to the outside of the 20 pipe. These sensor produce pressure signals, which are used to determine the speed of sound of 21 the mixture. Because the speed of sound of a given mixture can be calculated from the speed i of sound of the components in the mixture, the measured speed of sound can be used to 2 determine the phase fraction of the mixture.
3 Often these various types of flow meters will be used in conjunction with each 4 other to measure various fluid parameters of the device. For example, a flow rate meter may be used on one section of the pipe, followed downstream by a phase fraction meter, 6 or vice versa. Or, these flow meters may be combined into an integrated flow meter 7 apparatus.
8 The accuracy of these and other prior art flow meters are generally enhanced 9 when the fluid mixture being measured is relatively well mixed or "homogenous."
io Relatively inhomogeneous mixtures, having larger unmixed portions of the components 11 that constitute the mixture, may not provide suitable pressure disturbances (i.e., acoustic 12 differences) that can be easily resolved by the pressure sensors that typical constitute a 13 traditional flow meters. Additionally, prior art flow meters may have difficulties in 14 measuring the parameters of fluid mixtures having more than two phases. The art would is therefore benefit from ways to improve the performance of these and other traditional 16 flow meter techniques.
is SUMMARY OF THE INVENTION
19 A venturi-assisted flow meter arrangement is disclosed. The venturi is positioned 20 in the pipe or conduit containing the fluid mixture to be measured upstream of the flow 21 meter. The flow meter is preferably a flow rate meter and/or a phase fraction meter.
22 When the fluid mixture is passed through the venturi, it is homogenized or mixed, which 23 can increase the accuracy of the measurements made by the downstream flow meter.
1 Additionally, the venturi can be used to compute the flow momentum of the fluid 2 mixture, which may be used to calibrate or double check the operation of the flow meter, 3 or allow it to compute the phase fraction for a three phase mixture.
.4 According to an aspect of the present invention there is provided an apparatus for
11 In many industries it is desirable to measure various parameters of fluids or fluid 12 mixtures in pipes, including the temperature, pressure, composition (i.e., phase fraction, 13 e.g., 10% water, 90% oil), flow rate, and the speed of sound (SOS) in the fluid or 14 mixture. (As used herein, "fluid" may refer to a liquid or gas, and a "fluid mixture" may be mixtures of liquids or gases). Different sensor arrangements, referred to generically as 16 "flow meters," can be used to measure these parameters, such as those that are disclosed 17 in the following U.S. Patents Serial Nos.: 6,782,150, filed Nov. 29, 2000;
6,435,030, 18 filed June 25, 1999; 6,450,037, filed June 25, 1999; 6,536,291, filed July 2, 1999;
19 6,601,458, filed Mar. 7, 2000; 6,354,147, filed June 25, 1999; 6,463,813, filed June 25, 1999 and publicly available 20030084707A1, filed Nov. 7, 2001.
22 A flow meter typically comprises a sensor, a sensor array, or multiple sensor 23 arrays. In any of these flow meters, the sensors may comprise fiber optic sensors, 1 possibly incorporating fiber Bragg gratings (FBGs), which can be mounted or coiled 2 around the pipe containing the fluid to be measured. Other flow meters allow optical 3 devices or other sensing devices to be ported or placed within the pipe to make the 4 required measurements. When one uses a fiber optic based flow meter, the fluid or s mixture parameters may be measured without the need to "tap in" to the pipe, as many of 6 these parameters may be sensed externally to the pipe though the means disclosed in 7 these incorporated references. Often, these externally mounted sensors are "passive"
8 sensors in the sense that they do not require stimulating the fluid or mixture of interest by 9 external means, but instead make the required measurements simply by sensing various io naturally occurring fluid effects.
i i In the oil and gas industry, or comparable industries, it is desirable to measure, in 12 situ, the flow produced from an oil well. Typically the produced fluid may be comprised 13 of three components or phases, such as oil, water, and gas, which may additionally 14 contain other components, such as solids (e.g., rocks or sand) or other liquid phases. In a 15 production environment, it is often useful to determine the phase fraction, or 16 composition, of the fluid being measured, as well as the speed of the flowing mixture.
17 Techniques for measuring fluid or mixture flow rate exist in the prior art.
For is example, elsewhere there is disclosed a flow rate meter which preferably uses fiber 19 optic sensors. These fiber optic sensors are disposed at two different axial locations 20 along the pipe containing the fluid to be measured. Naturally occurring pressure 21 disturbances in the fluid perturb the first sensor through the wall of the pipe, creating a WO 2004/003484 PCT/GB2003/0025]]
1 time-varying pressure signal. When the pressure disturbances, or pressure field, moves 2 from the first sensor to the second sensor, a similar pressure signal is measured. The two 3 signals from the pressure sensor can then be cross-correlated using well-known 4 techniques to determine the time shift in the pressure signals. This time delay, when divided by the axial distance of the sensor, can be used to determine flow rate.
6 Optionally, the sensors may comprise filters capable of filtering out certain undesirable 7 wavelengths, which may constitute a single sensor or multiple sensors.
8 Other flow rate techniques using venturis are also known in the art. For example, 9 U.S. Patent No. 5,591,922, entitled "Method and Apparatus for Measuring Multiphase io Flow," issued Jan. 7, 1997.
11 In the `922 patent, a pair of venturis within a pipe are spaced from one another at an axial 12 distance. As is well known, the venturi causes a pressure difference (OP) at each venturi, 13 which are measured. These differential pressure signals are cross-correlated to determine 14 a time delay, which can then be divided by the axial distance to determine a flow is velocity.
16 Flow meters for determining phase fraction ("phase fraction meter") in a fluid 17 mixture are also known in the art. For example, referring to U.S. Patent 6,354,147, entitled 18 "Fluid Parameter Measurement in Pipes Using Acoustic Pressures," issued March 12, 2002 a 19 spatial array of pressure sensors, preferably fiber optic sensors, are coupled to the outside of the 20 pipe. These sensor produce pressure signals, which are used to determine the speed of sound of 21 the mixture. Because the speed of sound of a given mixture can be calculated from the speed i of sound of the components in the mixture, the measured speed of sound can be used to 2 determine the phase fraction of the mixture.
3 Often these various types of flow meters will be used in conjunction with each 4 other to measure various fluid parameters of the device. For example, a flow rate meter may be used on one section of the pipe, followed downstream by a phase fraction meter, 6 or vice versa. Or, these flow meters may be combined into an integrated flow meter 7 apparatus.
8 The accuracy of these and other prior art flow meters are generally enhanced 9 when the fluid mixture being measured is relatively well mixed or "homogenous."
io Relatively inhomogeneous mixtures, having larger unmixed portions of the components 11 that constitute the mixture, may not provide suitable pressure disturbances (i.e., acoustic 12 differences) that can be easily resolved by the pressure sensors that typical constitute a 13 traditional flow meters. Additionally, prior art flow meters may have difficulties in 14 measuring the parameters of fluid mixtures having more than two phases. The art would is therefore benefit from ways to improve the performance of these and other traditional 16 flow meter techniques.
is SUMMARY OF THE INVENTION
19 A venturi-assisted flow meter arrangement is disclosed. The venturi is positioned 20 in the pipe or conduit containing the fluid mixture to be measured upstream of the flow 21 meter. The flow meter is preferably a flow rate meter and/or a phase fraction meter.
22 When the fluid mixture is passed through the venturi, it is homogenized or mixed, which 23 can increase the accuracy of the measurements made by the downstream flow meter.
1 Additionally, the venturi can be used to compute the flow momentum of the fluid 2 mixture, which may be used to calibrate or double check the operation of the flow meter, 3 or allow it to compute the phase fraction for a three phase mixture.
.4 According to an aspect of the present invention there is provided an apparatus for
5 determining at least one parameter of a fluid mixture flowing in a conduit, the apparatus
6 comprising a restriction at a first axial location along the conduit for homogenizing the
7 fluid mixture downstream from the restriction, and at least one flow meter along the
8 conduit for measuring at least one parameter of the homogenized fluid mixture, the flow
9 meter comprising an array of pressure sensors for measuring unsteady pressure variations within the conduit.
11 According to another aspect of the present invention there is provided an 12 apparatus for determining at least one parameter of a fluid mixture flowing in a conduit, 13 the apparatus comprising a restriction at a first axial location along the conduit, at least 14 one sensor assembly located at the restriction for providing at least one parameter indicative of the flow momentum of the fluid mixture, at least one flow meter at a second 16 axial location along the conduit for providing at least one parameter indicative of the 17 fluid mixture, the flow meter comprising an array of pressure sensors for measuring 18 unsteady pressure variations within the conduit, and a computer for receiving the at least 19 one parameter indicative of the flow momentum to calibrate the at least one flow meter.
According to a further aspect of the present invention there is provided an 21 apparatus for determining the phase fraction of components in a fluid mixture flowing in 22 a conduit, the apparatus comprising at least one sensor assembly located at a restriction 23 for providing at least one parameter indicative of the flow momentum of the fluid 24 mixture, at least one flow rate meter along the conduit for providing at least one parameter indicative of the fluid mixture flow rate, the flow meter comprising an array of 26 pressure sensors for measuring unsteady pressure variations within the conduit, at least 5a 1 one phase fraction meter along the conduit for providing at least one parameter indicative 2 of the density of the fluid mixture, and a computer for receiving the at least one 3 parameter indicative of the flow momentum, the at least one parameter indicative of the '4 fluid mixture flow rate, and the at least one parameter indicative of the density of the fluid mixture to compute the phase fraction of components in the fluid mixture.
6 According to a further aspect of the present invention there is provided a method 7 for determining at least one parameter of a fluid mixture flowing in a conduit, the method 8 comprising homogenizing the fluid mixture by passing the mixture through a restriction 9 in the conduit at a first axial location along the conduit, and measuring at least one parameter of the homogenized fluid mixture using at least one flow meter along the 11 conduit, the flow meter comprising an array of pressure sensors for measuring unsteady 12 pressure variations within the conduit.
13 According to a further aspect of the present invention there is provided a method 14 for determining at least one parameter of a fluid mixture flowing in a conduit, the method comprising measuring at least one parameter indicative of the flow momentum of the 16 fluid mixture using a sensor assembly along the conduit, measuring at least one 17 parameter of the fluid mixture using at least one flow meter along the conduit, the flow 18 meter comprising an array of pressure sensors for measuring unsteady pressure variations 19 within the conduit, and calibrating the at least one flow meter using the at least one parameter indicative of the flow momentum.
21 According to a further aspect of the present invention there is provided a method 22 for determining the phase fraction of components in a fluid mixture flowing in a conduit, 23 the method comprising measuring at least one parameter indicative of the flow 24 momentum of the fluid mixture using a sensor assembly along the conduit, measuring at least one parameter indicative of the fluid mixture flow rate using at least one flow rate 26 meter along the conduit, the flow meter comprising an array of pressure sensors for 5b 1 measuring unsteady pressure variations within the conduit, measuring at least one 2 parameter indicative of the density of the fluid mixture using at least one phase fraction 3 meter along the conduit, and computing the phase fraction of components in the fluid 4 mixture using the at least one parameter indicative of the flow momentum, the at least one parameter indicative of the flow rate, and the at least one parameter indicative of the 6 density.
8 Figure 1 is a side view of a pipe having a venturi placed upstream of traditional 9 flow meter(s) to improve their performance.
Figure 2 is a side view of a pipe with a venturi, illustrating homogenization of 11 fluid flow.
