CA2399536A1 - Improved method and system for measuring multiphase flow using multiple pressure differentials - Google Patents
Improved method and system for measuring multiphase flow using multiple pressure differentials Download PDFInfo
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- CA2399536A1 CA2399536A1 CA002399536A CA2399536A CA2399536A1 CA 2399536 A1 CA2399536 A1 CA 2399536A1 CA 002399536 A CA002399536 A CA 002399536A CA 2399536 A CA2399536 A CA 2399536A CA 2399536 A1 CA2399536 A1 CA 2399536A1
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- 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
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- 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
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01F—MEASURING VOLUME, VOLUME FLOW, MASS FLOW OR LIQUID LEVEL; METERING BY VOLUME
- G01F15/00—Details of, or accessories for, apparatus of groups G01F1/00 - G01F13/00 insofar as such details or appliances are not adapted to particular types of such apparatus
- G01F15/08—Air or gas separators in combination with liquid meters; Liquid separators in combination with gas-meters
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Abstract
An improved method and system for measuring a multi-phase flow in a pressure flow meter. An extended venturi (114) is used and pressure of the multi-phas e flow is measured at three or more positions in the venturi, which define two or more pressure differentials in the flow conduit. The differential pressur es are then used to calculate the mass flow of the gas phases, the total mass flow, and the liquid phase. The method for determining the mass flow of the high void fraction fluid flow and the gas flow includes certain steps. The first step is calculating a gas density for the gas flow (210). The next two steps are finding a normalized gas mass flow rate through the venturi and computing a gas mass flow rate (220). The following step is estimating the g as velocity in the venturi tube throat (230). The next step is calculating the pressure drop experienced by the gas phase due to work performed by the gas phase in accelerating the liquid phase between the upstream pressure measuri ng point (142) and the pressure measuring point in the venturi throat (240, 250 ).
Description
IMPROVED METHOD AND SYSTEM FOR MEASURING MULTIPHASE
FLOW USING MULTIPLE PRESSURE DIFFERENTIALS
CONTRACTUAL ORIGIN OF THE INVENTION
This invention was made with United States Government support under Contract No. DE-AC07-94ID13223, now Contract No. DE-AC07-99ID13727 1 o awarded by the United States Department of Energy. The United States Government has certain rights in the invention.
RELATED APPLICATIONS
This application claims priority from two United States continuation-in-part patent applications, S/N 09/401,375, filed September 22, 1999 and S/N
09/400,946, filed September 22, 1999.
BACKGROUND OF THE INVENTION
Field of the Invention 2 0 The present invention relates to a flow meter for measuring the flow of very high void fraction multi-phase fluid streams. More particularly, the present invention relates to an apparatus and method in which multiple pressure differentials are used to determine mass flow rates of gas and liquid phases of a predominantly gas fluid stream to thereby determine the mass flow rate of each phase.
State of the Art There are many situations where it is desirable to monitor multi-phase fluid streams prior to separation. For example, in oil well or gas well management, it is important to know the relative quantities of gas and liquid in a multi-phase fluid 3 0 stream, to thereby enable determination of the amount of gas, etc.
actually obtained.
This is of critical importance in situations, such as off shore drilling, in which it is common for the production lines of several different companies to be tied into a common distribution line to carry the fuel back to shore. In the prior art, a common method for metering a gas is to separate out the liquid phase, but a separation system in not desirable for fiscal reasons. When multiple production lines feed into a common distribution line, it is important to know the flow rates from each production line to thereby provide an accurate accounting for the production facilities.
In recent years, the metering of mufti-phase fluid streams prior to l0 separation has achieved increased attention. Significant progress has been made in the metering of mufti-phase fluids by first homogenizing the flow in a mixer then metering the pseudo single phase fluid in a venturi in concert with a gamma densitometer or similar device. This approach relies on the successful creation of a homogenous mixture with equal phase velocities, which behaves as if it were a single phase fluid with mixture density p=apg+(1-a)pl where a is the volume fraction of the gas phase, and pg is the gas phase density and p, is the liquid phase density. This technique works well for flows which after homogenizing the continuous phase is a liquid phase. While the upper limit of applicability of this approach is ill defined, it is generally agreed that for void fractions greater than 2 0 about ninety to ninety-five percent (90-95%) a homogenous mixture is very difficult to create or sustain. The characteristic unhomogenized flow in this void fraction range is that of an annular or ring shaped flow configuration. The gas phase flows in the center of the channel and the liquid phase adheres to and travels along the sidewall of the conduit as a thick film. Depending on the 2 5 relative flow rates of each phase, significant amounts of the denser liquid phase may also become entrained in the gas phase and be conveyed as dispersed droplets. Nonetheless, a liquid filin is always present on the wall of the conduit.
While the liquid generally occupies less than five percent (5%) of the cross-sectional volume of the flow channel, the mass flow rate of the liquid may be 3 o comparable to or even several times greater than that of the gas phase due to its greater density.
The fact that the phases are partially or fully separated, and consequently have phase velocities which are significantly different (slip), complicates the metering problem. The presence of the liquid phase distorts the gas mass flow rate measurements and causes conventional meters, such as orifice plates or venturi meters, to overestimate the flow rate of the gas phase. For example the gas mass flow can be estimated using the standard equation mg = AC' 4 2pg4P
1- ~i where m~ is the gas mass flow rate, A is the area of the throat, OP is the measured pressure differential, pg the gas density at flow conditions, C~ the discharge coefficient, and Y is the expansion factor. In test samples using void fractions ranging from 0.997 to 0.95, the error in the measured gas mass flow rate ranges from 7% to 30%. It is important to note that the presence of the liquid phase increases the pressure drop in the venturi and results in over-predicting the true gas mass flow rate. The pressure drop is caused by the interaction between the gas and liquid phases. Liquid droplet acceleration by the gas, irreversible drag force work done by the gas phase in accelerating the liquid film and wall losses determine the magnitude of the observed pressure drop. In addition, the flow is complicated by the continuous entrainment of liquid into the gas, the redeposition 2 0 of liquid from the gas into the liquid film along the venturi length, and also by the presence of surface waves on the surface of the annular or ringed liquid phase film. The surface waves on the liquid create a roughened surface over which the gas must flow increasing the momentum loss due to the addition of drag at the liquid/gas interface.
FLOW USING MULTIPLE PRESSURE DIFFERENTIALS
CONTRACTUAL ORIGIN OF THE INVENTION
This invention was made with United States Government support under Contract No. DE-AC07-94ID13223, now Contract No. DE-AC07-99ID13727 1 o awarded by the United States Department of Energy. The United States Government has certain rights in the invention.
RELATED APPLICATIONS
This application claims priority from two United States continuation-in-part patent applications, S/N 09/401,375, filed September 22, 1999 and S/N
09/400,946, filed September 22, 1999.
BACKGROUND OF THE INVENTION
Field of the Invention 2 0 The present invention relates to a flow meter for measuring the flow of very high void fraction multi-phase fluid streams. More particularly, the present invention relates to an apparatus and method in which multiple pressure differentials are used to determine mass flow rates of gas and liquid phases of a predominantly gas fluid stream to thereby determine the mass flow rate of each phase.
State of the Art There are many situations where it is desirable to monitor multi-phase fluid streams prior to separation. For example, in oil well or gas well management, it is important to know the relative quantities of gas and liquid in a multi-phase fluid 3 0 stream, to thereby enable determination of the amount of gas, etc.
actually obtained.
This is of critical importance in situations, such as off shore drilling, in which it is common for the production lines of several different companies to be tied into a common distribution line to carry the fuel back to shore. In the prior art, a common method for metering a gas is to separate out the liquid phase, but a separation system in not desirable for fiscal reasons. When multiple production lines feed into a common distribution line, it is important to know the flow rates from each production line to thereby provide an accurate accounting for the production facilities.
In recent years, the metering of mufti-phase fluid streams prior to l0 separation has achieved increased attention. Significant progress has been made in the metering of mufti-phase fluids by first homogenizing the flow in a mixer then metering the pseudo single phase fluid in a venturi in concert with a gamma densitometer or similar device. This approach relies on the successful creation of a homogenous mixture with equal phase velocities, which behaves as if it were a single phase fluid with mixture density p=apg+(1-a)pl where a is the volume fraction of the gas phase, and pg is the gas phase density and p, is the liquid phase density. This technique works well for flows which after homogenizing the continuous phase is a liquid phase. While the upper limit of applicability of this approach is ill defined, it is generally agreed that for void fractions greater than 2 0 about ninety to ninety-five percent (90-95%) a homogenous mixture is very difficult to create or sustain. The characteristic unhomogenized flow in this void fraction range is that of an annular or ring shaped flow configuration. The gas phase flows in the center of the channel and the liquid phase adheres to and travels along the sidewall of the conduit as a thick film. Depending on the 2 5 relative flow rates of each phase, significant amounts of the denser liquid phase may also become entrained in the gas phase and be conveyed as dispersed droplets. Nonetheless, a liquid filin is always present on the wall of the conduit.
While the liquid generally occupies less than five percent (5%) of the cross-sectional volume of the flow channel, the mass flow rate of the liquid may be 3 o comparable to or even several times greater than that of the gas phase due to its greater density.
The fact that the phases are partially or fully separated, and consequently have phase velocities which are significantly different (slip), complicates the metering problem. The presence of the liquid phase distorts the gas mass flow rate measurements and causes conventional meters, such as orifice plates or venturi meters, to overestimate the flow rate of the gas phase. For example the gas mass flow can be estimated using the standard equation mg = AC' 4 2pg4P
1- ~i where m~ is the gas mass flow rate, A is the area of the throat, OP is the measured pressure differential, pg the gas density at flow conditions, C~ the discharge coefficient, and Y is the expansion factor. In test samples using void fractions ranging from 0.997 to 0.95, the error in the measured gas mass flow rate ranges from 7% to 30%. It is important to note that the presence of the liquid phase increases the pressure drop in the venturi and results in over-predicting the true gas mass flow rate. The pressure drop is caused by the interaction between the gas and liquid phases. Liquid droplet acceleration by the gas, irreversible drag force work done by the gas phase in accelerating the liquid film and wall losses determine the magnitude of the observed pressure drop. In addition, the flow is complicated by the continuous entrainment of liquid into the gas, the redeposition 2 0 of liquid from the gas into the liquid film along the venturi length, and also by the presence of surface waves on the surface of the annular or ringed liquid phase film. The surface waves on the liquid create a roughened surface over which the gas must flow increasing the momentum loss due to the addition of drag at the liquid/gas interface.
Other simple solutions have been proposed to solve the overestimation of gas mass flow rate under multi-phase conditions. For example, Murdock, ignores any interaction (momentum exchange) between the gas and liquid phases and proposed to calculate the gas mass flow if the ratio of gas to liquid mass flow is known in advance. See Murdock, J. W. (1962). Two Phase Flow Measurement with Orifices, ASME Journal of Basic Engineering, December, 419-433.