13 In the disclosure that follows, in the interest of clarity, not all features of actual 14 commercial implementations of a venturi augmented flow meter and related techniques are described. It will of course be appreciated that in the development of any such actual 16 implementation, as in any such project, numerous engineering and design decisions must 17 be made to achieve the developers' specific goals, e.g., compliance with mechanical and 18 business related constraints, which will vary from one implementation to another. While 19 attention must necessarily be paid to proper engineering and design practices for the environment in question, it should be appreciated that development of a venturi 21 augmented flow meter and related techniques would nevertheless be a routine 22 undertaking for those of skill in the art given the details provided by this disclosure, even 23 if such development efforts are complex and time-consuming.
1 Figures 1 shows a cross section of a pipe 1 having a venturi 5 placed within. The 2 fluid mixture within the pipe flows from left to right as indicated by the arrow.
3 Downstream from the venturi, in a preferred embodiment, are a phase fraction meter 7 4 and a flow rate meter 8. Any suitable phase fraction meter 7 and/or flow rate meter 8 can s be used in, and would be benefited by, the disclosed configuration. For example, the 6 phase fraction meter 7 could constitute the meter disclosed in U.S. Patent 6,354,147, 7 entitled "Fluid Parameter Measurement in Pipes Using Acoustic Pressures,"
issued March 9 12, 2002. The flow meter could constitute a meter disclosed elsewhere. The details of these flow meters 9 are not disclosed herein, but preferably include passive fiber optic based sensors employing, or working in conjunction with, fiber Bragg grating (FBGs) in, for example, a scanning Fabry-Perot, 11 acousto-optic tuned filter (AOTF), optical filter, or time-of-flight arrangement having 12 sufficient sensitivity for the particular conditions and measurements to be made. Such 13 sensors are capable of measuring one or more of the following parameters:
pressure, 14 temperature, speed of sound, axial momentum, and volumetric flow. The sensors may operate actively or passively.
16 While shown at the same location on the pipe, it should be understood that the 17 meters 7 and 8 could be displaced axially along the pipe, i.e., in sequence. Moreover, the 18 venturi 5 can be used in conjunction with the phase fraction meter 7 or flow rate meter 8 19 individually, although in a preferred embodiment it is preferred that both meters be present because in a commercial embodiment it is usually beneficial to know as much 1 about the flowing fluid mixture as possible. Additionally, other types of flow meters may 2 be added, and may be multiplexed together, which is facilitated when optical 3 technologies are used. Each flow meter 7 and/or 8 can be incorporated into an existing 4 section of pipe 1, or can be incorporated into a pipe section that is inserted in line into a production pipe or well casing.
6 Multiple phase fraction meters 7 and/or flow rate meters 8 could be employed, 7 with such redundancy providing back up in case of meter failure or providing additional 8 measurements to aid in measurement accuracy. The meters 7 and/or 8 may be placed in a 9 housing within the production pipe or well casing. The housing may comprise a vessel, io such as a pressure vessel, that serves to protect the sensing arrays and to physically and it acoustically isolate them from the outside environment.
12 Also disclosed in Figure 1 are pressure sensors 11 and 12, and a temperature 13 sensor 6, for respectively measuring the pressure and temperature of the fluid mixture in 14 the pipe. The use of such additional sensors may be useful in their own right to is determine further parameters about the fluid, or to calibrate the system.
For example, the 16 density (and hence speed of sound) of a fluid component or mixture, measured by the 17 phase fraction meter 7, varies as a function of temperature and pressure, and so the 18 temperature and pressure measured by the sensors 11 and 6 are useful inputs into the 19 phase fraction meter. It may also be useful to know the temperature and/or pressure to 20 determine if materials within the mixture will volatize into a gaseous state, which again 21 would change the speed of sound and/or affect the speed of sound/phase fraction 22 calculation made by the phase fraction meter 7. The temperature and pressure sensors 6, 23 11, and 12 may be incorporated within the phase fraction meter 7 and/or the flow rate 1 meter 8, or may occur at different locations along the pipe than those shown in Figure 1.
2 Additionally, the pressure sensors 11 and 12, may also be useful in computing the 3 momentum of the fluid, as will be explained in further detail below.
4 The pressure sensors 11 and 12 and the temperature sensor 6 may constitute any s several well known sensors, including fiber optic sensors, electrical sensors, piezoelectric 6 sensors, and the like, such as those that are disclosed in the incorporated references. The 7 sensors, depending on their construction, may be placeable on, around, or within the pipe, 8 and at varying locations along its length. Moreover, these measurements, and 9 particularly the pressure measurements by sensors 11 and 12 at the venturi, may be used io to further improve the capabilities of the phase fraction meter 7 and/or the flow rate meter 11 8, as will be explained further below. Measuring the temperature and pressure via 12 sensors 6, 11 and 12 may also be useful to calibrate the actual sensor elements 13 themselves. For example, one skilled in the art will appreciate that the FBGs used in a 14 preferred system have optical characteristics that will vary with temperature, and the 15 temperature measurement may therefore be used to calibrate those sensor elements.
16 Venturi 5 could constitute any known material such as aluminum, iron, stainless 17 steel, plastic, or similar materials, and could be affixed to the inside of the pipe 1 in any is number of ways, including by brazing, soldering, bolting, glueing, or by a pressure fit.
19 Alternatively, the venturi need not be a unitary piece but instead could be formed by 20 deforming the pipe's surface, or could be separately formed and welded to respective 21 ends of the pipe 1. Additionally, the venturi can be manufactured using a single solid 22 cylinder, and machining the cylinder to form the venturi and related contiguous pipe 23 structures. As one skilled in the art will realize, the composition of the venturi 5, and the 1 means for affixing the venturi to the pipe 1, will necessarily depend on the composition 2 (and possibly thickness) of the pipe and/or the environment in question. For example, 3 where the venturi is to be employed in an oil/gas production pipe, and therefore 4 potentially subject to corrosive chemicals, high temperatures, and mechanical s disturbances (such as from sand or rock floating in the pipe), it may be beneficial for the 6 venturi to comprise stainless steel welded to the inner diameter of the pipe.
7 The venturi is comprised of three sections: a converging inlet or approach section 8 3, a throat section 4, and an outlet or diffuser section 10. The inlet 3 may be shaped as 9 appropriate, for instance as a circle, ellipse, or portion thereof. In a preferred embodiment, it is shaped as a quarter ellipse. The exit section may diverge at an angle of i i about 5 to 10 degrees relative to the axis of the pipe 1, and preferably at an angle of about 12 6 to 7 degrees. As one skilled in the art will recognize, the venturi 5 could be designed in 13 any number of ways and consistently with well-known venturi design constraints.
14 In one aspect of the disclosed invention, the venturi 5 assists the phase fraction '5 meter 7 and/or the flow rate meter 8 by causing the fluid mixture within the pipe to 16 become more uniform or homogenized. Referring to Figure 2, it should be appreciated 17 that the fluid mixture may not be well mixed (2) prior to its entry into the venturi 5. For is example, large bubbles, or large unmixed sections of oil in water, may have formed in the 19 mixture as it progresses along the pipe, perhaps aided by gravity or the natural tendency of such components to separate. However, once the fluid mixture enters the venturi 5, the 21 fluid is subject to increased velocity in the throat 4 of the venturi. This tends to mix, or 22 cavitate, the mixed fluid, particularly after it enters the outlet 10, resulting in a better 23 homogenized version of the mixed fluid (9). This improved homogenization will provide 1 a more constant input to both the phase fraction meter 7 and/or the flow rate meter 8, 2 which should improve the accuracy of those meters. Moreover, the cavitation of the fluid 3 mixture by the venturi 5 adds additional acoustic energy to the fluid mixture, making it 4 easier for the meters 7 and/or 8 to passively detect the dynamics in the mixture. One 5 skilled in the art will appreciate that because of the large acoustic impedance contrast in 6 gas/liquid mixtures, fluid mixture mixing in such mixtures is more important than for 7 liquid/liquid phase fraction determinations, such as for oil and water.
8 To realize the full benefit of the mixing that is provided by the venturi, the phase 9 fraction meter 7 and/or the flow rate meter 8 should be placed within the wake created by io the mixture. In other words, the meters 7 and/or 8 should not be placed so far from the 11 venturi along the axis of the pipe that the mixture will have the opportunity to re-settle or 12 re-segregate. On the other hand, the meters 7 and/or 8 may need to be suitably spaced 13 from the venturi so that the turbulent effect of the venturi does not so directly affect the 14 measurements being made or add "noise" to the measurement. A suitable spacing for the is meters 7 and/or 8 will depend on several factors, such as the expected flow rate of the 16 mixture, the speed at which the components in the mixture will settle, etc., and 17 experimentation may be required in a given commercial setting to determine the optimal 18 spacing. Depending on the application, it may not be necessary to place both the phase 19 fraction meter 7 and the flow rate meter downstream from the venturi. For example, if suitably sensitive, the flow rate meter might be placed upstream of the venturi.
21 It is preferred to use a venturi 5 to provide mixing of the fluid mixture, especially 22 when one considers the related benefits of the use of the venturi to measure flow 23 momentum, as discussed below. However, should those additional benefits not be i necessary in a given application, any other well-known means could be used in place of 2 venturi 5 to mix the mixture. For example, a rotating paddle wheel, a screen containing 3 holes, or other restriction or means for mechanically disrupting the mixture could be 4 used. Likewise, other venturi-like structures could be made which would intrude into the s inner diameter of the pipe to create sidewall discontinuities or undulations, which could 6 have the same effect on cavitating the fluid mixture within the pipe.
7 The venturi is useful in aspects other than in just homogenizing the mixture.
8 Specifically, and in accordance with another aspect of the invention, the pressure sensors 9 11 and 12 can be used to measure the pressure differential across the venturi 5.
io (Although drawn on the outside of the pipe 1, the pressure sensor 12 could also, and may it preferably be, placed in conjunction with the wall of the venturi 5 at the throat 4, which 12 might improve its dynamics). This pressure differential measurement allow different, or 13 extra, information to be determined about the mixture, which can improve the accuracy 14 of the phase fraction meter 8 and/or the flow rate meter 7, and which can be particularly is useful in determining the phase fraction of a three-phase fluid mixture (e.g., 16 oil/gas/water).
n An example of how the addition of a venturi 5 can assist in determining the phase is fractions in a three phase flow is first discussed. As is well known to those skilled in the 19 art of fluid dynamics, the pressure differential (OP) measured across the venturi by 20 sensors 11 and 12 is proportional to the flow momentum of the fluid, i.e., AP =
21 apmixumix2, where p,,,, is the density of the mixture, u,,,ix is the velocity of the mixture, 22 and a is a constant or fitting parameter. Because the flow rate meter 8 measures the speed of 23 the mixture, i.e., uk, the density of the mixture, põk, can be calculated.
Moreover, the speed 1 of sound in the mixture, ami,,, is measured by the phase fraction meter 8 as previously 2 explained (see U.S. patent 6,354,147 for further details). The densities of the three 3 components, e.g., oil, gas, and water, (p1, P2, and p3) are also known, as are the speed of 4 sound in these components (a1, a2, and a3). From this, the phase fraction of the oil, gas, and water (41i ~2, 43) can be calculated by the solving for these three variables in the 6 following known fluid dynamics equations:
7 Pmu=`JP1+$2P2+4)3p3;
8 1 = 4)1 + Y'2 + 4)3; and 9 1/(pm;a,, 2) = $1/(P1a1) + W2/(P2a22) + y-3/(P3a32).
(The latter of these equations is known in the art as the "Wood Equation.").
Accordingly, 11 while an existing phase fraction meter has some capability to handle or infer the phase 12 fraction for more than two-phase fluid mixtures, the accuracy of the phase fraction 13 determination can be facilitated, and made more accurate, by the addition of the 14 measurement provided by the venturi 5. Moreover, the disclosed technique is useful to 1s measure phase fraction of three-liquid-phase mixtures, or those mixtures incorporating a 16 gaseous phase.