Unfortunately this method still has up to a 20% error rate or more.
Another example of a multi-phase measurement device in the prior art, is U.S. Patent No. 5,461,930, to Farchi, et al, which appears to teach the use of a water cut meter and a volumetric flow meter for measuring the gas and liquid phases. This invention is complicated and must use a positive displacement device to measure the liquid and gas flow rates so it can avoid the problem of slip between the gas and liquid phases. This system does not appear to be effective for liquid fractions below (5% - 10%). As mentioned earlier, other such prior art systems such as U.S. Patent No. 5,400,657 to Kolpak, et al, are only effective for multi-phase fluid flows where the gas fraction is 25% of the volume and the liquid is 75% of the volume.
Other volumetric measuring devices such as U.S. Patent No. 4,231,262 to Boll, et al, measure a flow of solids in a gas stream. For example, coal dust in a 2 0 nitrogen stream may be measured. Although these types of devices use pressure measuring structures, they are not able to address the problem of measuring a liquid fraction in a mufti-phase flow where the liquid phase is less than 10%
or even 5% of the overall volume. Measuring a liquid and gas is significantly different from measuring a gas with a solid particulate. The mass of the liquid is significant and not uniform throughout the gas. Incorrectly measuring the liquid throws off the overall measurements significantly. Furthermore, such devices which have two pressure measuring points on the venturi throat, do not take into 5 account the fact that a pressure drop is caused by the interaction between the gas and liquid phases and must be calculated for accordingly.
While past attempts at metering mufti-phase fluid streams have produced acceptable results below the ninety to ninety five percent (90-95%) void fraction range, they have not provided satisfactory metering for the very high void multi-phase flows which have less than five to ten (5-10%) non-gas phase by volume.
When discussing large amounts of natural gas or other fuel, even a few percent difference in the amount of non-gas phase can mean substantial differences in the value of a production facility. For example, if there are two wells which produce equal amounts of natural gas per day. The first well produces, by volume, 1 liquid and the second well produces S% liquid. If a conventional mass flow rate meter is relied upon to determine the amount of gas produced, the second well will erroneously appear to produce as much as 20 - 30 % more gas than the first well. Suppose further that the liquid produced is a light hydrocarbon liquid (e.g.
a gas condensate such as butane or propane) which is valuable in addition to the 2 0 natural gas produced. Conventional meters will provide no information about the amount of liquid produced. Then if the amount of liquid produced is equally divided between the two wells, the value of the production from the first well will be overestimated while the production from the second well will be underestimated. To properly value the gas and liquid production from both wells, a method of more accurately determining the mass flow rate of both the gas and liquid phases is required.
The prior art, however, has been generally incapable of accurately metering the very high void mufti-phase fluid streams. In light of the problems of the prior art, there is a need for an apparatus and method that is less complex and provides increased accuracy for very high void mufti-phase fluid streams.
Such an apparatus and method should be physically rugged, simple to use, and less expensive than current technology.
SUMMARY OF THE INVENTION
It is an object of the present invention to provide an improved apparatus and method for metering very high void mufti-phase fluid streams.
It is another object of the present invention to provide an apparatus and method which increases the accuracy of metering with respect to both the gas phase and the liquid phase when measuring very high void mufti-phase fluid streams.
It is still another object of the present invention to provide such an apparatus and method which does not require homogenization or separation of the 2 0 mufti-phase fluid in order to determine flow rate for each of the phases.
The above and other objects of the invention are realized in a specific apparatus for metering the phases of a multiple phase fluid. The flow meter includes a cross-sectional area change in the flow conduit such as a venturi with an elongate passage. Disposed along the elongate passage is a converging section, an extended throat section, and a diffuser. The flow meter also includes a plurality of pressure monitoring sites which are used to monitor pressure changes which occur as the mufti-phase fluid passes through the elongate passage and venturi. These pressure changes, in turn, can be processed to provide information as to the respective flow rates of the phases of the mufti-phase fluid.
By determining the flow rates of the components of the mufti-phase fluid, the amount of natural gas, etc., can be accurately determined and accounting improved.
In accordance with another aspect of the present invention a method for determining the mass flow of the high void fraction fluid flow and the gas flow includes a number of steps. The first step is calculating a gas density for the gas flow. The next two steps are finding the normalized gas mass flow rate through the venturi and then computing the actual gas mass flow rate. The following step is estimating the gas velocity in the venturi tube throat. The next step is calculating the additional pressure drop experienced by the gas phase due to work performed by the gas phase in accelerating the liquid phase between the upstream pressure measuring point and the pressure measuring point at the end of the venturi contraction or throat. Yet another step is estimating the liquid velocity in 2 0 the venturi throat using the calculated pressure drop experienced by the gas-phase due to work performed by the gas phase. Then, the friction loss is computed between the liquid phase and the conduit wall in the venturi tube using the liquid velocity. Finally, the total mass flow rate based on measured pressure in the venturi throat is calculated, and the liquid mass flow rate is calculated by subtracting the total mass flow rate and the gas mass flow rate.
BRIEF DESCRIPTION OF THE DRAWINGS
The above and other objects, features and advantages of the invention will become apparent from a consideration of the following detailed description presented in connection with the accompanying drawings in which:
FIG. 1 shows a side, cross-sectional view of a differential pressure flow meter with pressure measuring ports;
FIG. 2 shows a side, cross-sectional view of a differential pressure flow meter with an round shoulder;
FIG. 3 is a flow chart showing the steps required to calculate the mass flow in a multiphase flow.
DETAILED DESCRIPTION
Reference will now be made to the drawings in which the various elements of the present invention will be given numeral designations and in which the invention will be discussed so as to enable one skilled in the art to make and use the invention. It is to be understood that the following description 2 0 is only exemplary of the principles of the present invention, and should not be viewed as narrowing the pending claims.
Turning now to FIG. l, there is shown another differential pressure flow meter, generally indicated at 110. The differential pressure flow meter 110 includes a venturi 114 formed by a sidewall 118 which defines a fluid flow passage 122. The fluid flow passage 122 is segmented into an inlet section 126, a converging section 130, an extended throat section 134, a diffuser section 138 and an outlet section 140.
The geometry and conduit diameter of the flow obstruction will vary depending on the particular application. The conduit may be larger or smaller depending on the specific flow rate, pressure, temperature and other similar factors. One important characteristic of the flow meter is that the preferred contraction ratio in the conduit should be between .4 and .75. The contraction ratio is defined as the ratio of the throat diameter 134 to the upstream conduit diameter 122. It is also important that the length of the throat is at least ten times the diameter of the throat. Of course, other throat lengths may be used.
An example of one possible set of conduit measurements will now be given, but it should be realized that the actual geometry will depend on the volume and size of the specific application. In one embodiment of the invention, the inlet section 126 has a diameter of about 3.8 cm adjacent the opening 142 at the upstream, proximal end 114a of the venturi 114. The converging section 130 tapers inwardly from the inlet section 126 at an angle of about ten degrees (10°) until it connects with the extended throat section 134, which has a diameter of 2 0 about 2.5 cm. The extended throat section 134 remains substantially the same diameter throughout its length and may be about 30 cm long to provide ample length to determine acceleration differences between the various phases. At the end of the extended throat section 134b, the diffuser section 138 tapers outwardly at an angle of about three degrees (3°) until the diameter of the outlet section passage 140 is substantially the same as that at the inlet section 126 (i.e. 3 cm). It should be realized that many other specific geometric configurations could be defined which have characteristics similar to the example above.
5 In order to monitor the pressure differentials caused by the changes in fluid velocity, the differential pressure flow meter shown in FIG. 1 utilizes up to four different measurement points. Each pair of pressure measurement points defines a pressure differential. Only two pressure differential measurements are required to determine the gas and liquid flow rates. The preferred pressure 10 differentials are OP3 and OP2. Pressure differential number three (0P3) is defined as the pressure change between points 150 and 154. Pressure differential number two (0P2) is between points 154 and 158. The pressure differential OPZ is important because it is used for the calculation of the pressure drop experienced by the gas phase due to the work performed by the gas phase in accelerating the liquid phase.
It should also be apparent based on this disclosure that the combination of pressure differentials OP3 and OPo or OPZ and OPo may be used instead. Each of these combinations work equally well, with the exception that the numerical constants in the algorithm change. It is also important that an absolute pressure 2 0 and temperature measurement will be provided at the venturi inlet 142.
Now the pressure ports will be described more specifically. A first pressure measuring port 150 is disposed to measure the pressure in the inlet section 142. The first pressure measuring port 150 is connected to a pressure monitoring means, such as a pressure transducer 151, to provide a pressure reading.
A second pressure measuring port 154 is provided at the entrance of the extended throat section 134. The second pressure measuring port 154 is disposed adjacent the upstream, proximal end 134a of the extended throat section 134. A pressure transducer 151 is also coupled to the second pressure measuring port 154.
Distally from the second pressure measuring port 154, but still within the extended throat section 134, is a third pressure monitoring port 158.
Preferably, the third pressure monitoring port 158 is disposed adjacent the distal end 134b of the extended throat section 134, and adjacent the beginning 138a of the diffuser section 138.
The respective pressure measuring ports 150, 154, and 158 are disposed in communication with a flow processor 153 or similar mechanism through the pressure monitoring means or pressure transducers 151, 155, and 159. The flow processor 153 enables the acquisition of the measured pressure differentials, and thus fluid flow rates in accordance with the present invention. Further, an accurate determination of the relative acceleration of the two phases can also be obtained by comparing the pressure drop between the inlet section 126 (through 2 0 measuring port 150) and the distal end 134b of the extended throat section (through measuring port 1 S 8), as indicated at OPo In an alternative embodiment of the invention, a fourth pressure measuring port 161 is disposed at the end of the extended throat 134b. A fifth pressure measuring port 162 is disposed in the outlet section 140 adjacent to the distal end 138b of the diffuser section 138. Both of these pressure measuring ports are coupled to pressure monitoring means or pressure transducer 163. The fourth and fifth monitoring ports allow a pressure differential OP, to be measured.
The pressure differential (0P1) between the extended throat section 134 and the distal end 138b of the diffuser section 138 can also be analyzed.
It should also be realized that different angles and lengths can be used for the venturi constriction and the extended throat of the venturi tube. In fact, the converging section of the venturi is not required to gradually taper. FIG. 2 shows a converging section 172 as formed by an annular shoulder in a venturi tube to reduce the cross-sectional area of the inlet section. The preferred size of the radius of curvature for an annular shoulder 172 is about 0.652 cm. The converging section can also be formed by placing a solid object in the conduit which occupies part but not all of the conduit cross-section.
It is vital that the correct method be used in the current invention to estimate the gas and fluid mass flow. Otherwise errors in the range of 20% or more will be introduced into the measurements, as in the prior art. Reliable metering of high void fraction multi-phase flows over a wide range of conditions (liquid loading, pressure, temperature, and gas and liquid composition) without 2 0 prior knowledge of the liquid and gas mass flow rates requires a different approach than the simple modification of the single phase meter readings as done in the prior art. Conceptually, the method of metering a fluid flow described here is to impose an acceleration or pressure drop on the flow field via a structure or venturi constriction and then observe the pressure response of the device across two pressure differentials as described above. Because the mufti-phase pressure response differs significantly from that of a single-phase fluid, the measured pressure differentials are a unique function of the mass flow rates of each phase.
As described above, the gas and liquid phases are strongly coupled. When the gas phase accelerates in the converging section of the nozzle, the denser liquid phase velocity appreciably lags that of the lighter gas phase. In the extended throat region, the liquid phase continues to accelerate, ultimately approaching its equilibrium velocity with respect to the gas phase. Even at equilibrium, significant velocity differences or slip will exist between the gas and liquid phases. A method for accurately calculating the gas and liquid mass flows in an extended venturi tube will now be described. (A derivation of the method is shown later.) This method uses the four values which are determined though testing. These values are: ~P3 which is the measured pressure differential across the venturi contraction, OPZ which is the measured pressure differential across the extended venturi throat, P which is the absolute pressure upstream from the venturi (psi), and T which is the temperature of the upstream flow. These measured values are used with a number of predefined constants which will be defined as they are used. Alternatively, the pressure differentials 2 0 OP3 and OPo, or the pressure differentials OPo and OPz may be used.
First, the gas density for the gas flow must be calculated based on the current gas well pressure and temperature. This is done using the following equation which uses English units. Any other consistent set of units may also be used with appropriate modifications to the equations.
Equation 1 P + 14.7 60 + 459.67 rhog", = rhog 14.7 T+ 459.67 where rhog is the density of natural gas (i.e. a mixture methane and other hydrocarbon and non-hydrocarbon gases) at standard temperature (60 ° F) and pressure (1 atmosphere) for a specific well;
P is the pressure upstream from the venturi in pounds per square 1 o inch (psi); and T is the temperature upstream from the venturi in degrees Fahrenheit.
The value of rhog will be different for various natural gas compositions and must be supplied by the well operator. At the standard temperature (60° F) and pressure ( 1 atmosphere) the value of rhos for pure methane is 0.044 lb/ft3.
The second step is finding a normalized gas mass flow rate based on the square root of a pressure difference across the contraction multiplied by a first predetermined coefficient, and the square root of a measured pressure differential across a venturi throat. The normalized gas mass flow rate is found using the 2 0 following equation:
Equation 2 mgm= A+B OP3+C OPZ
where A, B, and C are experimentally determined constants required to calculate gas mass flow rate;
~P3 is the measured pressure differential across a venturi 5 contraction; and OPZ is the measured pressure differential across a venturi throat.
The preferred values for the constants in the equation above are as follows: A
is -0.0018104, B is 0.008104 and C is -0.0026832 when pressure is in pounds per square inch (psi), density in lbs/ft3 and mass flow rate in thousands of mass 10 lbs/minute. Of course, these numbers are determined experimentally and may change depending on the geometry of the venturi, the fluids used, and the system of units used.
Calculating the normalized gas mass flow rate is important because it allows the meter to be applied to the wells or situations where the pressure or 15 meter diameter for the liquids present are different than the conditions under which the meter was originally calibrated. This means that the meter does not need to be calibrated under conditions identical to those present in a particular application and that the meter may be sized to match the production rate from a particular well.
2 0 The functional form of Equation 2 is arnved at by derivation from the conservation of mass and energy followed by a simplifying approximation. Other functional forms of Equation 2 can be used with equivalent results. The functional form of Equation 2 is consistent with the conservation laws and provides a good representation of the calibration data.
The third step is computing a gas mass flow rate using the normalized gas mass flow rate, the gas density, and a contraction ratio of the venturi tube.
The equation for calculating the gas mass flow rate from these quantities is Equation 3 rho~,, mg - m~ ' A~ ' 1- ~ 4 where mgm is the normalized gas mass flow rate;
At is the venturi throat area;
(3 is the contraction ratio of the throat area; and rhog", is the gas density at current well conditions.
The fourth step is estimating the gas velocity in the venturi tube throat.
The equation for estimating the gas velocity is:
Equation 4 mg ug =
rhog ~ Al where m~ is the gas mass flow rate;
rhog is the density of the gas phase for a specific well; and At is the venturi throat area.
Unfortunately this method still has up to a 20% error rate or more.
Another example of a multi-phase measurement device in the prior art, is U.S. Patent No. 5,461,930, to Farchi, et al, which appears to teach the use of a water cut meter and a volumetric flow meter for measuring the gas and liquid phases. This invention is complicated and must use a positive displacement device to measure the liquid and gas flow rates so it can avoid the problem of slip between the gas and liquid phases. This system does not appear to be effective for liquid fractions below (5% - 10%). As mentioned earlier, other such prior art systems such as U.S. Patent No. 5,400,657 to Kolpak, et al, are only effective for multi-phase fluid flows where the gas fraction is 25% of the volume and the liquid is 75% of the volume.
Other volumetric measuring devices such as U.S. Patent No. 4,231,262 to Boll, et al, measure a flow of solids in a gas stream. For example, coal dust in a 2 0 nitrogen stream may be measured. Although these types of devices use pressure measuring structures, they are not able to address the problem of measuring a liquid fraction in a mufti-phase flow where the liquid phase is less than 10%
or even 5% of the overall volume. Measuring a liquid and gas is significantly different from measuring a gas with a solid particulate. The mass of the liquid is significant and not uniform throughout the gas. Incorrectly measuring the liquid throws off the overall measurements significantly. Furthermore, such devices which have two pressure measuring points on the venturi throat, do not take into 5 account the fact that a pressure drop is caused by the interaction between the gas and liquid phases and must be calculated for accordingly.
While past attempts at metering mufti-phase fluid streams have produced acceptable results below the ninety to ninety five percent (90-95%) void fraction range, they have not provided satisfactory metering for the very high void multi-phase flows which have less than five to ten (5-10%) non-gas phase by volume.
When discussing large amounts of natural gas or other fuel, even a few percent difference in the amount of non-gas phase can mean substantial differences in the value of a production facility. For example, if there are two wells which produce equal amounts of natural gas per day. The first well produces, by volume, 1 liquid and the second well produces S% liquid. If a conventional mass flow rate meter is relied upon to determine the amount of gas produced, the second well will erroneously appear to produce as much as 20 - 30 % more gas than the first well. Suppose further that the liquid produced is a light hydrocarbon liquid (e.g.
a gas condensate such as butane or propane) which is valuable in addition to the 2 0 natural gas produced. Conventional meters will provide no information about the amount of liquid produced. Then if the amount of liquid produced is equally divided between the two wells, the value of the production from the first well will be overestimated while the production from the second well will be underestimated. To properly value the gas and liquid production from both wells, a method of more accurately determining the mass flow rate of both the gas and liquid phases is required.
The prior art, however, has been generally incapable of accurately metering the very high void mufti-phase fluid streams. In light of the problems of the prior art, there is a need for an apparatus and method that is less complex and provides increased accuracy for very high void mufti-phase fluid streams.
Such an apparatus and method should be physically rugged, simple to use, and less expensive than current technology.
SUMMARY OF THE INVENTION
It is an object of the present invention to provide an improved apparatus and method for metering very high void mufti-phase fluid streams.
It is another object of the present invention to provide an apparatus and method which increases the accuracy of metering with respect to both the gas phase and the liquid phase when measuring very high void mufti-phase fluid streams.
It is still another object of the present invention to provide such an apparatus and method which does not require homogenization or separation of the 2 0 mufti-phase fluid in order to determine flow rate for each of the phases.
The above and other objects of the invention are realized in a specific apparatus for metering the phases of a multiple phase fluid. The flow meter includes a cross-sectional area change in the flow conduit such as a venturi with an elongate passage. Disposed along the elongate passage is a converging section, an extended throat section, and a diffuser. The flow meter also includes a plurality of pressure monitoring sites which are used to monitor pressure changes which occur as the mufti-phase fluid passes through the elongate passage and venturi. These pressure changes, in turn, can be processed to provide information as to the respective flow rates of the phases of the mufti-phase fluid.
By determining the flow rates of the components of the mufti-phase fluid, the amount of natural gas, etc., can be accurately determined and accounting improved.
In accordance with another aspect of the present invention a method for determining the mass flow of the high void fraction fluid flow and the gas flow includes a number of steps. The first step is calculating a gas density for the gas flow. The next two steps are finding the normalized gas mass flow rate through the venturi and then computing the actual gas mass flow rate. The following step is estimating the gas velocity in the venturi tube throat. The next step is calculating the additional pressure drop experienced by the gas phase due to work performed by the gas phase in accelerating the liquid phase between the upstream pressure measuring point and the pressure measuring point at the end of the venturi contraction or throat. Yet another step is estimating the liquid velocity in 2 0 the venturi throat using the calculated pressure drop experienced by the gas-phase due to work performed by the gas phase. Then, the friction loss is computed between the liquid phase and the conduit wall in the venturi tube using the liquid velocity. Finally, the total mass flow rate based on measured pressure in the venturi throat is calculated, and the liquid mass flow rate is calculated by subtracting the total mass flow rate and the gas mass flow rate.
BRIEF DESCRIPTION OF THE DRAWINGS
The above and other objects, features and advantages of the invention will become apparent from a consideration of the following detailed description presented in connection with the accompanying drawings in which:
FIG. 1 shows a side, cross-sectional view of a differential pressure flow meter with pressure measuring ports;
FIG. 2 shows a side, cross-sectional view of a differential pressure flow meter with an round shoulder;
FIG. 3 is a flow chart showing the steps required to calculate the mass flow in a multiphase flow.
DETAILED DESCRIPTION
Reference will now be made to the drawings in which the various elements of the present invention will be given numeral designations and in which the invention will be discussed so as to enable one skilled in the art to make and use the invention. It is to be understood that the following description 2 0 is only exemplary of the principles of the present invention, and should not be viewed as narrowing the pending claims.
Turning now to FIG. l, there is shown another differential pressure flow meter, generally indicated at 110. The differential pressure flow meter 110 includes a venturi 114 formed by a sidewall 118 which defines a fluid flow passage 122. The fluid flow passage 122 is segmented into an inlet section 126, a converging section 130, an extended throat section 134, a diffuser section 138 and an outlet section 140.