17 The additional measurement provided by the venturi can also assist in improving, 19 or calibrating existing phase fraction meters 7 and/or flow rate meters 8 when dealing 19 with the simpler problem of two-phase fluid mixtures. Consider for example an oil/water mixture. Fundamental to the operation of known phase fraction meters such as those 21 discussed herein is that the densities of the oil and water be known within some 22 degree of accuracy. However, suppose the density of water cannot be accurately i known. A practical example of this would occur if water produced in conjunction with 2 oil from an oil/gas well inadvertently mixes with water used to pressurize the well. The 3 mixed waters may have different densities, for example, because they may differ in 4 salinity content. Therefore, if the produced water and the pressurizing water become s mixed, for example, because of a breach in the production system, the density of the 6 water may shift away from its assumed value. By using the venturi.
measurement, the 7 overall density of the mixture can be calculated, which measurement can then be used to s adjust or calculate the supposedly known density of the water in the fluid mixture by 9 manipulating the above equations and/or other equations as one skilled in the art will to appreciate. In other words, the venturi 5 can be said to "calibrate" the phase fraction t I meter 7 by providing additional measurements useful with respect to the phase fraction 12 meter. In a sense, the venturi "over constrains" the system by providing additional 13 measurements that are not necessarily needed by the phase fraction meter 7, but which 14 can improve its accuracy, or double check the integrity of the fluidic parameters used by is that system. The flow rate meter 8 can be similarly calibrated (e.g., double-checked or 16 verified or adjusted), as one skilled in the art will appreciate by reviewing the 17 discussed references.
is Although it has been disclosed that mixing or "homogenization" of the fluid t9 mixture is believed advantageous to supply a homogenized fluid mixture to the phase 20 fraction meter and/or flow rate meter 7, and hence preferable to place these meters 21 downstream from the venturi 5, this is not necessary in all applications.
If the meters can 22 operate sufficiently in a given application without homogenizing the fluid mixture, then 23 the venturi, and its accompanying flow momentum measurement, can be made I downstream of the meters 7 and/or 8 by applying the same mathematical analysis 2 described above. Indeed, this may be a desirable configuration in some applications if it 3 is desired to calibrate the meters 7 and/or 8, or if it is desirable to use the flow momentum 4 measurement to assist in determining the phase fraction of a three-phase flow, but it is not desirable to alter the native state of the fluid mixture in the pipe when making the flow 6 rate and phase fraction measurements.
7 As one skilled- in the art will appreciate, especially in light of the discussed 8 references, the various signals from the sensors and flow meters disclosed herein are 9 preferably sent to computer to process and evaluate the received data, and to make the necessary mathematic calculations. If the disclosed sensors and/or flow meters are fiber i I optic based, the signals will first be sent to an optoelectric detector(s) to transform the 12 optical signals into electrical signals useable by a standard computer, as is well known.
13 Moreover, the optical devices may be multiplexed together, e.g., by wavelength-division 14 multiplexing or time-division multiplexing, which would allow a single fiber optic fiber to carry the signals from the pipe to the necessary electronics, as is well known. In an 16 oil/gas application, the pipe will preferably be deployed down the oil well and connected 17 by a fiber optic cable(s) to the detection electronics and computer(s) residing on the Is earth's surface and accessible by an operator.
19 In summary, the measurement of flow momentum by the venturi 5 improves the phase fraction and/or flow rate measurement than when the phase fraction meter 7 and/or 21 the flow rate meter 8 operated independently, and adds additional performance to the 22 system.
1 The benefits disclosed herein can be realized independently of the orientation of 2 the pipe, be it horizontal, vertical, or otherwise.
11 According to another aspect of the present invention there is provided an 12 apparatus for determining at least one parameter of a fluid mixture flowing in a conduit, 13 the apparatus comprising a restriction at a first axial location along the conduit, at least 14 one sensor assembly located at the restriction for providing at least one parameter indicative of the flow momentum of the fluid mixture, at least one flow meter at a second 16 axial location along the conduit for providing at least one parameter indicative of the 17 fluid mixture, the flow meter comprising an array of pressure sensors for measuring 18 unsteady pressure variations within the conduit, and a computer for receiving the at least 19 one parameter indicative of the flow momentum to calibrate the at least one flow meter.
According to a further aspect of the present invention there is provided an 21 apparatus for determining the phase fraction of components in a fluid mixture flowing in 22 a conduit, the apparatus comprising at least one sensor assembly located at a restriction 23 for providing at least one parameter indicative of the flow momentum of the fluid 24 mixture, at least one flow rate meter along the conduit for providing at least one parameter indicative of the fluid mixture flow rate, the flow meter comprising an array of 26 pressure sensors for measuring unsteady pressure variations within the conduit, at least 5a 1 one phase fraction meter along the conduit for providing at least one parameter indicative 2 of the density of the fluid mixture, and a computer for receiving the at least one 3 parameter indicative of the flow momentum, the at least one parameter indicative of the '4 fluid mixture flow rate, and the at least one parameter indicative of the density of the fluid mixture to compute the phase fraction of components in the fluid mixture.
6 According to a further aspect of the present invention there is provided a method 7 for determining at least one parameter of a fluid mixture flowing in a conduit, the method 8 comprising homogenizing the fluid mixture by passing the mixture through a restriction 9 in the conduit at a first axial location along the conduit, and measuring at least one parameter of the homogenized fluid mixture using at least one flow meter along the 11 conduit, the flow meter comprising an array of pressure sensors for measuring unsteady 12 pressure variations within the conduit.
13 According to a further aspect of the present invention there is provided a method 14 for determining at least one parameter of a fluid mixture flowing in a conduit, the method comprising measuring at least one parameter indicative of the flow momentum of the 16 fluid mixture using a sensor assembly along the conduit, measuring at least one 17 parameter of the fluid mixture using at least one flow meter along the conduit, the flow 18 meter comprising an array of pressure sensors for measuring unsteady pressure variations 19 within the conduit, and calibrating the at least one flow meter using the at least one parameter indicative of the flow momentum.
21 According to a further aspect of the present invention there is provided a method 22 for determining the phase fraction of components in a fluid mixture flowing in a conduit, 23 the method comprising measuring at least one parameter indicative of the flow 24 momentum of the fluid mixture using a sensor assembly along the conduit, measuring at least one parameter indicative of the fluid mixture flow rate using at least one flow rate 26 meter along the conduit, the flow meter comprising an array of pressure sensors for 5b 1 measuring unsteady pressure variations within the conduit, measuring at least one 2 parameter indicative of the density of the fluid mixture using at least one phase fraction 3 meter along the conduit, and computing the phase fraction of components in the fluid 4 mixture using the at least one parameter indicative of the flow momentum, the at least one parameter indicative of the flow rate, and the at least one parameter indicative of the 6 density.
8 Figure 1 is a side view of a pipe having a venturi placed upstream of traditional 9 flow meter(s) to improve their performance.
Figure 2 is a side view of a pipe with a venturi, illustrating homogenization of 11 fluid flow.
13 In the disclosure that follows, in the interest of clarity, not all features of actual 14 commercial implementations of a venturi augmented flow meter and related techniques are described. It will of course be appreciated that in the development of any such actual 16 implementation, as in any such project, numerous engineering and design decisions must 17 be made to achieve the developers' specific goals, e.g., compliance with mechanical and 18 business related constraints, which will vary from one implementation to another. While 19 attention must necessarily be paid to proper engineering and design practices for the environment in question, it should be appreciated that development of a venturi 21 augmented flow meter and related techniques would nevertheless be a routine 22 undertaking for those of skill in the art given the details provided by this disclosure, even 23 if such development efforts are complex and time-consuming.
1 Figures 1 shows a cross section of a pipe 1 having a venturi 5 placed within. The 2 fluid mixture within the pipe flows from left to right as indicated by the arrow.
3 Downstream from the venturi, in a preferred embodiment, are a phase fraction meter 7 4 and a flow rate meter 8. Any suitable phase fraction meter 7 and/or flow rate meter 8 can s be used in, and would be benefited by, the disclosed configuration. For example, the 6 phase fraction meter 7 could constitute the meter disclosed in U.S. Patent 6,354,147, 7 entitled "Fluid Parameter Measurement in Pipes Using Acoustic Pressures,"
issued March 9 12, 2002. The flow meter could constitute a meter disclosed elsewhere. The details of these flow meters 9 are not disclosed herein, but preferably include passive fiber optic based sensors employing, or working in conjunction with, fiber Bragg grating (FBGs) in, for example, a scanning Fabry-Perot, 11 acousto-optic tuned filter (AOTF), optical filter, or time-of-flight arrangement having 12 sufficient sensitivity for the particular conditions and measurements to be made. Such 13 sensors are capable of measuring one or more of the following parameters:
pressure, 14 temperature, speed of sound, axial momentum, and volumetric flow. The sensors may operate actively or passively.
16 While shown at the same location on the pipe, it should be understood that the 17 meters 7 and 8 could be displaced axially along the pipe, i.e., in sequence. Moreover, the 18 venturi 5 can be used in conjunction with the phase fraction meter 7 or flow rate meter 8 19 individually, although in a preferred embodiment it is preferred that both meters be present because in a commercial embodiment it is usually beneficial to know as much 1 about the flowing fluid mixture as possible. Additionally, other types of flow meters may 2 be added, and may be multiplexed together, which is facilitated when optical 3 technologies are used. Each flow meter 7 and/or 8 can be incorporated into an existing 4 section of pipe 1, or can be incorporated into a pipe section that is inserted in line into a production pipe or well casing.
6 Multiple phase fraction meters 7 and/or flow rate meters 8 could be employed, 7 with such redundancy providing back up in case of meter failure or providing additional 8 measurements to aid in measurement accuracy. The meters 7 and/or 8 may be placed in a 9 housing within the production pipe or well casing. The housing may comprise a vessel, io such as a pressure vessel, that serves to protect the sensing arrays and to physically and it acoustically isolate them from the outside environment.
12 Also disclosed in Figure 1 are pressure sensors 11 and 12, and a temperature 13 sensor 6, for respectively measuring the pressure and temperature of the fluid mixture in 14 the pipe. The use of such additional sensors may be useful in their own right to is determine further parameters about the fluid, or to calibrate the system.
For example, the 16 density (and hence speed of sound) of a fluid component or mixture, measured by the 17 phase fraction meter 7, varies as a function of temperature and pressure, and so the 18 temperature and pressure measured by the sensors 11 and 6 are useful inputs into the 19 phase fraction meter. It may also be useful to know the temperature and/or pressure to 20 determine if materials within the mixture will volatize into a gaseous state, which again 21 would change the speed of sound and/or affect the speed of sound/phase fraction 22 calculation made by the phase fraction meter 7. The temperature and pressure sensors 6, 23 11, and 12 may be incorporated within the phase fraction meter 7 and/or the flow rate 1 meter 8, or may occur at different locations along the pipe than those shown in Figure 1.
2 Additionally, the pressure sensors 11 and 12, may also be useful in computing the 3 momentum of the fluid, as will be explained in further detail below.
4 The pressure sensors 11 and 12 and the temperature sensor 6 may constitute any s several well known sensors, including fiber optic sensors, electrical sensors, piezoelectric 6 sensors, and the like, such as those that are disclosed in the incorporated references. The 7 sensors, depending on their construction, may be placeable on, around, or within the pipe, 8 and at varying locations along its length. Moreover, these measurements, and 9 particularly the pressure measurements by sensors 11 and 12 at the venturi, may be used io to further improve the capabilities of the phase fraction meter 7 and/or the flow rate meter 11 8, as will be explained further below. Measuring the temperature and pressure via 12 sensors 6, 11 and 12 may also be useful to calibrate the actual sensor elements 13 themselves. For example, one skilled in the art will appreciate that the FBGs used in a 14 preferred system have optical characteristics that will vary with temperature, and the 15 temperature measurement may therefore be used to calibrate those sensor elements.
16 Venturi 5 could constitute any known material such as aluminum, iron, stainless 17 steel, plastic, or similar materials, and could be affixed to the inside of the pipe 1 in any is number of ways, including by brazing, soldering, bolting, glueing, or by a pressure fit.
19 Alternatively, the venturi need not be a unitary piece but instead could be formed by 20 deforming the pipe's surface, or could be separately formed and welded to respective 21 ends of the pipe 1. Additionally, the venturi can be manufactured using a single solid 22 cylinder, and machining the cylinder to form the venturi and related contiguous pipe 23 structures. As one skilled in the art will realize, the composition of the venturi 5, and the 1 means for affixing the venturi to the pipe 1, will necessarily depend on the composition 2 (and possibly thickness) of the pipe and/or the environment in question. For example, 3 where the venturi is to be employed in an oil/gas production pipe, and therefore 4 potentially subject to corrosive chemicals, high temperatures, and mechanical s disturbances (such as from sand or rock floating in the pipe), it may be beneficial for the 6 venturi to comprise stainless steel welded to the inner diameter of the pipe.
7 The venturi is comprised of three sections: a converging inlet or approach section 8 3, a throat section 4, and an outlet or diffuser section 10. The inlet 3 may be shaped as 9 appropriate, for instance as a circle, ellipse, or portion thereof. In a preferred embodiment, it is shaped as a quarter ellipse. The exit section may diverge at an angle of i i about 5 to 10 degrees relative to the axis of the pipe 1, and preferably at an angle of about 12 6 to 7 degrees. As one skilled in the art will recognize, the venturi 5 could be designed in 13 any number of ways and consistently with well-known venturi design constraints.
14 In one aspect of the disclosed invention, the venturi 5 assists the phase fraction '5 meter 7 and/or the flow rate meter 8 by causing the fluid mixture within the pipe to 16 become more uniform or homogenized. Referring to Figure 2, it should be appreciated 17 that the fluid mixture may not be well mixed (2) prior to its entry into the venturi 5. For is example, large bubbles, or large unmixed sections of oil in water, may have formed in the 19 mixture as it progresses along the pipe, perhaps aided by gravity or the natural tendency of such components to separate. However, once the fluid mixture enters the venturi 5, the 21 fluid is subject to increased velocity in the throat 4 of the venturi. This tends to mix, or 22 cavitate, the mixed fluid, particularly after it enters the outlet 10, resulting in a better 23 homogenized version of the mixed fluid (9). This improved homogenization will provide 1 a more constant input to both the phase fraction meter 7 and/or the flow rate meter 8, 2 which should improve the accuracy of those meters. Moreover, the cavitation of the fluid 3 mixture by the venturi 5 adds additional acoustic energy to the fluid mixture, making it 4 easier for the meters 7 and/or 8 to passively detect the dynamics in the mixture. One 5 skilled in the art will appreciate that because of the large acoustic impedance contrast in 6 gas/liquid mixtures, fluid mixture mixing in such mixtures is more important than for 7 liquid/liquid phase fraction determinations, such as for oil and water.
8 To realize the full benefit of the mixing that is provided by the venturi, the phase 9 fraction meter 7 and/or the flow rate meter 8 should be placed within the wake created by io the mixture. In other words, the meters 7 and/or 8 should not be placed so far from the 11 venturi along the axis of the pipe that the mixture will have the opportunity to re-settle or 12 re-segregate. On the other hand, the meters 7 and/or 8 may need to be suitably spaced 13 from the venturi so that the turbulent effect of the venturi does not so directly affect the 14 measurements being made or add "noise" to the measurement. A suitable spacing for the is meters 7 and/or 8 will depend on several factors, such as the expected flow rate of the 16 mixture, the speed at which the components in the mixture will settle, etc., and 17 experimentation may be required in a given commercial setting to determine the optimal 18 spacing. Depending on the application, it may not be necessary to place both the phase 19 fraction meter 7 and the flow rate meter downstream from the venturi. For example, if suitably sensitive, the flow rate meter might be placed upstream of the venturi.
21 It is preferred to use a venturi 5 to provide mixing of the fluid mixture, especially 22 when one considers the related benefits of the use of the venturi to measure flow 23 momentum, as discussed below. However, should those additional benefits not be i necessary in a given application, any other well-known means could be used in place of 2 venturi 5 to mix the mixture. For example, a rotating paddle wheel, a screen containing 3 holes, or other restriction or means for mechanically disrupting the mixture could be 4 used. Likewise, other venturi-like structures could be made which would intrude into the s inner diameter of the pipe to create sidewall discontinuities or undulations, which could 6 have the same effect on cavitating the fluid mixture within the pipe.
7 The venturi is useful in aspects other than in just homogenizing the mixture.
8 Specifically, and in accordance with another aspect of the invention, the pressure sensors 9 11 and 12 can be used to measure the pressure differential across the venturi 5.
io (Although drawn on the outside of the pipe 1, the pressure sensor 12 could also, and may it preferably be, placed in conjunction with the wall of the venturi 5 at the throat 4, which 12 might improve its dynamics). This pressure differential measurement allow different, or 13 extra, information to be determined about the mixture, which can improve the accuracy 14 of the phase fraction meter 8 and/or the flow rate meter 7, and which can be particularly is useful in determining the phase fraction of a three-phase fluid mixture (e.g., 16 oil/gas/water).
n An example of how the addition of a venturi 5 can assist in determining the phase is fractions in a three phase flow is first discussed. As is well known to those skilled in the 19 art of fluid dynamics, the pressure differential (OP) measured across the venturi by 20 sensors 11 and 12 is proportional to the flow momentum of the fluid, i.e., AP =
21 apmixumix2, where p,,,, is the density of the mixture, u,,,ix is the velocity of the mixture, 22 and a is a constant or fitting parameter. Because the flow rate meter 8 measures the speed of 23 the mixture, i.e., uk, the density of the mixture, põk, can be calculated.
Moreover, the speed 1 of sound in the mixture, ami,,, is measured by the phase fraction meter 8 as previously 2 explained (see U.S. patent 6,354,147 for further details). The densities of the three 3 components, e.g., oil, gas, and water, (p1, P2, and p3) are also known, as are the speed of 4 sound in these components (a1, a2, and a3). From this, the phase fraction of the oil, gas, and water (41i ~2, 43) can be calculated by the solving for these three variables in the 6 following known fluid dynamics equations:
7 Pmu=`JP1+$2P2+4)3p3;
8 1 = 4)1 + Y'2 + 4)3; and 9 1/(pm;a,, 2) = $1/(P1a1) + W2/(P2a22) + y-3/(P3a32).
(The latter of these equations is known in the art as the "Wood Equation.").
Accordingly, 11 while an existing phase fraction meter has some capability to handle or infer the phase 12 fraction for more than two-phase fluid mixtures, the accuracy of the phase fraction 13 determination can be facilitated, and made more accurate, by the addition of the 14 measurement provided by the venturi 5. Moreover, the disclosed technique is useful to 1s measure phase fraction of three-liquid-phase mixtures, or those mixtures incorporating a 16 gaseous phase.
17 The additional measurement provided by the venturi can also assist in improving, 19 or calibrating existing phase fraction meters 7 and/or flow rate meters 8 when dealing 19 with the simpler problem of two-phase fluid mixtures. Consider for example an oil/water mixture. Fundamental to the operation of known phase fraction meters such as those 21 discussed herein is that the densities of the oil and water be known within some 22 degree of accuracy. However, suppose the density of water cannot be accurately i known. A practical example of this would occur if water produced in conjunction with 2 oil from an oil/gas well inadvertently mixes with water used to pressurize the well. The 3 mixed waters may have different densities, for example, because they may differ in 4 salinity content. Therefore, if the produced water and the pressurizing water become s mixed, for example, because of a breach in the production system, the density of the 6 water may shift away from its assumed value. By using the venturi.
measurement, the 7 overall density of the mixture can be calculated, which measurement can then be used to s adjust or calculate the supposedly known density of the water in the fluid mixture by 9 manipulating the above equations and/or other equations as one skilled in the art will to appreciate. In other words, the venturi 5 can be said to "calibrate" the phase fraction t I meter 7 by providing additional measurements useful with respect to the phase fraction 12 meter. In a sense, the venturi "over constrains" the system by providing additional 13 measurements that are not necessarily needed by the phase fraction meter 7, but which 14 can improve its accuracy, or double check the integrity of the fluidic parameters used by is that system. The flow rate meter 8 can be similarly calibrated (e.g., double-checked or 16 verified or adjusted), as one skilled in the art will appreciate by reviewing the 17 discussed references.
is Although it has been disclosed that mixing or "homogenization" of the fluid t9 mixture is believed advantageous to supply a homogenized fluid mixture to the phase 20 fraction meter and/or flow rate meter 7, and hence preferable to place these meters 21 downstream from the venturi 5, this is not necessary in all applications.
If the meters can 22 operate sufficiently in a given application without homogenizing the fluid mixture, then 23 the venturi, and its accompanying flow momentum measurement, can be made I downstream of the meters 7 and/or 8 by applying the same mathematical analysis 2 described above. Indeed, this may be a desirable configuration in some applications if it 3 is desired to calibrate the meters 7 and/or 8, or if it is desirable to use the flow momentum 4 measurement to assist in determining the phase fraction of a three-phase flow, but it is not desirable to alter the native state of the fluid mixture in the pipe when making the flow 6 rate and phase fraction measurements.
7 As one skilled- in the art will appreciate, especially in light of the discussed 8 references, the various signals from the sensors and flow meters disclosed herein are 9 preferably sent to computer to process and evaluate the received data, and to make the necessary mathematic calculations. If the disclosed sensors and/or flow meters are fiber i I optic based, the signals will first be sent to an optoelectric detector(s) to transform the 12 optical signals into electrical signals useable by a standard computer, as is well known.
13 Moreover, the optical devices may be multiplexed together, e.g., by wavelength-division 14 multiplexing or time-division multiplexing, which would allow a single fiber optic fiber to carry the signals from the pipe to the necessary electronics, as is well known. In an 16 oil/gas application, the pipe will preferably be deployed down the oil well and connected 17 by a fiber optic cable(s) to the detection electronics and computer(s) residing on the Is earth's surface and accessible by an operator.
19 In summary, the measurement of flow momentum by the venturi 5 improves the phase fraction and/or flow rate measurement than when the phase fraction meter 7 and/or 21 the flow rate meter 8 operated independently, and adds additional performance to the 22 system.
1 The benefits disclosed herein can be realized independently of the orientation of 2 the pipe, be it horizontal, vertical, or otherwise.
Claims (71)
1. An apparatus for determining at least one parameter of a fluid mixture flowing in a conduit, the apparatus comprising:
a restriction at a first axial location along the conduit for homogenizing the fluid mixture downstream from the restriction; and at least one flow meter along the conduit for measuring at least one parameter of the homogenized fluid mixture, the flow meter comprising an array of pressure sensors for measuring unsteady pressure variations within the conduit.
a restriction at a first axial location along the conduit for homogenizing the fluid mixture downstream from the restriction; and at least one flow meter along the conduit for measuring at least one parameter of the homogenized fluid mixture, the flow meter comprising an array of pressure sensors for measuring unsteady pressure variations within the conduit.
2. The apparatus of claim 1, wherein the at least one flow meter is non-invasively coupled to the outside of the conduit.
3. The apparatus of claim 1 or 2, wherein the flow meter is selected from at least one member of the group consisting of a flow rate meter and a phase fraction meter.