The geometry and conduit diameter of the flow obstruction will vary depending on the particular application. The conduit may be larger or smaller depending on the specific flow rate, pressure, temperature and other similar factors. One important characteristic of the flow meter is that the preferred contraction ratio in the conduit should be between .4 and .75. The contraction ratio is defined as the ratio of the throat diameter 134 to the upstream conduit diameter 122. It is also important that the length of the throat is at least ten times the diameter of the throat. Of course, other throat lengths may be used.
An example of one possible set of conduit measurements will now be given, but it should be realized that the actual geometry will depend on the volume and size of the specific application. In one embodiment of the invention, the inlet section 126 has a diameter of about 3.8 cm adjacent the opening 142 at the upstream, proximal end 114a of the venturi 114. The converging section 130 tapers inwardly from the inlet section 126 at an angle of about ten degrees (10°) until it connects with the extended throat section 134, which has a diameter of 2 0 about 2.5 cm. The extended throat section 134 remains substantially the same diameter throughout its length and may be about 30 cm long to provide ample length to determine acceleration differences between the various phases. At the end of the extended throat section 134b, the diffuser section 138 tapers outwardly at an angle of about three degrees (3°) until the diameter of the outlet section passage 140 is substantially the same as that at the inlet section 126 (i.e. 3 cm). It should be realized that many other specific geometric configurations could be defined which have characteristics similar to the example above.
5 In order to monitor the pressure differentials caused by the changes in fluid velocity, the differential pressure flow meter shown in FIG. 1 utilizes up to four different measurement points. Each pair of pressure measurement points defines a pressure differential. Only two pressure differential measurements are required to determine the gas and liquid flow rates. The preferred pressure 10 differentials are OP3 and OP2. Pressure differential number three (0P3) is defined as the pressure change between points 150 and 154. Pressure differential number two (0P2) is between points 154 and 158. The pressure differential OPZ is important because it is used for the calculation of the pressure drop experienced by the gas phase due to the work performed by the gas phase in accelerating the liquid phase.
It should also be apparent based on this disclosure that the combination of pressure differentials OP3 and OPo or OPZ and OPo may be used instead. Each of these combinations work equally well, with the exception that the numerical constants in the algorithm change. It is also important that an absolute pressure 2 0 and temperature measurement will be provided at the venturi inlet 142.
Now the pressure ports will be described more specifically. A first pressure measuring port 150 is disposed to measure the pressure in the inlet section 142. The first pressure measuring port 150 is connected to a pressure monitoring means, such as a pressure transducer 151, to provide a pressure reading.
A second pressure measuring port 154 is provided at the entrance of the extended throat section 134. The second pressure measuring port 154 is disposed adjacent the upstream, proximal end 134a of the extended throat section 134. A pressure transducer 151 is also coupled to the second pressure measuring port 154.
Distally from the second pressure measuring port 154, but still within the extended throat section 134, is a third pressure monitoring port 158.
Preferably, the third pressure monitoring port 158 is disposed adjacent the distal end 134b of the extended throat section 134, and adjacent the beginning 138a of the diffuser section 138.
The respective pressure measuring ports 150, 154, and 158 are disposed in communication with a flow processor 153 or similar mechanism through the pressure monitoring means or pressure transducers 151, 155, and 159. The flow processor 153 enables the acquisition of the measured pressure differentials, and thus fluid flow rates in accordance with the present invention. Further, an accurate determination of the relative acceleration of the two phases can also be obtained by comparing the pressure drop between the inlet section 126 (through 2 0 measuring port 150) and the distal end 134b of the extended throat section (through measuring port 1 S 8), as indicated at OPo In an alternative embodiment of the invention, a fourth pressure measuring port 161 is disposed at the end of the extended throat 134b. A fifth pressure measuring port 162 is disposed in the outlet section 140 adjacent to the distal end 138b of the diffuser section 138. Both of these pressure measuring ports are coupled to pressure monitoring means or pressure transducer 163. The fourth and fifth monitoring ports allow a pressure differential OP, to be measured.
The pressure differential (0P1) between the extended throat section 134 and the distal end 138b of the diffuser section 138 can also be analyzed.
It should also be realized that different angles and lengths can be used for the venturi constriction and the extended throat of the venturi tube. In fact, the converging section of the venturi is not required to gradually taper. FIG. 2 shows a converging section 172 as formed by an annular shoulder in a venturi tube to reduce the cross-sectional area of the inlet section. The preferred size of the radius of curvature for an annular shoulder 172 is about 0.652 cm. The converging section can also be formed by placing a solid object in the conduit which occupies part but not all of the conduit cross-section.
It is vital that the correct method be used in the current invention to estimate the gas and fluid mass flow. Otherwise errors in the range of 20% or more will be introduced into the measurements, as in the prior art. Reliable metering of high void fraction multi-phase flows over a wide range of conditions (liquid loading, pressure, temperature, and gas and liquid composition) without 2 0 prior knowledge of the liquid and gas mass flow rates requires a different approach than the simple modification of the single phase meter readings as done in the prior art. Conceptually, the method of metering a fluid flow described here is to impose an acceleration or pressure drop on the flow field via a structure or venturi constriction and then observe the pressure response of the device across two pressure differentials as described above. Because the mufti-phase pressure response differs significantly from that of a single-phase fluid, the measured pressure differentials are a unique function of the mass flow rates of each phase.
As described above, the gas and liquid phases are strongly coupled. When the gas phase accelerates in the converging section of the nozzle, the denser liquid phase velocity appreciably lags that of the lighter gas phase. In the extended throat region, the liquid phase continues to accelerate, ultimately approaching its equilibrium velocity with respect to the gas phase. Even at equilibrium, significant velocity differences or slip will exist between the gas and liquid phases. A method for accurately calculating the gas and liquid mass flows in an extended venturi tube will now be described. (A derivation of the method is shown later.) This method uses the four values which are determined though testing. These values are: ~P3 which is the measured pressure differential across the venturi contraction, OPZ which is the measured pressure differential across the extended venturi throat, P which is the absolute pressure upstream from the venturi (psi), and T which is the temperature of the upstream flow. These measured values are used with a number of predefined constants which will be defined as they are used. Alternatively, the pressure differentials 2 0 OP3 and OPo, or the pressure differentials OPo and OPz may be used.
First, the gas density for the gas flow must be calculated based on the current gas well pressure and temperature. This is done using the following equation which uses English units. Any other consistent set of units may also be used with appropriate modifications to the equations.
Equation 1 P + 14.7 60 + 459.67 rhog", = rhog 14.7 T+ 459.67 where rhog is the density of natural gas (i.e. a mixture methane and other hydrocarbon and non-hydrocarbon gases) at standard temperature (60 ° F) and pressure (1 atmosphere) for a specific well;
P is the pressure upstream from the venturi in pounds per square 1 o inch (psi); and T is the temperature upstream from the venturi in degrees Fahrenheit.
The value of rhog will be different for various natural gas compositions and must be supplied by the well operator. At the standard temperature (60° F) and pressure ( 1 atmosphere) the value of rhos for pure methane is 0.044 lb/ft3.
The second step is finding a normalized gas mass flow rate based on the square root of a pressure difference across the contraction multiplied by a first predetermined coefficient, and the square root of a measured pressure differential across a venturi throat. The normalized gas mass flow rate is found using the 2 0 following equation:
Equation 2 mgm= A+B OP3+C OPZ
where A, B, and C are experimentally determined constants required to calculate gas mass flow rate;
~P3 is the measured pressure differential across a venturi 5 contraction; and OPZ is the measured pressure differential across a venturi throat.
The preferred values for the constants in the equation above are as follows: A
is -0.0018104, B is 0.008104 and C is -0.0026832 when pressure is in pounds per square inch (psi), density in lbs/ft3 and mass flow rate in thousands of mass 10 lbs/minute. Of course, these numbers are determined experimentally and may change depending on the geometry of the venturi, the fluids used, and the system of units used.
Calculating the normalized gas mass flow rate is important because it allows the meter to be applied to the wells or situations where the pressure or 15 meter diameter for the liquids present are different than the conditions under which the meter was originally calibrated. This means that the meter does not need to be calibrated under conditions identical to those present in a particular application and that the meter may be sized to match the production rate from a particular well.
2 0 The functional form of Equation 2 is arnved at by derivation from the conservation of mass and energy followed by a simplifying approximation. Other functional forms of Equation 2 can be used with equivalent results. The functional form of Equation 2 is consistent with the conservation laws and provides a good representation of the calibration data.
The third step is computing a gas mass flow rate using the normalized gas mass flow rate, the gas density, and a contraction ratio of the venturi tube.
The equation for calculating the gas mass flow rate from these quantities is Equation 3 rho~,, mg - m~ ' A~ ' 1- ~ 4 where mgm is the normalized gas mass flow rate;
At is the venturi throat area;
(3 is the contraction ratio of the throat area; and rhog", is the gas density at current well conditions.
The fourth step is estimating the gas velocity in the venturi tube throat.
The equation for estimating the gas velocity is:
Equation 4 mg ug =
rhog ~ Al where m~ is the gas mass flow rate;
rhog is the density of the gas phase for a specific well; and At is the venturi throat area.
The fifth step is calculating the pressure drop experienced by the gas phase due to work performed by the gas phase in accelerating the liquid phase between an upstream pressure measuring point and a pressure measuring point in the distal end of the venturi throat. The pressure drop is calculated as follows:
Equation 5 OPgr~ = OP - 2 ~ rhog", ~ ug ~ (1- X34) where OP3 is the measured pressure differential across a venturi contraction;
rhogW is gas density at well conditions;
u~ is the gas velocity in the venturi throat; and (3 is the contraction ratio of the throat area to the upstream area.
It is important to note that the calculations outlined in steps two and five are important because they allow for estimating the mass flow of each phase.
Step six is estimating the liquid velocity (u,) in the venturi throat using the calculated pressure drop experienced by the gas phase due to work performed by the gas phase. This is performed as follows Equation 6 2(~P3 - 4Pg,;) u' rho, ~ [( 1 + /~ 4 ) + gcfw]
where 2 0 OP3 is the measured pressure differential across a venturi contraction;
Equation 5 OPgr~ = OP - 2 ~ rhog", ~ ug ~ (1- X34) where OP3 is the measured pressure differential across a venturi contraction;
rhogW is gas density at well conditions;
u~ is the gas velocity in the venturi throat; and (3 is the contraction ratio of the throat area to the upstream area.
It is important to note that the calculations outlined in steps two and five are important because they allow for estimating the mass flow of each phase.