4. The apparatus of claim 3, wherein the at least one parameter measured by the flow rate meter is indicative of the flow rate of the fluid mixture, and wherein the at least one parameter measured by the phase fraction meter is indicative of the phase fraction of the fluid mixture.
5. The apparatus of claim 4, further comprising a sensor along the conduit and selected from the group consisting of a pressure sensor and a temperature sensor.
6. The apparatus of claim 5, wherein the sensor is used to calibrate either the flow rate meter or the phase fraction meter.
7. The apparatus of any one of claims 1 to 6, wherein the restriction comprises a venturi.
8. The apparatus of claim 7, further comprising a sensor assembly proximate to the venturi that provides at least one parameter indicative of a flow momentum of the fluid mixture.
9. The apparatus of claim 8, wherein the flow meters are comprised of a flow rate meter for measuring at least one parameter indicative of fluid mixture flow rate and a phase fraction meter for measuring at least one parameter indicative of the phase fractions of the fluid mixture.
10. The apparatus of claim 9, wherein the parameters indicative of flow momentum and flow rate are used to compute the phase fraction of the fluid mixture.
11. The apparatus of claim 9, wherein the at least one parameter indicative of flow momentum is used to calibrate either the flow rate meter or the phase fraction meter.
12. The apparatus of any one of claims 1 to 11, wherein the pressure sensors are selected from the group consisting of a fiber optic based sensor, a piezoelectric sensor, a capacitive strain gauge, piezoresistive sensor, an accelerometer, and a hydrophone.
13. The apparatus of any one of claims 1 to 12, wherein the first axial location is upstream of the flow meter.
14. The apparatus of any one of claims 1 to 13, wherein the at least one parameter is selected from at least one member of the group consisting of a speed of sound of the fluid mixture, a velocity of the fluid mixture, and a phase fraction of the fluid mixture.
15. An apparatus for determining at least one parameter of a fluid mixture flowing in a conduit, the apparatus comprising:
a restriction at a first axial location along the conduit;
at least one sensor assembly located at the restriction for providing at least one parameter indicative of the flow momentum of the fluid mixture;
at least one flow meter at a second axial location along the conduit for providing at least one parameter indicative of the fluid mixture, the flow meter comprising an array of pressure sensors for measuring unsteady pressure variations within the conduit; and a computer for receiving the at least one parameter indicative of the flow momentum to calibrate the at least one flow meter.
a restriction at a first axial location along the conduit;
at least one sensor assembly located at the restriction for providing at least one parameter indicative of the flow momentum of the fluid mixture;
at least one flow meter at a second axial location along the conduit for providing at least one parameter indicative of the fluid mixture, the flow meter comprising an array of pressure sensors for measuring unsteady pressure variations within the conduit; and a computer for receiving the at least one parameter indicative of the flow momentum to calibrate the at least one flow meter.
16. The apparatus of claim 15, wherein the restriction comprises a venturi.
17. The apparatus of claim 15 or 16, wherein the at least one flow meter is fiber optic based.
18. The apparatus of claim 17, wherein the at least one flow meter is non-invasively coupled to the outside of the conduit.
19. The apparatus of any one of claims 15 to 18, wherein the flow meter is selected from the group consisting of a flow rate meter and a phase fraction meter.
20. The apparatus of claim 19, wherein at least one parameter measured by the flow rate meter is indicative of the flow rate of the fluid mixture, and wherein the at least one parameter measured by the phase fraction meter is indicative of the phase fraction of the fluid mixture.
21. The apparatus of claim 20, further comprising an additional sensor along the conduit and selected from the group consisting of a pressure sensor and a temperature sensor.
22. The apparatus of claim 21, wherein the additional sensor is used to further calibrate either the flow rate meter or the phase fraction meter.
23. The apparatus of any one of claims 15 to 22, wherein the sensor assembly comprises pressure sensors.
24. The apparatus of claim 23, wherein the at least one flow meter is downstream from the restriction in the flowing fluid mixture.
25. An apparatus for determining the phase fraction of components in a fluid mixture flowing in a conduit, the apparatus comprising:
at least one sensor assembly located at a restriction for providing at least one parameter indicative of the flow momentum of the fluid mixture;
at least one flow rate meter along the conduit for providing at least one parameter indicative of the fluid mixture flow rate, the flow meter comprising an array of pressure sensors for measuring unsteady pressure variations within the conduit;
at least one phase fraction meter along the conduit for providing at least one parameter indicative of the density of the fluid mixture; and a computer for receiving the at least one parameter indicative of the flow momentum, the at least one parameter indicative of the fluid mixture flow rate, and the at least one parameter indicative of the density of the fluid mixture to compute the phase fraction of components in the fluid mixture.
at least one sensor assembly located at a restriction for providing at least one parameter indicative of the flow momentum of the fluid mixture;
at least one flow rate meter along the conduit for providing at least one parameter indicative of the fluid mixture flow rate, the flow meter comprising an array of pressure sensors for measuring unsteady pressure variations within the conduit;
at least one phase fraction meter along the conduit for providing at least one parameter indicative of the density of the fluid mixture; and a computer for receiving the at least one parameter indicative of the flow momentum, the at least one parameter indicative of the fluid mixture flow rate, and the at least one parameter indicative of the density of the fluid mixture to compute the phase fraction of components in the fluid mixture.
26. The apparatus of claim 25, further comprising an additional sensor along the conduit and selected from the group consisting of a pressure sensor and a temperature sensor.
27. The apparatus of claim 26, wherein the additional sensor is used to calibrate either the flow rate meter, the phase fraction meter, or the sensor assembly.
28. The apparatus of claim 25 or 26, wherein the flow rate meter, the phase fraction meter, or the sensor assembly are fiber optic based.
29. The apparatus of claim 28, wherein the flow rate meter, the phase fraction meter, or the sensor assembly are coupled to the outside of the conduit.
30. The apparatus of any one of claims 25 to 29, wherein the at least one sensor assembly is located proximate to a restriction within the conduit.
31. The apparatus of claim 30, wherein the restriction comprises a venturi.
32. The apparatus of claim 30 or 31, wherein either the at least one flow rate meter or the at least one phase fraction meter is downstream from the restriction in the flowing fluid mixture.
33. The apparatus of any one of claims 25 to 32, wherein the fluid mixture has three components.
34. The apparatus of claim 33, wherein one of the components is gaseous.
35. A method for determining at least one parameter of a fluid mixture flowing in a conduit, the method comprising:
homogenizing the fluid mixture by passing the mixture through a restriction in the conduit at a first axial location along the conduit; and measuring at least one parameter of the homogenized fluid mixture using at least one flow meter along the conduit, the flow meter comprising an array of pressure sensors for measuring unsteady pressure variations within the conduit.
homogenizing the fluid mixture by passing the mixture through a restriction in the conduit at a first axial location along the conduit; and measuring at least one parameter of the homogenized fluid mixture using at least one flow meter along the conduit, the flow meter comprising an array of pressure sensors for measuring unsteady pressure variations within the conduit.
36. The method of claim 35, wherein the flow meter is selected from at least one member of the group consisting of a flow rate meter and a phase fraction meter.
37. The method of claim 36, wherein the at least one parameter measured by the flow rate meter is indicative of the flow rate of the fluid mixture, and wherein the at least one parameter measured by the phase fraction meter is indicative of the phase fraction of the fluid mixture.
38. The method of any one of claims 35 to 37, wherein the at least one flow meter is non-invasively coupled to the outside of the conduit.
39. The method of any one of claims 35 to 38, further comprising measuring the pressure or temperature of the fluid mixture.
40. The method of claim 39, further comprising calibrating either the flow rate meter or the phase fraction meter using the measured pressure or temperature.
41. The method of any one of claims 35 to 40, wherein the restriction comprises a venturi.
42. The method of any one of claims 35 to 41, further comprising measuring at least one parameter indicative of the flow momentum of the fluid mixture at the first axial location.
43. The method of claim 42, wherein the method contains two flow meters.
44. The method of claim 43, wherein the at least one parameters measured by the flow meters are indicative of the fluid mixture flow rate and a phase fraction.
45. The method of claim 43, wherein the at least one parameters indicative of the fluid mixture flow rate and the phase fraction are used to compute the phase fraction.
46. The method of claim 42, wherein the parameter indicative of the flow momentum is used to calibrate either the flow rate meter or the phase fraction meter.
47. The method of any one of claims 35 to 46, wherein the pressure sensors are selected from the group consisting of a fiber optic based sensor, a piezoelectric sensor, a capacitive stain gauge, piezoresistive sensor, an accelerometer and a hydrophone.
48. The method of any one of claims 35 to 47, wherein the first axial location is upstream of the flow meter.
49. The method of any one of claims 35 to 48, wherein the at least one parameter is selected from at least one member of the group consisting of a speed of sound of the fluid mixture, a velocity of the fluid mixture, and a phase fraction of the fluid mixture.
50. A method for determining at least one parameter of a fluid mixture flowing in a conduit, the method comprising:
measuring at least one parameter indicative of the flow momentum of the fluid mixture using a sensor assembly along the conduit;
measuring at least one parameter of the fluid mixture using at least one flow meter along the conduit, the flow meter comprising an array of pressure sensors for measuring unsteady pressure variations within the conduit; and calibrating the at least one flow meter using the at least one parameter indicative of the flow momentum.
measuring at least one parameter indicative of the flow momentum of the fluid mixture using a sensor assembly along the conduit;
measuring at least one parameter of the fluid mixture using at least one flow meter along the conduit, the flow meter comprising an array of pressure sensors for measuring unsteady pressure variations within the conduit; and calibrating the at least one flow meter using the at least one parameter indicative of the flow momentum.
51. The method of claim 50, wherein the parameter indicative of the flow momentum is measured at a location having a restriction in the conduit.
52. The method of claim 51, wherein the restriction comprises a venturi.
53. The method of any one of claims 50 to 52, wherein the restriction homogenizes the fluid mixture before the at least one parameter of the fluid mixture is measured.
54. The method of any one of claims 50 to 53, wherein the flow meter is selected from at least one member of the group consisting of a flow rate meter and a phase fraction meter.
55. The method of claim 54, further comprising measuring the pressure or temperature of the fluid mixture.
56. The method of claim 55, further comprising calibrating either the flow rate meter or the phase fraction meter using the measured pressure or temperature.
57. The method of claim 55, wherein at least one parameter measured by the flow rate meter is indicative of the flow rate of the fluid mixture, and wherein the at least one parameter measured by the phase fraction meter is indicative of the phase fraction of the fluid mixture.
58. The method of any one of claims 50 to 57, wherein the at least one flow meter is coupled to the outside of the conduit.
59. The method of any one of claims 50 to 58, wherein the method contains two flow meters.
60. The method of claim 59, wherein the at least one parameters measured by the flow meters are indicative of the fluid mixture flow rate and a phase fraction.
61. The method of claim 60, wherein the parameters indicative of the fluid mixture flow rate and the phase fraction are used to compute the phase fraction.
62. A method for determining the phase fraction of components in a fluid mixture flowing in a conduit, the method comprising:
measuring at least one parameter indicative of the flow momentum of the fluid mixture using a sensor assembly along the conduit;
measuring at least one parameter indicative of the fluid mixture flow rate using at least one flow rate meter along the conduit, the flow meter comprising an array of pressure sensors for measuring unsteady pressure variations within the conduit;
measuring at least one parameter indicative of the density of the fluid mixture using at least one phase fraction meter along the conduit; and computing the phase fraction of components in the fluid mixture using the at least one parameter indicative of the flow momentum, the at least one parameter indicative of the flow rate, and the at least one parameter indicative of the density.
measuring at least one parameter indicative of the flow momentum of the fluid mixture using a sensor assembly along the conduit;
measuring at least one parameter indicative of the fluid mixture flow rate using at least one flow rate meter along the conduit, the flow meter comprising an array of pressure sensors for measuring unsteady pressure variations within the conduit;
measuring at least one parameter indicative of the density of the fluid mixture using at least one phase fraction meter along the conduit; and computing the phase fraction of components in the fluid mixture using the at least one parameter indicative of the flow momentum, the at least one parameter indicative of the flow rate, and the at least one parameter indicative of the density.
63. The method of claim 62, wherein the parameter indicative of the flow momentum is measured at a location having a restriction in the conduit.
64. The method of claim 63, wherein the restriction comprises a venturi.
65. The method of any one of claims 62 to 64, wherein the restriction homogenizes the fluid mixture before either the at least one parameter indicative of the flow rate or the at least one parameter indicative of the density are measured.
66. The method of any one of claims 62 to 65, further comprising measuring the pressure or temperature of the fluid mixture.
67. The method of claim 66, further comprising calibrating either the flow rate meter or the phase fraction meter using the measured pressure or temperature.
68. The method of any one of claims 62 to 67, wherein the flow rate meter, the phase fraction meter, or the sensor assembly are fiber optic based.
69. The method of any one of claims 62 to 68, wherein the flow rate meter, the phase fraction meter, or the sensor assembly are coupled to the outside of the conduit.
70. The method of any one of claims 62 to 69, wherein the fluid mixture has three components.
71. The method of claim 70, wherein one of the components is gaseous.
Applications Claiming Priority (3)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US10/186,382 | 2002-06-28 | ||
| US10/186,382 US6698297B2 (en) | 2002-06-28 | 2002-06-28 | Venturi augmented flow meter |
| PCT/GB2003/002511 WO2004003484A2 (en) | 2002-06-28 | 2003-06-09 | Venturi augmented flow meter |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CA2489944A1 CA2489944A1 (en) | 2004-01-08 |
| CA2489944C true CA2489944C (en) | 2011-02-15 |
Family
ID=29779870
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA2489944A Expired - Fee Related CA2489944C (en) | 2002-06-28 | 2003-06-09 | Venturi augmented flow meter |
Country Status (5)
| Country | Link |
|---|---|
| US (1) | US6698297B2 (en) |
| AU (1) | AU2003241039A1 (en) |
| CA (1) | CA2489944C (en) |
| GB (1) | GB2405485B (en) |
| WO (1) | WO2004003484A2 (en) |
Families Citing this family (77)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US7275421B2 (en) * | 2002-01-23 | 2007-10-02 | Cidra Corporation | Apparatus and method for measuring parameters of a mixture having solid particles suspended in a fluid flowing in a pipe |
| US7032432B2 (en) * | 2002-01-23 | 2006-04-25 | Cidra Corporation | Apparatus and method for measuring parameters of a mixture having liquid droplets suspended in a vapor flowing in a pipe |
| US7359803B2 (en) * | 2002-01-23 | 2008-04-15 | Cidra Corporation | Apparatus and method for measuring parameters of a mixture having solid particles suspended in a fluid flowing in a pipe |
| US7328624B2 (en) * | 2002-01-23 | 2008-02-12 | Cidra Corporation | Probe for measuring parameters of a flowing fluid and/or multiphase mixture |
| CA2513105C (en) * | 2002-11-12 | 2013-01-08 | Cidra Corporation | An apparatus having an array of piezoelectric film sensors for measuring parameters of a process flow within a pipe |
| US7165464B2 (en) * | 2002-11-15 | 2007-01-23 | Cidra Corporation | Apparatus and method for providing a flow measurement compensated for entrained gas |
| AU2003295992A1 (en) * | 2002-11-22 | 2004-06-18 | Cidra Corporation | Method for calibrating a flow meter having an array of sensors |
| US6997256B2 (en) * | 2002-12-17 | 2006-02-14 | Sensor Highway Limited | Use of fiber optics in deviated flows |
| WO2004063741A2 (en) * | 2003-01-13 | 2004-07-29 | Cidra Corporation | Apparatus for measuring parameters of a flowing multiphase fluid mixture |
| ATE480753T1 (en) * | 2003-01-13 | 2010-09-15 | Expro Meters Inc | APPARATUS AND METHOD FOR DETERMINING THE VELOCITY OF A FLUID IN A PIPE USING ULTRASONIC SENSORS |
| US7343818B2 (en) * | 2003-01-21 | 2008-03-18 | Cidra Corporation | Apparatus and method of measuring gas volume fraction of a fluid flowing within a pipe |
| EP1590637B1 (en) | 2003-01-21 | 2008-11-05 | Expro Meters, Inc. | An apparatus and method of measuring gas volume fraction of a fluid flowing within a pipe |
| US6945095B2 (en) * | 2003-01-21 | 2005-09-20 | Weatherford/Lamb, Inc. | Non-intrusive multiphase flow meter |
| WO2004065912A2 (en) | 2003-01-21 | 2004-08-05 | Cidra Corporation | Apparatus and method for measuring unsteady pressures within a large diameter pipe |
| EP1599705B1 (en) | 2003-03-04 | 2019-01-02 | CiDra Corporation | An apparatus having a multi-band sensor assembly for measuring a parameter of a fluid flow flowing within a pipe |
| US6986276B2 (en) * | 2003-03-07 | 2006-01-17 | Weatherford/Lamb, Inc. | Deployable mandrel for downhole measurements |
| US7121152B2 (en) * | 2003-06-06 | 2006-10-17 | Cidra Corporation | Portable flow measurement apparatus having an array of sensors |
| EP1644705B1 (en) * | 2003-06-24 | 2016-10-12 | Cidra Corporate Services, Inc. | System and method for operating a flow process |
| WO2005054789A1 (en) * | 2003-07-08 | 2005-06-16 | Cidra Corporation | Method and apparatus for measuring characteristics of core-annular flow |
| ATE414261T1 (en) * | 2003-07-15 | 2008-11-15 | Expro Meters Inc | APPARATUS AND METHOD FOR COMPENSATING A CORIOLIS FLOW METER |
| US7299705B2 (en) * | 2003-07-15 | 2007-11-27 | Cidra Corporation | Apparatus and method for augmenting a Coriolis meter |
| CA2532577C (en) * | 2003-07-15 | 2013-01-08 | Cidra Corporation | A configurable multi-function flow measurement apparatus having an array of sensors |
| US7134320B2 (en) * | 2003-07-15 | 2006-11-14 | Cidra Corporation | Apparatus and method for providing a density measurement augmented for entrained gas |
| US7127360B2 (en) * | 2003-07-15 | 2006-10-24 | Cidra Corporation | Dual function flow measurement apparatus having an array of sensors |
| US6910388B2 (en) * | 2003-08-22 | 2005-06-28 | Weatherford/Lamb, Inc. | Flow meter using an expanded tube section and sensitive differential pressure measurement |
| US20080264182A1 (en) * | 2003-08-22 | 2008-10-30 | Jones Richard T | Flow meter using sensitive differential pressure measurement |
| US7237440B2 (en) * | 2003-10-10 | 2007-07-03 | Cidra Corporation | Flow measurement apparatus having strain-based sensors and ultrasonic sensors |
| US8024335B2 (en) * | 2004-05-03 | 2011-09-20 | Microsoft Corporation | System and method for dynamically generating a selectable search extension |
| US7367239B2 (en) * | 2004-03-23 | 2008-05-06 | Cidra Corporation | Piezocable based sensor for measuring unsteady pressures inside a pipe |
| US7426852B1 (en) | 2004-04-26 | 2008-09-23 | Expro Meters, Inc. | Submersible meter for measuring a parameter of gas hold-up of a fluid |
| WO2005116637A2 (en) * | 2004-05-17 | 2005-12-08 | Cidra Corporation | Apparatus and method for measuring the composition of a mixture |
| NO321752B1 (en) * | 2004-06-07 | 2006-06-26 | Roxar Flow Measurement As | System for sand detection in constrictions or currents in rudder |
| US7114401B2 (en) * | 2004-08-18 | 2006-10-03 | Baker Hughes Incorporated | Apparatus and methods for abrasive fluid flow meter |
| WO2006112878A2 (en) | 2004-09-16 | 2006-10-26 | Cidra Corporation | Apparatus and method for providing a fluid cut measurement of a multi-liquid mixture compensated for entrained gas |
| US7389687B2 (en) * | 2004-11-05 | 2008-06-24 | Cidra Corporation | System for measuring a parameter of an aerated multi-phase mixture flowing in a pipe |
| US7657392B2 (en) * | 2005-05-16 | 2010-02-02 | Cidra Corporate Services, Inc. | Method and apparatus for detecting and characterizing particles in a multiphase fluid |
| US7526966B2 (en) * | 2005-05-27 | 2009-05-05 | Expro Meters, Inc. | Apparatus and method for measuring a parameter of a multiphase flow |
| WO2006130499A2 (en) * | 2005-05-27 | 2006-12-07 | Cidra Corporation | An apparatus and method for fiscal measuring of an aerated fluid |
| US7249525B1 (en) | 2005-06-22 | 2007-07-31 | Cidra Corporation | Apparatus for measuring parameters of a fluid in a lined pipe |
| US8641813B2 (en) * | 2005-07-07 | 2014-02-04 | Expro Meters, Inc. | System and method for optimizing a gas/liquid separation process |
| US7603916B2 (en) | 2005-07-07 | 2009-10-20 | Expro Meters, Inc. | Wet gas metering using a differential pressure and a sonar based flow meter |
| US7503227B2 (en) * | 2005-07-13 | 2009-03-17 | Cidra Corporate Services, Inc | Method and apparatus for measuring parameters of a fluid flow using an array of sensors |
| EP1922527A1 (en) * | 2005-08-17 | 2008-05-21 | CiDra Corporation | A system and method for providing a compositional measurement of a mixture having entrained gas |
| NO325703B1 (en) * | 2006-03-16 | 2008-07-07 | Sensorteknikk As | Method of recording the characteristic state, quantity and composition of a streaming medium |
| US7454981B2 (en) * | 2006-05-16 | 2008-11-25 | Expro Meters. Inc. | Apparatus and method for determining a parameter in a wet gas flow |
| US7624650B2 (en) | 2006-07-27 | 2009-12-01 | Expro Meters, Inc. | Apparatus and method for attenuating acoustic waves propagating within a pipe wall |
| US7555945B2 (en) * | 2006-08-14 | 2009-07-07 | Board Of Trustees Of Michigan State University | Mass air flow sensor having off axis converging and diverging nozzles |
| US20080057848A1 (en) * | 2006-08-31 | 2008-03-06 | Honeywell International, Inc. | Venturi gate valve assembly for an auxiliary power unit |
| US7654155B2 (en) * | 2006-09-19 | 2010-02-02 | Weatherford/Lamb, Inc. | Wet-gas flowmeter |
| US7624651B2 (en) * | 2006-10-30 | 2009-12-01 | Expro Meters, Inc. | Apparatus and method for attenuating acoustic waves in pipe walls for clamp-on ultrasonic flow meter |
| US7673526B2 (en) * | 2006-11-01 | 2010-03-09 | Expro Meters, Inc. | Apparatus and method of lensing an ultrasonic beam for an ultrasonic flow meter |
| EP2092278A2 (en) | 2006-11-09 | 2009-08-26 | Expro Meters, Inc. | Apparatus and method for measuring a fluid flow parameter within an internal passage of an elongated body |