Step six is estimating the liquid velocity (u,) in the venturi throat using the calculated pressure drop experienced by the gas phase due to work performed by the gas phase. This is performed as follows Equation 6 2(~P3 - 4Pg,;) u' rho, ~ [( 1 + /~ 4 ) + gcfw]
where 2 0 OP3 is the measured pressure differential across a venturi contraction;
OPg~3 1S the pressure drop experienced by the gas-phase due to work performed by the gas phase on the liquid phase;
rho, is the liquid density; and gcfw is a constant which characterizes wall friction. The preferred value for gcfw is defined as 0.062. This value may be adjusted depending on different venturi geometries or different fluids.
The seventh step is computing the friction between the liquid phase and.a wall in the venturi which is performed:
Equation 7 1 o f = gcfw ~ 2 ~ rhol ~ u~
where gcfw is a constant which characterizes wall friction;
rho~ is the liquid density; and u, is the liquid velocity in the venturi throat.
The eighth step is calculating the total mass flow rate based on the measured pressure in the venturi throat, the calculated friction and the gas velocity. The equation for this is:
Equation 8 2(0P - f ) mr - (1-~a),ug'Ar 2 0 where OP3 is the measured pressure differential across a venturi contraction;
rho, is the liquid density; and gcfw is a constant which characterizes wall friction. The preferred value for gcfw is defined as 0.062. This value may be adjusted depending on different venturi geometries or different fluids.
The seventh step is computing the friction between the liquid phase and.a wall in the venturi which is performed:
Equation 7 1 o f = gcfw ~ 2 ~ rhol ~ u~
where gcfw is a constant which characterizes wall friction;
rho~ is the liquid density; and u, is the liquid velocity in the venturi throat.
The eighth step is calculating the total mass flow rate based on the measured pressure in the venturi throat, the calculated friction and the gas velocity. The equation for this is:
Equation 8 2(0P - f ) mr - (1-~a),ug'Ar 2 0 where OP3 is the measured pressure differential across a venturi contraction;
(3 is the contraction ratio of the throat diameter to the upstream diameter; and up is the gas velocity in the venturi throat.
The liquid mass flow rate can now be calculated as the difference between the total and gas mass flow rates.
Equation 9 mr - ~mr _ mg ) wherein m2 is the total mass flow rate; and 1 o me is the gas mass flow rate.
Calculating the gas mass flow rate, total mass flow rate, and liquid mass flow rate using the method outlined above is much more accurate than the prior art. The accuracy of method outlined above is within ~4% for the gas phase, ~5% for the liquid phase, and ~4% for the total mass flow. This accuracy can even be increased using measured calibrations for a specific installation to benchmark the readings.
FIG. 3 shows a summary of the method used to accurately calculate the mass flow through the elongated venturi. The method for determining the mass flow of the high void fraction fluid flow and the gas flow includes steps which 2 0 were described with Equations 1-9. Refernng to FIG. 3, the first step is calculating a gas density for the gas flow 210. The next two steps are finding a normalized gas mass flow rate through the venturi 220 and computing a gas mass flow rate 230. The following step is estimating the gas velocity in the venturi tube throat 240. The next step is calculating the pressure drop experienced by the gas-phase due to work performed by the gas phase in accelerating the liquid phase between the upstream pressure measuring point and the pressure measuring point in the venturi throat 250. Yet another step is estimating the liquid velocity 260 in the venturi throat using the calculated pressure drop experienced by the 5 gas-phase due to work performed by the gas phase. Then the friction is computed 270 between the liquid phase and a wall in the venturi tube. Finally, the total mass flow rate based on measured pressure in the venturi throat is calculated and the liquid mass flow rate is determined 290.
Theoretical Gas Mass Flow Rate 10 Now a discussion of the theoretical derivations will be outlined which produced the method described above. The theoretical derivation is based on the physical laws describing the conservation of mass and energy for both the gas and liquid phases. The conservation of mass and energy equations for each phase are shown below where the subscript 1 denotes the upstream condition measured at 15 142 by pressure tap 150 in FIG. 1, and the subscript 2 denotes the venturi throat entrance measured at 134a by pressure tap 154. OP~13 is the pressure drop experienced by the gas phase due to work done by the gas phase in accelerating the liquid phase between the pressure measuring location at the beginning of the elongated throat and the pressure measuring location at the end of the throat.
It is 2 0 assumed that only the liquid phase is in contact with the wall, fW is the wall friction coefficient and G~ is a geometry factor which accounts for the acceleration of the fluid in the venturi contraction and the surface area of the contraction.
Equations 10 mg = aiPgug~Ai - azPgugzAz mr - ~1- a1)PrutA~ - ~1- az)PturzAz P + 2 pgugl = Pz + 2 pgugz + OPgt P + 2 Pru i = Pz + 2 Prui - 4Pgr~ + G~.fw 2 Prui In Equations 10, a is void fraction, po is density of a gas at standard temperature, u° is the gas velocity, A, is the conduit area upstream of the venturi, AZ is the conduit area in the venturi throat, and P, and PZ are the pressures at locations 142 (tap 150) and 134a (tap 154) in the conduit.
The gas phase energy equation can be rewritten using the equation for the gas phase mass flow rate, where D is the diameter of the upstream piping, d is the throat diameter, (3=d/D is the contraction ratio, and OP3 = Pz - P1 is the pressure drop across the contraction.
Equation 11 ~P3 = 1 m2 2 ~1 a2 ~4) + ~Pgl3 2 Pgaz Az ai With the approximation that a, and az=1, the modified orifice equation results.
Equation 12 OP3 ~ 2 Az (1- /34)+ ~Pgr3 Pg For single-phase flow OPg,3 is equal to zero and the equation is solved directly for the mass flow rate mg. In practice, the single-phase result is modified by the addition of an empirical constant C~ which accounts for the true discharge characteristics (non-ideal one-dimensional behavior and friction losses) of the nozzle and Y which takes compressibility effects into account.
Equation 13 C~ AY
mg,~ = 1- a4 2pgOP3 As shown in the introduction, if the Equation 13 above is used under multiphase conditions, the mass flow rate of the gas phase can be significantly 1 o overestimated. Under multiphase conditions the mass flow rate of the gas phase is given by:
Equation 14 Cama2A2Y
mg = 2 2pg(~P3 - OPgr3) 1- ~a~~ l~
a~
where aZAz represents the cross sectional area occupied by the gas phase. When ~P3 is large with respect to OPg~3 the quantity under the radical can be approximated by Equation 15 0P - OPgl3 ~ DP - C~gr~ x OPgi3 where Cg,3 is a constant that is determined experimentally. Empirically it has been found that OPg,3can be replaced by a function of OPZ, the pressure drop in the extended throat, with appropriate choice of constants. The mass flow rate of gas under both single phase and multiphase conditions now becomes Equation 16 mg CZ~A 4 2PgL OP3 _ CZ x P2~
1- ~3 where it has been assumed that az~al ~ 1. The constants C2~ and CZ have been determined empirically and the validity of the equation has been tested over a wide range of conditions. It is important to note that this method can be used not only with natural gas production but other gas and liquid phase compositions.
In addition, it is also important to recognize that Equations 10 - 16 are used to derive calculation steps in the calculation method.
We have assumed that aZ~a~ ~ 1, making Equation 16 above only approximate. The statistical fitting procedure used to determine the constants CZ~and CZ implicitly determines a weighted mean value of a. Because a does not appear explicitly and is unknown, there is an uncertainty of ~l-2% over the void fraction range 0.95< a<1.0, implicit in the equation. If a or (1- a) is independently measured, the observed measurement uncertainties can be significantly reduced. The uncertainty can also be significantly reduced if, at 2 0 installation, the actual flow rates are accurately known. If this measurement is available then the meter reading can be adjusted to reflect the true value and the uncertainty in the gas phase mass flow rate measurement can be reduced to less than 0.5% of reading if the gas and liquid flow rates change by less than 50%
or so over time. The repeatability of the measurement is essentially the random uncertainty in the pressure measurements, less than about 0.5% of reading.
Total and Liquid Mass Flow Rate If the ratio of liquid to gas flow rate is known a priori with certainty then the mass flow rate of the liquid phase can be directly obtained from ml=mg(m,lm~known. Note that because the liquid mass flow rate is only a fraction (0-30%) of the gas mass flow rate the uncertainty in the measurement is magnified. For instance, if m~/m~= 0.01, a 1% error in m~ is magnified to become a 100% of reading error for the liquid phase. An additional fixed error of 1 %
in the ratio m,/mg results in a 200% of reading total error for the liquid phase.
This approach, of course, assumes that the m,/m~ ratio remains constant over time.
Unfortunately, without accurate independent knowledge of a or (1-a) the liquid mass flow rate cannot be obtained directly from one-dimensional theory.
The velocity of the liquid phase can, however, be estimated directly as now described. Once the mass flow rate of the gas phase is determined the OP~,3 term can be estimated from the gas phase energy equation:
Equation 17 1 z OPgl3 ~ ~P3 - 2 AZ (1- X34) Pg 2 0 Equation 17 allows us to derive Equation 5 in the calculation method.
Rearranging the liquid phase energy equation yields Equation 18 ~P3 + OPgt~ = 1 Pni 1- u21 + G~ fw 1 p,u 2 2 u~2 2 and using the expression for the mass flow rate of liquid results in:
Equation 19 5 OP3 + ~Pgl3 = 2 Prui 1- (1- a2)z ~4 + G~fw 2 p,u 2 ( _ 2 With the assumption that ( 1- a2 )Z ~ 4 < < 1 the liquid velocity u,ZCan be ( i) estimated. If (1-a) is known then the liquid mass flow rate could be estimated directly from m~ (1-az)pu,ZA. Unfortunately, (1-a) cannot be accurately estimated directly from the differential pressure data; it must be independently measured to 10 pursue this approach.
If we consider the gas and liquid phases together but allow their velocities to differ, the total mass flow rate can be written as:
Equation 20 (1- a) mt = mg + m~ = a pg + S, p, ug A
15 where the density term in brackets is the effective density, psl;p and S=u~/u, which is ratio of the gas velocity to the liquid velocity or slip. Since m~ is constant throughout the venturi, it allows us to write the pressure drop OP3 as Equation 21 0P = 2 apg + ~1 S,a) pr ug(1- /j4)+ G~.fv 2 Pru2 The second term on the right hand side is the friction loss assuming that only the liquid phase is in contact with the wall. The equation can be rearranged to yield the total mass flow rate Equation 22 2 OP3 - G~,fy,, 2 prur2 A
aPg+ s Pr ugA- ~1_ ~4).u g The total mass flow rate m~ can then be obtained directly from OP3 once ue is estimated from the measured value of mg, u$ =mglpgA and the liquid velocity is 1 o calculated by solving equation 19 for u,2. The total mass flow rate using this method is a measurement with an uncertainty of ~4% of the actual measured flow. In principle, (since the total mass flow rate is the sum of the gas and liquid mass flow rates) the liquid mass flow rate can now be obtained directly from mr=mt mg. The liquid mass flow rate can then be obtained within ~5% of the total mass flow rate.