| US7660648B2 (en) * | 2007-01-10 | 2010-02-09 | Halliburton Energy Services, Inc. | Methods for self-balancing control of mixing and pumping |
| US7726876B2 (en) * | 2007-03-14 | 2010-06-01 | Entegris, Inc. | System and method for non-intrusive thermal monitor |
| KR100937472B1 (en) * | 2007-09-07 | 2010-01-19 | 주식회사 녹색기술연구소 | Differential pressure flowmeter |
| US7637167B2 (en) * | 2008-04-25 | 2009-12-29 | Schlumberger Technology Corporation | Apparatus and method for characterizing two phase fluid flow |
| BRPI0804823B1 (en) * | 2008-11-05 | 2018-09-11 | Surco Tecnologia Industrial Ltda. | dual temperature and pressure and flow optical measurement equipment |
| US8061219B2 (en) * | 2010-03-02 | 2011-11-22 | Schlumberger Technology Corporation | Flow restriction insert for differential pressure measurement |
| US20110226143A1 (en) * | 2010-03-22 | 2011-09-22 | Michael Cudworth | Single stencil patchwork system |
| US8429985B2 (en) | 2010-08-24 | 2013-04-30 | General Electric Company | Apparatus for use in determining a plurality of characteristics of a multiphase flow within a pipe |
| US8631824B2 (en) | 2010-08-25 | 2014-01-21 | Ecolab Usa Inc. | Apparatus, method and system for dispensing liquid products to two or more appliances |
| US8742883B2 (en) | 2010-08-25 | 2014-06-03 | Ecolab Usa Inc. | Method and system for monitoring operation of a dispensing system |
| US9176089B2 (en) | 2013-03-29 | 2015-11-03 | Stmicroelectronics Pte Ltd. | Integrated multi-sensor module |
| US9618653B2 (en) * | 2013-03-29 | 2017-04-11 | Stmicroelectronics Pte Ltd. | Microelectronic environmental sensing module |
| US9000542B2 (en) | 2013-05-31 | 2015-04-07 | Stmicroelectronics Pte Ltd. | Suspended membrane device |
| GB201317486D0 (en) * | 2013-10-03 | 2013-11-20 | Steven Richard | Improvements in or related to flow metering |
| US10335808B2 (en) | 2014-10-29 | 2019-07-02 | Elliptic Works, LLC | Flow control devices and related systems |
| US10126266B2 (en) | 2014-12-29 | 2018-11-13 | Concentric Meter Corporation | Fluid parameter sensor and meter |
| EP3215812B1 (en) | 2014-12-29 | 2020-10-07 | Concentric Meter Corporation | Fluid parameter sensor and meter |
| US10107784B2 (en) | 2014-12-29 | 2018-10-23 | Concentric Meter Corporation | Electromagnetic transducer |
| CN105547379B (en) * | 2015-12-22 | 2019-08-06 | 中国石油天然气股份有限公司 | A kind of petroleum downhole flowmeter based on dual-polarization state optical fibre device |
| US10704425B2 (en) | 2016-07-14 | 2020-07-07 | General Electric Company | Assembly for a gas turbine engine |
| US10429330B2 (en) | 2016-07-18 | 2019-10-01 | Stmicroelectronics Pte Ltd | Gas analyzer that detects gases, humidity, and temperature |
| US10254261B2 (en) | 2016-07-18 | 2019-04-09 | Stmicroelectronics Pte Ltd | Integrated air quality sensor that detects multiple gas species |
| US10557812B2 (en) | 2016-12-01 | 2020-02-11 | Stmicroelectronics Pte Ltd | Gas sensors |
| US10648841B1 (en) * | 2019-03-08 | 2020-05-12 | Saudi Arabian Oil Company | Multiphase flow meter combining extended throat venturi with microwave resonators |
| EP3948173A4 (en) * | 2019-04-01 | 2022-12-14 | Feelit Technologies Ltd. | Methods and devices for determination of differential parameters associated with fluid flow within a conduit |
Family Cites Families (108)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US3149492A (en) | 1961-03-06 | 1964-09-22 | Astra Inc | Fluid pressure gauge |
| US3851521A (en) | 1973-01-19 | 1974-12-03 | M & J Valve Co | System and method for locating breaks in liquid pipelines |
| FR2357868A1 (en) | 1976-07-07 | 1978-02-03 | Schlumberger Compteurs | Vortex type fluid flow meter - uses differential pressure sensor outside pipe linked to two pressure valves inside pipe |
| DE2636737C2 (en) | 1976-08-14 | 1978-06-22 | Danfoss A/S, Nordborg (Daenemark) | Device for the ultrasonic measurement of physical quantities of flowing media |
| US4080837A (en) | 1976-12-03 | 1978-03-28 | Continental Oil Company | Sonic measurement of flow rate and water content of oil-water streams |
| DE2703439C3 (en) | 1977-01-28 | 1979-08-09 | Danfoss A/S, Nordborg (Daenemark) | Device for measuring physical quantities of a liquid with two ultrasonic transducers |
| US4164865A (en) | 1977-02-22 | 1979-08-21 | The Perkin-Elmer Corporation | Acoustical wave flowmeter |
| US4144768A (en) | 1978-01-03 | 1979-03-20 | The Boeing Company | Apparatus for analyzing complex acoustic fields within a duct |
| JPS5543471A (en) | 1978-09-25 | 1980-03-27 | Nissan Motor Co Ltd | Karman vortex flow meter |
| US4236406A (en) | 1978-12-11 | 1980-12-02 | Conoco, Inc. | Method and apparatus for sonic velocity type water cut measurement |
| JPS5750612A (en) * | 1980-09-12 | 1982-03-25 | Nippon Telegr & Teleph Corp <Ntt> | Measuring apparatus for flow rate of gas |
| DE3172259D1 (en) | 1980-11-21 | 1985-10-17 | Ici Plc | Method and apparatus for leak detection in pipelines |
| US4520320A (en) | 1981-09-10 | 1985-05-28 | The United States Of America As Represented By The Secretary Of Commerce | Synchronous phase marker and amplitude detector |
| US4445389A (en) | 1981-09-10 | 1984-05-01 | The United States Of America As Represented By The Secretary Of Commerce | Long wavelength acoustic flowmeter |
| US4499418A (en) | 1982-08-05 | 1985-02-12 | Texaco Inc. | Water cut monitoring means and method |
| US4546649A (en) | 1982-09-27 | 1985-10-15 | Kantor Frederick W | Instrumentation and control system and method for fluid transport and processing |
| JPS6079273A (en) * | 1983-10-06 | 1985-05-07 | Nippon Kagaku Kogyo Kk | Laser doppler current meter |
| US4576043A (en) * | 1984-05-17 | 1986-03-18 | Chevron Research Company | Methods for metering two-phase flow |
| US4515473A (en) | 1984-09-13 | 1985-05-07 | Geo-Centers, Inc. | Photoelastic stress sensor signal processor |
| CA1257712A (en) | 1985-11-27 | 1989-07-18 | Toshimasa Tomoda | Metering choke |
| US4862750A (en) | 1987-02-11 | 1989-09-05 | Nice Gerald J | Vortex shedding fluid velocity meter |
| JPH0423560Y2 (en) | 1987-02-17 | 1992-06-02 | ||
| US4884457A (en) | 1987-09-30 | 1989-12-05 | Texaco Inc. | Means and method for monitoring the flow of a multi-phase petroleum stream |
| US4864868A (en) | 1987-12-04 | 1989-09-12 | Schlumberger Industries, Inc. | Vortex flowmeter transducer |
| NO166379C (en) | 1987-12-18 | 1991-07-10 | Sensorteknikk As | PROCEDURE FOR REGISTERING MULTIPHASE FLOWS THROUGH A TRANSPORT SYSTEM. |
| US4858474A (en) * | 1987-12-30 | 1989-08-22 | General Electric Co. | Angular momentum mass flowmeter with optical pickoff |
| US4813270A (en) | 1988-03-04 | 1989-03-21 | Atlantic Richfield Company | System for measuring multiphase fluid flow |
| US4896540A (en) | 1988-04-08 | 1990-01-30 | Parthasarathy Shakkottai | Aeroacoustic flowmeter |
| US5363342A (en) | 1988-04-28 | 1994-11-08 | Litton Systems, Inc. | High performance extended fiber optic hydrophone |
| GB8817348D0 (en) | 1988-07-21 | 1988-08-24 | Imperial College | Gas/liquid flow measurement |
| US4978863A (en) * | 1988-09-06 | 1990-12-18 | The Dow Chemical Company | Method and apparatus for fiber optic backscattered light measurement to determine flow rates of multi-phase streams |
| FR2637075B1 (en) | 1988-09-23 | 1995-03-10 | Gaz De France | METHOD AND DEVICE FOR INDICATING THE FLOW OF A COMPRESSIBLE FLUID FLOWING IN A REGULATOR, AND VIBRATION SENSOR USED FOR THIS PURPOSE |
| US4950883A (en) | 1988-12-27 | 1990-08-21 | United Technologies Corporation | Fiber optic sensor arrangement having reflective gratings responsive to particular wavelengths |
| JPH02203230A (en) | 1989-01-31 | 1990-08-13 | Daikin Ind Ltd | Detector converter for variation in pressure in tube |
| US4947127A (en) | 1989-02-23 | 1990-08-07 | Texaco Inc. | Microwave water cut monitor |
| US4932262A (en) | 1989-06-26 | 1990-06-12 | General Motors Corporation | Miniature fiber optic pressure sensor |
| US4976157A (en) * | 1989-11-08 | 1990-12-11 | The Babcock & Wilcox Company | Fiber optic flow sensor |
| US5024099A (en) | 1989-11-20 | 1991-06-18 | Setra Systems, Inc. | Pressure transducer with flow-through measurement capability |
| US4996419A (en) | 1989-12-26 | 1991-02-26 | United Technologies Corporation | Distributed multiplexed optical fiber Bragg grating sensor arrangeement |
| US5317576A (en) | 1989-12-26 | 1994-05-31 | United Technologies Corporation | Continously tunable single-mode rare-earth doped pumped laser arrangement |
| US5152181A (en) | 1990-01-19 | 1992-10-06 | Lew Hyok S | Mass-volume vortex flowmeter |
| US5115670A (en) | 1990-03-09 | 1992-05-26 | Chevron Research & Technology Company | Measurement of fluid properties of two-phase fluids using an ultrasonic meter |
| US5099697A (en) * | 1990-04-02 | 1992-03-31 | Agar Corporation Ltd. | Two and three-phase flow measurement |
| US5040415A (en) | 1990-06-15 | 1991-08-20 | Rockwell International Corporation | Nonintrusive flow sensing system |
| FR2671877B1 (en) | 1991-01-22 | 1993-12-03 | Centre Nal Recherc Scientifique | METHOD AND DEVICE FOR MEASURING INSTANT FLOW SPEED. |
| GB2253907B (en) | 1991-03-21 | 1995-05-24 | Halliburton Logging Services | Device for sensing fluid behaviour |
| US5218197A (en) | 1991-05-20 | 1993-06-08 | The United States Of America As Represented By The Secretary Of The Navy | Method and apparatus for the non-invasive measurement of pressure inside pipes using a fiber optic interferometer sensor |
| US5207107A (en) | 1991-06-20 | 1993-05-04 | Exxon Research And Engineering Company | Non-intrusive flow meter for the liquid based on solid, liquid or gas borne sound |
| JPH0820295B2 (en) | 1991-08-01 | 1996-03-04 | マイクロ モーション，インコーポレイティド | Coriolis effect mass flow meter |
| US5509311A (en) | 1991-10-08 | 1996-04-23 | Lew; Hyok S. | Dynamically isolated vortex sensing pressure transducer |
| NO174643C (en) | 1992-01-13 | 1994-06-08 | Jon Steinar Gudmundsson | Apparatus and method for determining flow rate and gas / liquid ratio in multi-phase streams |