As previously noted in the discussion of the measurement of the gas mass flow rate, if the flow rates of each phase are accurately known at the time of installation, measurement performance over a reasonable range of mass flow rates can be significantly enhanced. The uncertainty in the gas mass flow rate measurement can be reduced to <0.5% of reading by benchmarking even if the gas and/or liquid mass flow rates change by X50%. Similarly, the uncertainty in the total mass flow rate can be reduced by <2% of reading for the same X50%
changes in gas and/or liquid mass flow rates. The corresponding improvement in accuracy of the liquid phase measurement is also significant. Because the liquid mass flow rate measurement is dependent on both the gas phase and total mass flow rate measurements, the uncertainty is also sensitive to changes in both gas and liquid mass flow rate. If the liquid mass flow rate measurement is benchmarked at an initial value, the data indicate that the accuracy attainable is l0 X20% of reading for changes in gas mass flow rate in the range of _<~15%
and/or changes in liquid mass flow rate in the range of <_~25%. The uncertainty in the liquid mass flow rate quoted in terms of percent of total mass flow rate becomes ~1%.
Measurement uncertainties can be significantly reduced if flow rates are accurately known at time of meter installation or periodically measured by separation and separate metering during the service life of the meter and the well.
Because the liquid phase is generally only a small fraction of the total mass flow rate the uncertainty in its measurement is inherently high. If the void fraction a is accurately and independently measured, the liquid mass flow rate can be 2 0 calculated directly from m, - ( 1 - a) l, u,2 A where the u,z the liquid velocity is obtained as described above from equation 19. The void fraction may be accurately and independently measured using a gamma ray attenuation densitometer or through ultrasonic film thickness measurements. This approach has been shown to significantly reduce the uncertainty in the liquid mass flow rate measurement.
The liquid mass flow rate can now be calculated as the difference between the total and gas mass flow rates.
Equation 9 mr - ~mr _ mg ) wherein m2 is the total mass flow rate; and 1 o me is the gas mass flow rate.
Calculating the gas mass flow rate, total mass flow rate, and liquid mass flow rate using the method outlined above is much more accurate than the prior art. The accuracy of method outlined above is within ~4% for the gas phase, ~5% for the liquid phase, and ~4% for the total mass flow. This accuracy can even be increased using measured calibrations for a specific installation to benchmark the readings.
FIG. 3 shows a summary of the method used to accurately calculate the mass flow through the elongated venturi. The method for determining the mass flow of the high void fraction fluid flow and the gas flow includes steps which 2 0 were described with Equations 1-9. Refernng to FIG. 3, the first step is calculating a gas density for the gas flow 210. The next two steps are finding a normalized gas mass flow rate through the venturi 220 and computing a gas mass flow rate 230. The following step is estimating the gas velocity in the venturi tube throat 240. The next step is calculating the pressure drop experienced by the gas-phase due to work performed by the gas phase in accelerating the liquid phase between the upstream pressure measuring point and the pressure measuring point in the venturi throat 250. Yet another step is estimating the liquid velocity 260 in the venturi throat using the calculated pressure drop experienced by the 5 gas-phase due to work performed by the gas phase. Then the friction is computed 270 between the liquid phase and a wall in the venturi tube. Finally, the total mass flow rate based on measured pressure in the venturi throat is calculated and the liquid mass flow rate is determined 290.
Theoretical Gas Mass Flow Rate 10 Now a discussion of the theoretical derivations will be outlined which produced the method described above. The theoretical derivation is based on the physical laws describing the conservation of mass and energy for both the gas and liquid phases. The conservation of mass and energy equations for each phase are shown below where the subscript 1 denotes the upstream condition measured at 15 142 by pressure tap 150 in FIG. 1, and the subscript 2 denotes the venturi throat entrance measured at 134a by pressure tap 154. OP~13 is the pressure drop experienced by the gas phase due to work done by the gas phase in accelerating the liquid phase between the pressure measuring location at the beginning of the elongated throat and the pressure measuring location at the end of the throat.
It is 2 0 assumed that only the liquid phase is in contact with the wall, fW is the wall friction coefficient and G~ is a geometry factor which accounts for the acceleration of the fluid in the venturi contraction and the surface area of the contraction.
Equations 10 mg = aiPgug~Ai - azPgugzAz mr - ~1- a1)PrutA~ - ~1- az)PturzAz P + 2 pgugl = Pz + 2 pgugz + OPgt P + 2 Pru i = Pz + 2 Prui - 4Pgr~ + G~.fw 2 Prui In Equations 10, a is void fraction, po is density of a gas at standard temperature, u° is the gas velocity, A, is the conduit area upstream of the venturi, AZ is the conduit area in the venturi throat, and P, and PZ are the pressures at locations 142 (tap 150) and 134a (tap 154) in the conduit.
The gas phase energy equation can be rewritten using the equation for the gas phase mass flow rate, where D is the diameter of the upstream piping, d is the throat diameter, (3=d/D is the contraction ratio, and OP3 = Pz - P1 is the pressure drop across the contraction.
Equation 11 ~P3 = 1 m2 2 ~1 a2 ~4) + ~Pgl3 2 Pgaz Az ai With the approximation that a, and az=1, the modified orifice equation results.
Equation 12 OP3 ~ 2 Az (1- /34)+ ~Pgr3 Pg For single-phase flow OPg,3 is equal to zero and the equation is solved directly for the mass flow rate mg. In practice, the single-phase result is modified by the addition of an empirical constant C~ which accounts for the true discharge characteristics (non-ideal one-dimensional behavior and friction losses) of the nozzle and Y which takes compressibility effects into account.
Equation 13 C~ AY
mg,~ = 1- a4 2pgOP3 As shown in the introduction, if the Equation 13 above is used under multiphase conditions, the mass flow rate of the gas phase can be significantly 1 o overestimated. Under multiphase conditions the mass flow rate of the gas phase is given by:
Equation 14 Cama2A2Y
mg = 2 2pg(~P3 - OPgr3) 1- ~a~~ l~
a~
where aZAz represents the cross sectional area occupied by the gas phase. When ~P3 is large with respect to OPg~3 the quantity under the radical can be approximated by Equation 15 0P - OPgl3 ~ DP - C~gr~ x OPgi3 where Cg,3 is a constant that is determined experimentally. Empirically it has been found that OPg,3can be replaced by a function of OPZ, the pressure drop in the extended throat, with appropriate choice of constants. The mass flow rate of gas under both single phase and multiphase conditions now becomes Equation 16 mg CZ~A 4 2PgL OP3 _ CZ x P2~
1- ~3 where it has been assumed that az~al ~ 1. The constants C2~ and CZ have been determined empirically and the validity of the equation has been tested over a wide range of conditions. It is important to note that this method can be used not only with natural gas production but other gas and liquid phase compositions.
In addition, it is also important to recognize that Equations 10 - 16 are used to derive calculation steps in the calculation method.
We have assumed that aZ~a~ ~ 1, making Equation 16 above only approximate. The statistical fitting procedure used to determine the constants CZ~and CZ implicitly determines a weighted mean value of a. Because a does not appear explicitly and is unknown, there is an uncertainty of ~l-2% over the void fraction range 0.95< a<1.0, implicit in the equation. If a or (1- a) is independently measured, the observed measurement uncertainties can be significantly reduced. The uncertainty can also be significantly reduced if, at 2 0 installation, the actual flow rates are accurately known. If this measurement is available then the meter reading can be adjusted to reflect the true value and the uncertainty in the gas phase mass flow rate measurement can be reduced to less than 0.5% of reading if the gas and liquid flow rates change by less than 50%
or so over time. The repeatability of the measurement is essentially the random uncertainty in the pressure measurements, less than about 0.5% of reading.
Total and Liquid Mass Flow Rate If the ratio of liquid to gas flow rate is known a priori with certainty then the mass flow rate of the liquid phase can be directly obtained from ml=mg(m,lm~known. Note that because the liquid mass flow rate is only a fraction (0-30%) of the gas mass flow rate the uncertainty in the measurement is magnified. For instance, if m~/m~= 0.01, a 1% error in m~ is magnified to become a 100% of reading error for the liquid phase. An additional fixed error of 1 %
in the ratio m,/mg results in a 200% of reading total error for the liquid phase.
This approach, of course, assumes that the m,/m~ ratio remains constant over time.
Unfortunately, without accurate independent knowledge of a or (1-a) the liquid mass flow rate cannot be obtained directly from one-dimensional theory.
The velocity of the liquid phase can, however, be estimated directly as now described. Once the mass flow rate of the gas phase is determined the OP~,3 term can be estimated from the gas phase energy equation:
Equation 17 1 z OPgl3 ~ ~P3 - 2 AZ (1- X34) Pg 2 0 Equation 17 allows us to derive Equation 5 in the calculation method.
Rearranging the liquid phase energy equation yields Equation 18 ~P3 + OPgt~ = 1 Pni 1- u21 + G~ fw 1 p,u 2 2 u~2 2 and using the expression for the mass flow rate of liquid results in:
Equation 19 5 OP3 + ~Pgl3 = 2 Prui 1- (1- a2)z ~4 + G~fw 2 p,u 2 ( _ 2 With the assumption that ( 1- a2 )Z ~ 4 < < 1 the liquid velocity u,ZCan be ( i) estimated. If (1-a) is known then the liquid mass flow rate could be estimated directly from m~ (1-az)pu,ZA. Unfortunately, (1-a) cannot be accurately estimated directly from the differential pressure data; it must be independently measured to 10 pursue this approach.
If we consider the gas and liquid phases together but allow their velocities to differ, the total mass flow rate can be written as:
Equation 20 (1- a) mt = mg + m~ = a pg + S, p, ug A
15 where the density term in brackets is the effective density, psl;p and S=u~/u, which is ratio of the gas velocity to the liquid velocity or slip. Since m~ is constant throughout the venturi, it allows us to write the pressure drop OP3 as Equation 21 0P = 2 apg + ~1 S,a) pr ug(1- /j4)+ G~.fv 2 Pru2 The second term on the right hand side is the friction loss assuming that only the liquid phase is in contact with the wall. The equation can be rearranged to yield the total mass flow rate Equation 22 2 OP3 - G~,fy,, 2 prur2 A
aPg+ s Pr ugA- ~1_ ~4).u g The total mass flow rate m~ can then be obtained directly from OP3 once ue is estimated from the measured value of mg, u$ =mglpgA and the liquid velocity is 1 o calculated by solving equation 19 for u,2. The total mass flow rate using this method is a measurement with an uncertainty of ~4% of the actual measured flow. In principle, (since the total mass flow rate is the sum of the gas and liquid mass flow rates) the liquid mass flow rate can now be obtained directly from mr=mt mg. The liquid mass flow rate can then be obtained within ~5% of the total mass flow rate.