| GB2282881B (en) | 1992-05-22 | 1996-04-10 | Commw Scient Ind Res Org | Method and apparatus for the measurement of the mass flowrates of fluid components in a multiphase slug flow |
| JPH0682281A (en) | 1992-09-01 | 1994-03-22 | Yokogawa Electric Corp | Vortex flowmeter |
| US5372046A (en) | 1992-09-30 | 1994-12-13 | Rosemount Inc. | Vortex flowmeter electronics |
| US5398542A (en) | 1992-10-16 | 1995-03-21 | Nkk Corporation | Method for determining direction of travel of a wave front and apparatus therefor |
| US5361130A (en) | 1992-11-04 | 1994-11-01 | The United States Of America As Represented By The Secretary Of The Navy | Fiber grating-based sensing system with interferometric wavelength-shift detection |
| US5360331A (en) | 1993-01-05 | 1994-11-01 | Dynisco, Inc. | Injection molding machine pressure transducer |
| US5513913A (en) | 1993-01-29 | 1996-05-07 | United Technologies Corporation | Active multipoint fiber laser sensor |
| US5347873A (en) | 1993-04-09 | 1994-09-20 | Badger Meter, Inc. | Double wing vortex flowmeter with strouhal number corrector |
| IT1262407B (en) | 1993-09-06 | 1996-06-19 | Finmeccanica Spa | INSTRUMENTATION USING INTEGRATED OPTIC COMPONENTS FOR DIAGNOSTICS OF PARTS WITH FIBER OPTIC SENSORS INCLUDED OR FIXED ON THE SURFACE. |
| US5426297A (en) | 1993-09-27 | 1995-06-20 | United Technologies Corporation | Multiplexed Bragg grating sensors |
| US5401956A (en) | 1993-09-29 | 1995-03-28 | United Technologies Corporation | Diagnostic system for fiber grating sensors |
| US6003383A (en) | 1994-03-23 | 1999-12-21 | Schlumberger Industries, S.A. | Vortex fluid meter incorporating a double obstacle |
| FR2720498B1 (en) * | 1994-05-27 | 1996-08-09 | Schlumberger Services Petrol | Multiphase flowmeter. |
| US5842374A (en) | 1994-06-02 | 1998-12-01 | Changmin Co., Ltd. | Measuring method of a wide range level and an apparatus thereof |
| FR2721398B1 (en) | 1994-06-21 | 1996-08-23 | Inst Francais Du Petrole | Method and device for monitoring, by periodic excitation, a flow of particles in a conduit. |
| 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 |
| GB9419006D0 (en) | 1994-09-21 | 1994-11-09 | Sensor Dynamics Ltd | Apparatus for sensor installation |
| US5741980A (en) | 1994-11-02 | 1998-04-21 | Foster-Miller, Inc. | Flow analysis system and method |
| GB9425463D0 (en) * | 1994-12-16 | 1995-02-15 | Wood Group Production Technolo | Flowmeter |
| US5959547A (en) | 1995-02-09 | 1999-09-28 | Baker Hughes Incorporated | Well control systems employing downhole network |
| US5730219A (en) | 1995-02-09 | 1998-03-24 | Baker Hughes Incorporated | Production wells having permanent downhole formation evaluation sensors |
| US5732776A (en) | 1995-02-09 | 1998-03-31 | Baker Hughes Incorporated | Downhole production well control system and method |
| US5706896A (en) | 1995-02-09 | 1998-01-13 | Baker Hughes Incorporated | Method and apparatus for the remote control and monitoring of production wells |
| NO317626B1 (en) | 1995-02-09 | 2004-11-29 | Baker Hughes Inc | Device for blocking tool transport in a production well |
| JP3803417B2 (en) | 1995-04-11 | 2006-08-02 | テルモ カーディオバスキュラー システムズ コーポレイション | Combination of mounting pad and level sensor ultrasonic transducer and mounting mechanism for mounting the sensor on the wall |
| US5576497A (en) | 1995-05-09 | 1996-11-19 | The Foxboro Company | Adaptive filtering for a vortex flowmeter |
| US5996690A (en) | 1995-06-06 | 1999-12-07 | Baker Hughes Incorporated | Apparatus for controlling and monitoring a downhole oil/water separator |
| US5576495A (en) * | 1995-10-23 | 1996-11-19 | The Babcock & Wilcox Company | Two phase flow meter |
| US5907104A (en) | 1995-12-08 | 1999-05-25 | Direct Measurement Corporation | Signal processing and field proving methods and circuits for a coriolis mass flow meter |
| US5670720A (en) | 1996-01-11 | 1997-09-23 | Morton International, Inc. | Wire-wrap low pressure sensor for pressurized gas inflators |
| GB2320731B (en) | 1996-04-01 | 2000-10-25 | Baker Hughes Inc | Downhole flow control devices |
| US5642098A (en) | 1996-04-18 | 1997-06-24 | Oems Corporation | Capacitive oil water emulsion sensor system |
| IE76714B1 (en) | 1996-04-19 | 1997-10-22 | Auro Environmental Ltd | Apparatus for measuring the velocity of a fluid flowing in a conduit |
| FR2748816B1 (en) | 1996-05-17 | 1998-07-31 | Schlumberger Ind Sa | ULTRASONIC DEVICE FOR MEASURING THE FLOW SPEED OF A FLUID |
| FR2749080B1 (en) | 1996-05-22 | 1998-08-07 | Schlumberger Services Petrol | METHOD AND APPARATUS FOR OPTICAL PHASE DISCRIMINATION FOR THREE-PHASE FLUID |
| US5708211A (en) | 1996-05-28 | 1998-01-13 | Ohio University | Flow regime determination and flow measurement in multiphase flow pipelines |
| US5680489A (en) | 1996-06-28 | 1997-10-21 | The United States Of America As Represented By The Secretary Of The Navy | Optical sensor system utilizing bragg grating sensors |
| US5939643A (en) | 1996-08-21 | 1999-08-17 | Endress + Hauser Flowtec Ag | Vortex flow sensor with a cylindrical bluff body having roughned surface |
| US5689540A (en) | 1996-10-11 | 1997-11-18 | Schlumberger Technology Corporation | X-ray water fraction meter |
| US5842347A (en) | 1996-10-25 | 1998-12-01 | Sengentrix, Inc. | Method and apparatus for monitoring the level of liquid nitrogen in a cryogenic storage tank |
| US5845033A (en) | 1996-11-07 | 1998-12-01 | The Babcock & Wilcox Company | Fiber optic sensing system for monitoring restrictions in hydrocarbon production systems |
| GB9624899D0 (en) | 1996-11-29 | 1997-01-15 | Schlumberger Ltd | Method and apparatus for measuring flow in a horizontal borehole |
| US5963880A (en) | 1997-04-29 | 1999-10-05 | Schlumberger Industries, Inc. | Method for predicting water meter accuracy |
| US6002985A (en) | 1997-05-06 | 1999-12-14 | Halliburton Energy Services, Inc. | Method of controlling development of an oil or gas reservoir |
| US5925879A (en) | 1997-05-09 | 1999-07-20 | Cidra Corporation | Oil and gas well packer having fiber optic Bragg Grating sensors for downhole insitu inflation monitoring |
| FR2764694B1 (en) | 1997-06-17 | 1999-09-03 | Aerospatiale | DEVICE FOR MEASURING NOISE IN A CONDUIT BROUGHT BY A FLUID |
| US6016702A (en) | 1997-09-08 | 2000-01-25 | Cidra Corporation | High sensitivity fiber optic pressure sensor for use in harsh environments |
| US5992519A (en) | 1997-09-29 | 1999-11-30 | Schlumberger Technology Corporation | Real time monitoring and control of downhole reservoirs |
| US6009216A (en) | 1997-11-05 | 1999-12-28 | Cidra Corporation | Coiled tubing sensor system for delivery of distributed multiplexed sensors |
| JP3485542B2 (en) * | 1998-04-23 | 2004-01-13 | ラティス インテレクチュアル プロパティー リミテッド | Gas mass ratio measurement method |
| EP1090274B1 (en) | 1998-06-26 | 2017-03-15 | Weatherford Technology Holdings, LLC | Fluid parameter measurement in pipes using acoustic pressures |
| US6354147B1 (en) | 1998-06-26 | 2002-03-12 | Cidra Corporation | Fluid parameter measurement in pipes using acoustic pressures |
| NO310322B1 (en) * | 1999-01-11 | 2001-06-18 | Flowsys As | Painting of multiphase flow in rudder |
| US6158288A (en) | 1999-01-28 | 2000-12-12 | Dolphin Technology, Inc. | Ultrasonic system for measuring flow rate, fluid velocity, and pipe diameter based upon time periods |
| AU4593600A (en) * | 1999-05-10 | 2000-11-21 | Schlumberger Holdings Limited | Flow meter for multi-phase mixtures |
| US6233374B1 (en) | 1999-06-04 | 2001-05-15 | Cidra Corporation | Mandrel-wound fiber optic pressure sensor |
| US6279660B1 (en) | 1999-08-05 | 2001-08-28 | Cidra Corporation | Apparatus for optimizing production of multi-phase fluid |
-
2002
- 2002-06-28 US US10/186,382 patent/US6698297B2/en not_active Expired - Lifetime
-
2003
- 2003-06-09 WO PCT/GB2003/002511 patent/WO2004003484A2/en not_active Application Discontinuation
- 2003-06-09 AU AU2003241039A patent/AU2003241039A1/en not_active Abandoned
- 2003-06-09 GB GB0427454A patent/GB2405485B/en not_active Expired - Fee Related
- 2003-06-09 CA CA2489944A patent/CA2489944C/en not_active Expired - Fee Related
Also Published As
| Publication number | Publication date |
|---|---|
| GB2405485B (en) | 2006-05-24 |
| GB2405485A (en) | 2005-03-02 |
| GB0427454D0 (en) | 2005-01-19 |
| WO2004003484A3 (en) | 2004-04-15 |
| US20040000197A1 (en) | 2004-01-01 |
| US6698297B2 (en) | 2004-03-02 |
| AU2003241039A1 (en) | 2004-01-19 |
| WO2004003484A2 (en) | 2004-01-08 |
| CA2489944A1 (en) | 2004-01-08 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CA2489944C (en) | Venturi augmented flow meter | |
| US7526966B2 (en) | Apparatus and method for measuring a parameter of a multiphase flow | |
| US7437946B2 (en) | Apparatus and method for measuring a parameter of a multiphase flow | |
| US7340353B2 (en) | Dual function flow measurement apparatus having an array of sensors | |
| US7380438B2 (en) | Apparatus and method for providing a fluid cut measurement of a multi-liquid mixture compensated for entrained gas | |
| US7295933B2 (en) | Configurable multi-function flow measurement apparatus having an array of sensors | |
| US7302861B2 (en) | Portable flow measurement apparatus having an array of sensors | |
| US7322245B2 (en) | Apparatus and method for measuring a fluid flowing in a pipe using acoustic pressures | |
| US9347310B2 (en) | Multiphase flowmeter for subsea applications | |
| EP1751503B1 (en) | Apparatus and method for measuring the composition of a mixture flowing in a pipe | |
| US20050061060A1 (en) | Apparatus and method for providing a density measurement augmented for entrained gas | |
| EP1982169B1 (en) | Apparatus and method for measuring parameters of a multiphase fluid flow | |
| WO1995033980A1 (en) | Multiphase fluid flow rate and density measurement | |
| CA2537933C (en) | An apparatus and method for providing a density measurement augmented for entrained gas | |
| RU2262082C2 (en) | Device for measuring gas-liquid fluid flow rate |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| EEER | Examination request | ||
| MKLA | Lapsed |
Effective date: 20170609 |