As previously noted in the discussion of the measurement of the gas mass flow rate, if the flow rates of each phase are accurately known at the time of installation, measurement performance over a reasonable range of mass flow rates can be significantly enhanced. The uncertainty in the gas mass flow rate measurement can be reduced to <0.5% of reading by benchmarking even if the gas and/or liquid mass flow rates change by X50%. Similarly, the uncertainty in the total mass flow rate can be reduced by <2% of reading for the same X50%
changes in gas and/or liquid mass flow rates. The corresponding improvement in accuracy of the liquid phase measurement is also significant. Because the liquid mass flow rate measurement is dependent on both the gas phase and total mass flow rate measurements, the uncertainty is also sensitive to changes in both gas and liquid mass flow rate. If the liquid mass flow rate measurement is benchmarked at an initial value, the data indicate that the accuracy attainable is l0 X20% of reading for changes in gas mass flow rate in the range of _<~15%
and/or changes in liquid mass flow rate in the range of <_~25%. The uncertainty in the liquid mass flow rate quoted in terms of percent of total mass flow rate becomes ~1%.
Measurement uncertainties can be significantly reduced if flow rates are accurately known at time of meter installation or periodically measured by separation and separate metering during the service life of the meter and the well.
Because the liquid phase is generally only a small fraction of the total mass flow rate the uncertainty in its measurement is inherently high. If the void fraction a is accurately and independently measured, the liquid mass flow rate can be 2 0 calculated directly from m, - ( 1 - a) l, u,2 A where the u,z the liquid velocity is obtained as described above from equation 19. The void fraction may be accurately and independently measured using a gamma ray attenuation densitometer or through ultrasonic film thickness measurements. This approach has been shown to significantly reduce the uncertainty in the liquid mass flow rate measurement.
Claims (30)
1. A method for determining total mass flow rate of a high void fraction flow having a liquid phase and a gas phase, the method comprising:
a) passing a high void fraction liquid and gas flow through a flow channel having a variable diameter;
b) detecting a first pressure differential value resulting from a change in the flow channel diameter;
c) detecting a second pressure differential value resulting from work performed by the gas phase in accelerating the liquid phase;
d) processing the first and second pressure differential values to determine the total mass flow rate of the high void fraction flow having a liquid phase and a gas phase.
a) passing a high void fraction liquid and gas flow through a flow channel having a variable diameter;
b) detecting a first pressure differential value resulting from a change in the flow channel diameter;
c) detecting a second pressure differential value resulting from work performed by the gas phase in accelerating the liquid phase;
d) processing the first and second pressure differential values to determine the total mass flow rate of the high void fraction flow having a liquid phase and a gas phase.
2. The method according to claim 1, further comprising the step of processing the total mass flow rate to calculate a liquid mass flow rate.
3. The method according to claim 1, wherein the flow channel having a variable diameter is an extended throat venturi having a converging section and a throat.
4. The method according to claim 3, wherein the step of processing the first and second pressure differential values to determine the total mass flow rate of a high void fraction flow having a liquid phase and a gas phase further comprises:
(a) calculating a gas density for a gas flow;
(b) calculating a normalized gas mass flow rate based on measured pressure differences across the converging section and the throat;
(c) computing a gas mass flow rate in the throat using the normalized gas mass flow rate, a gas density, venturi throat geometry, and a contraction ratio of the venturi;
(d) estimating gas velocity in the throat using the gas mass flow rate;
(e) calculating a pressure drop experienced by the gas phase due to work performed by the gas phase in accelerating the liquid phase between an upstream pressure measuring point prior to the venturi and a pressure measuring point in the throat;
(f) estimating liquid velocity in the throat using the calculated pressure drop experienced by the gas phase due to work performed by the gas phase;
(g) computing a friction value between the liquid phase and a wall in the venturi using the liquid velocity;
(h) calculating the total mass flow rate based on a measured pressure difference in the throat, the friction value and the gas velocity.
(a) calculating a gas density for a gas flow;
(b) calculating a normalized gas mass flow rate based on measured pressure differences across the converging section and the throat;
(c) computing a gas mass flow rate in the throat using the normalized gas mass flow rate, a gas density, venturi throat geometry, and a contraction ratio of the venturi;
(d) estimating gas velocity in the throat using the gas mass flow rate;
(e) calculating a pressure drop experienced by the gas phase due to work performed by the gas phase in accelerating the liquid phase between an upstream pressure measuring point prior to the venturi and a pressure measuring point in the throat;
(f) estimating liquid velocity in the throat using the calculated pressure drop experienced by the gas phase due to work performed by the gas phase;
(g) computing a friction value between the liquid phase and a wall in the venturi using the liquid velocity;
(h) calculating the total mass flow rate based on a measured pressure difference in the throat, the friction value and the gas velocity.
5. The method of claim 4, further comprising the step of calculating a liquid mass flow rate as the difference between the total mass flow rate and the gas mass flow rate.
6. The method of claim 4, wherein the step of calculating a gas density for a gas flow further comprises the step of calculating the gas density for the gas flow using the equation:
wherein rho g is a methane density at standard temperature (60° F) and pressure (1 atmosphere) for a specific well;
P is a pressure upstream from the venturi tube; and T is a temperature upstream from the venturi tube.
wherein rho g is a methane density at standard temperature (60° F) and pressure (1 atmosphere) for a specific well;
P is a pressure upstream from the venturi tube; and T is a temperature upstream from the venturi tube.
7. The method of claim 4 wherein the step of calculating a normalized gas mass (mgm) flow rate further comprises finding the normalized gas mass flow rate using the following equation:
where A, B, and C are experimentally determined constants required to calculate gas mass flow rate;
.DELTA.P3 is a measured pressure differential across the converging section; and .DELTA.P2 is a measured pressure differential across the throat.
where A, B, and C are experimentally determined constants required to calculate gas mass flow rate;
.DELTA.P3 is a measured pressure differential across the converging section; and .DELTA.P2 is a measured pressure differential across the throat.
8. The method of claim 7 wherein the constant A is -0.0018104, B is 0.008104 and C is -0.0026832 when pressure is in pounds per square inch (psi), mass flow rate is in thousands of mass lbs/minute, and density is in lbs/ft3 and area is in inches2.
9. The method of claim 4 wherein the step of computing a gas mass flow rate further comprises computing a gas mass flow rate (mg) using the following equation wherein mgm is the normalized gas mass flow rate;
A t is an area of the venturi throat in inches; and .beta. is a contraction ratio of the throat area to an upstream area.
A t is an area of the venturi throat in inches; and .beta. is a contraction ratio of the throat area to an upstream area.
10. The method of claim 4 wherein the step of estimating a gas velocity further comprises using the following equation:
wherein m g is the gas mass flow rate;
rho g is a gas density for a specific well; and A t is an area of the venturi throat.
wherein m g is the gas mass flow rate;
rho g is a gas density for a specific well; and A t is an area of the venturi throat.
11. The method of claim 4 wherein the step of calculating a pressure drop experienced by a gas phase due to work performed by the gas phase further comprises using the following equation:
wherein .DELTA.P3 is a measured pressure differential across the converging section;
rho gw is gas density at well conditions;
u g is a gas velocity in the throat; and .beta. is a contraction ratio of the throat area to an upstream area.
wherein .DELTA.P3 is a measured pressure differential across the converging section;
rho gw is gas density at well conditions;
u g is a gas velocity in the throat; and .beta. is a contraction ratio of the throat area to an upstream area.
12. The method of claim 4 wherein the step of estimating liquid velocity in throat is performed using the following equation:
wherein .DELTA.P3 is a measured pressure differential across the converging section;
.DELTA.P g13 is the pressure drop experienced by the gas-phase due to work performed by the gas phase on the liquid phase;
rho1 is a liquid density; and gcfw is a constant which characterizes wall friction.
wherein .DELTA.P3 is a measured pressure differential across the converging section;
.DELTA.P g13 is the pressure drop experienced by the gas-phase due to work performed by the gas phase on the liquid phase;
rho1 is a liquid density; and gcfw is a constant which characterizes wall friction.
13. The method as in claim 12 wherein the gcfw which represents wall friction is defined as 0.062.
14. The method as in claim 4 wherein the step of computing friction between the liquid phase and a wall in the venturi further comprises computing friction using the following equation:
wherein gcfw is a constant which characterizes wall friction;
rho1 is a liquid density; and u1 is the liquid velocity in the throat.
wherein gcfw is a constant which characterizes wall friction;
rho1 is a liquid density; and u1 is the liquid velocity in the throat.
15. The method as in claim 4 wherein the step of calculating the total mass flow rate further comprises calculating the total mass flow rate using the following equation:
wherein .DELTA.P3 is a measured pressure differential across the converging section;
.beta. is a contraction ratio of the throat area to an upstream area; and u g is the gas velocity in the throat.
wherein .DELTA.P3 is a measured pressure differential across the converging section;
.beta. is a contraction ratio of the throat area to an upstream area; and u g is the gas velocity in the throat.
16. The method as in claim 5, wherein the step of calculating the liquid mass flow rate as the difference between the total mass flow rate and the gas mass flow rate further comprises using the following equation:
m l = (m t - m g) wherein m t is the total mass flow rate; and m g is the gas mass flow rate.
m l = (m t - m g) wherein m t is the total mass flow rate; and m g is the gas mass flow rate.
17. A method for finding a gas mass flow rate and a liquid mass flow rate of a combined flow having a liquid phase and gas phase, using an extended throat venturi having a converging section and a throat, comprising the steps of:
(a) calculating a normalized gas mass flow rate based on measured pressure differences across the converging section and throat;
(b) computing a gas mass flow rate in the throat using the normalized gas mass flow rate, venturi throat geometry, a gas density, and a contraction ratio of the venturi;
(c) estimating gas velocity in the throat using the gas mass flow rate;
(d) calculating a pressure drop experienced by the gas phase due to work performed by the gas phase in accelerating the liquid phase between an upstream pressure measuring point prior to the venturi and a pressure measuring point in the throat;
(e) estimating liquid velocity in the throat using the calculated pressure drop from step (d);
(f) measuring a void fraction in the throat using a measurement device; and (g) calculating the liquid mass flow rate directly from one minus the void fraction multiplied by a liquid density value, the liquid velocity, and a throat area value.
(a) calculating a normalized gas mass flow rate based on measured pressure differences across the converging section and throat;
(b) computing a gas mass flow rate in the throat using the normalized gas mass flow rate, venturi throat geometry, a gas density, and a contraction ratio of the venturi;
(c) estimating gas velocity in the throat using the gas mass flow rate;
(d) calculating a pressure drop experienced by the gas phase due to work performed by the gas phase in accelerating the liquid phase between an upstream pressure measuring point prior to the venturi and a pressure measuring point in the throat;
(e) estimating liquid velocity in the throat using the calculated pressure drop from step (d);
(f) measuring a void fraction in the throat using a measurement device; and (g) calculating the liquid mass flow rate directly from one minus the void fraction multiplied by a liquid density value, the liquid velocity, and a throat area value.
18. The method for finding gas and liquid mass flow rates as in claim 17 wherein step (f) further comprises the step of measuring the void fraction in the throat using a gamma ray attenuation densitometer.
19. The method for finding a gas and liquid mass flow rates as in claim 17 wherein step (f) further comprises the step of measuring the void fraction in the throat using an ultrasonic film thickness measuring device.
20. The method for finding a gas and liquid mass flow rate as in claim 17 wherein step (f) further comprises the step of measuring the void fraction in the throat using a microwave attenuation densitometer or microwave resonant cavity densitometer.
21. A differential pressure flow meter for measuring a flow rate of a high void multi-phase flow to determine mass flow rates of a gas and a liquid phase through a flow channel, the apparatus comprising:
(a) a flow channel having a variable diameter;
(b) a pressure monitor, disposed in communication with at least three locations along the flow channel, including locations having different diameters, for determining at least two pressure differentials within the flow channel as the high void multi-phase flow passes through the flow channel; and (c) a processor, disposed in communication with the pressure monitor, for calculating a pressure drop experienced by the gas phase due to work performed by the gas phase in accelerating the liquid phase, such that the pressure drop is used to calculate the mass flow rates for the gas and liquid phases.
(a) a flow channel having a variable diameter;
(b) a pressure monitor, disposed in communication with at least three locations along the flow channel, including locations having different diameters, for determining at least two pressure differentials within the flow channel as the high void multi-phase flow passes through the flow channel; and (c) a processor, disposed in communication with the pressure monitor, for calculating a pressure drop experienced by the gas phase due to work performed by the gas phase in accelerating the liquid phase, such that the pressure drop is used to calculate the mass flow rates for the gas and liquid phases.
22. The differential pressure flow meter of claim 21, wherein the flow channel having a variable diameter has a first and second segment, the second segment having a smaller diameter than the first segment.
23. The differential pressure flow meter of claim 21, wherein the flow channel is a venturi tube, having a venturi inlet, a venturi outlet, and an extended throat having a throat inlet coupled to the venturi inlet and a throat outlet coupled to the venturi outlet.
24. The differential pressure flow meter of claim 22, wherein the at least two pressure differentials are used by the processor to calculate the pressure drop experienced by the gas phase due to work performed by the gas phase in accelerating the liquid phase.
25. The differential pressure flow meter of claim 23, wherein the at least two pressure differentials are used by the processor to calculate the pressure drop experienced by the gas phase due to work performed by the gas phase in accelerating the liquid phase.
26. The differential pressure flow meter of claim 23, wherein at least one pressure measuring point is disposed before the venturi inlet, at least one pressure measuring point is disposed in the throat inlet, and at least one pressure measuring point is disposed in the throat outlet.
27. The differential pressure flow meter of claim 23, wherein the pressure monitor further comprises:
a first pressure means for determining a first pressure differential between a location before the venturi inlet and a location in the throat inlet;
a second pressure means for determining a second pressure differential between a location adjacent the throat inlet and a location adjacent the throat outlet; and a calculation means for selectively combining the first and second pressure differentials to determine a flow rate of a high void fraction liquid and gas flow, which passes through the venturi tube.
a first pressure means for determining a first pressure differential between a location before the venturi inlet and a location in the throat inlet;
a second pressure means for determining a second pressure differential between a location adjacent the throat inlet and a location adjacent the throat outlet; and a calculation means for selectively combining the first and second pressure differentials to determine a flow rate of a high void fraction liquid and gas flow, which passes through the venturi tube.
28. The differential pressure flow meter as in claim 21 wherein the processor uses the pressure drop calculated to further estimate liquid velocity and friction.
29. The differential pressure flow meter as in claim 28 wherein the processor calculates the total mass flow rate using the liquid velocity, friction, gas mass flow rate and at least two pressure differentials.
30. The differential pressure flow meter as in claim 28 wherein the processor calculates a liquid mass flow rate as a difference between the total mass flow rate and the gas mass flow rate.
Applications Claiming Priority (5)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US09/401,375 US6332111B1 (en) | 1997-09-24 | 1999-09-22 | Method and system for measuring multiphase flow using multiple pressure differentials |
| US09/401,375 | 1999-09-22 | ||
| US09/400,946 | 1999-09-22 | ||
| US09/400,946 US6502467B1 (en) | 1997-09-24 | 1999-09-22 | System for measuring multiphase flow using multiple pressure differentials |
| PCT/US2000/025865 WO2001022041A1 (en) | 1999-09-22 | 2000-09-21 | Improved method and system for measuring multiphase flow using multiple pressure differentials |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CA2399536A1 true CA2399536A1 (en) | 2001-03-29 |
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| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA002399536A Abandoned CA2399536A1 (en) | 1999-09-22 | 2000-09-21 | Improved method and system for measuring multiphase flow using multiple pressure differentials |
Country Status (5)
| Country | Link |
|---|---|
| EP (1) | EP1409966A4 (en) |
| AU (1) | AU7598600A (en) |
| CA (1) | CA2399536A1 (en) |
| NO (1) | NO20023858L (en) |
| WO (1) | WO2001022041A1 (en) |
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| Publication number | Priority date | Publication date | Assignee | Title |
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| ATE423339T1 (en) | 2001-04-26 | 2009-03-15 | Abb As | METHOD FOR MONITORING AND DETECTING SENSOR FAILURE IN OIL AND GAS PRODUCTION SYSTEMS |
| NO320172B1 (en) | 2004-02-27 | 2005-11-07 | Roxar Flow Measurement As | Flow templates and methods for painting individual quantities of gas, hydrocarbon liquid and water in a fluid mixture |
| AU2008276178A1 (en) * | 2007-07-13 | 2009-01-22 | Mccrometer, Inc. | Two-phase flow meter |
| CN101333924B (en) * | 2008-05-23 | 2013-02-13 | 安东石油技术（集团）有限公司 | Oil gas water flow measurement system |
| CN101333925B (en) * | 2008-05-23 | 2013-02-13 | 安东石油技术（集团）有限公司 | Oil gas water three phase on-line inseparate flow measurement system |
| CN101338664B (en) * | 2008-05-23 | 2013-05-15 | 安东石油技术（集团）有限公司 | Condensed gas flow quantity measuring systems |
| CN101333926B (en) * | 2008-05-23 | 2013-05-15 | 安东石油技术（集团）有限公司 | Oil gas water flow measurement system possessing automatic control device |
| CN105486358B (en) * | 2015-11-19 | 2018-11-16 | 中国石油大学(华东) | Gas-liquid two-phase flow parameter measurement method based on Venturi tube double difference pressure |
| CN108664679B (en) * | 2017-04-01 | 2021-07-27 | 中国石油化工股份有限公司 | Oil and gas well production data analysis method |
| CN108664678B (en) * | 2017-04-01 | 2021-08-31 | 中国石油化工股份有限公司 | Yield prediction method |
| US10544674B2 (en) | 2017-08-23 | 2020-01-28 | Saudi Arabian Oil Company | Multiphase flow meter with tuning fork |
| US10890067B2 (en) | 2019-04-11 | 2021-01-12 | Saudi Arabian Oil Company | Method to use a buoyant body to measure two-phase flow in horizontal wells |
| US10908007B1 (en) | 2019-08-20 | 2021-02-02 | Saudi Arabian Oil Company | Multiphase flow metering system for horizontal well compartments |
| US11346177B2 (en) | 2019-12-04 | 2022-05-31 | Saudi Arabian Oil Company | Repairable seal assemblies for oil and gas applications |
| US11187044B2 (en) | 2019-12-10 | 2021-11-30 | Saudi Arabian Oil Company | Production cavern |
| CN111222229B (en) * | 2019-12-27 | 2022-10-21 | 清华大学深圳国际研究生院 | Method for constructing instantaneous flow measurement model in gas-liquid two-phase flow dynamic flow process |
| US11460330B2 (en) | 2020-07-06 | 2022-10-04 | Saudi Arabian Oil Company | Reducing noise in a vortex flow meter |
| CN112539790B (en) * | 2020-12-02 | 2024-04-30 | 哈尔滨工程大学 | Real-time online measurement system and method for cavitation share of two-phase flow in pipeline |
| CN113188613B (en) * | 2021-03-05 | 2024-04-05 | 深圳市联恒星科技有限公司 | Multi-phase flow measurement method and system based on uncertainty analysis |
| CN115452081B (en) * | 2022-09-22 | 2024-09-17 | 西安交通大学 | Two-phase flow gas phase mass flow measurement method and system based on differential pressure throttling device |
| CN116839809B (en) * | 2023-09-04 | 2023-12-05 | 哈尔滨工程大学 | Marine differential pressure principle instrument measurement correction method |
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| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US4231262A (en) * | 1979-03-28 | 1980-11-04 | The Babcock & Wilcox Company | System for measuring entrained solid flow |
| FR2720498B1 (en) * | 1994-05-27 | 1996-08-09 | Schlumberger Services Petrol | Multiphase flowmeter. |
| US5708211A (en) * | 1996-05-28 | 1998-01-13 | Ohio University | Flow regime determination and flow measurement in multiphase flow pipelines |
| CA2185867C (en) * | 1996-09-18 | 2000-03-21 | Varagur Srinivasa V. Rajan | Multi-phase fluid flow measurement apparatus and method |
| WO1999015862A1 (en) * | 1997-09-24 | 1999-04-01 | Lockheed Martin Idaho Technologies Company | Special configuration differential pressure flow meter |
-
2000
- 2000-09-21 EP EP00965242A patent/EP1409966A4/en not_active Withdrawn
- 2000-09-21 CA CA002399536A patent/CA2399536A1/en not_active Abandoned
- 2000-09-21 AU AU75986/00A patent/AU7598600A/en not_active Abandoned
- 2000-09-21 WO PCT/US2000/025865 patent/WO2001022041A1/en active Application Filing
-
2002
- 2002-08-14 NO NO20023858A patent/NO20023858L/en not_active Application Discontinuation
Also Published As
| Publication number | Publication date |
|---|---|
| NO20023858D0 (en) | 2002-08-14 |
| EP1409966A4 (en) | 2006-02-01 |
| NO20023858L (en) | 2002-09-27 |
| AU7598600A (en) | 2001-04-24 |
| WO2001022041A1 (en) | 2001-03-29 |
| EP1409966A1 (en) | 2004-04-21 |
| WO2001022041A9 (en) | 2002-10-03 |
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