WO2005093381A9 - Multi-phase coriolis flowmeter - Google Patents
Multi-phase coriolis flowmeterInfo
- Publication number
- WO2005093381A9 WO2005093381A9 PCT/US2005/006623 US2005006623W WO2005093381A9 WO 2005093381 A9 WO2005093381 A9 WO 2005093381A9 US 2005006623 W US2005006623 W US 2005006623W WO 2005093381 A9 WO2005093381 A9 WO 2005093381A9
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- apparent
- flow
- liquid
- gas
- operable
- Prior art date
Links
Classifications
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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
- G01F1/76—Devices for measuring mass flow of a fluid or a fluent solid material
- G01F1/78—Direct mass flowmeters
- G01F1/80—Direct mass flowmeters operating by measuring pressure, force, momentum, or frequency of a fluid flow to which a rotational movement has been imparted
- G01F1/84—Coriolis or gyroscopic mass flowmeters
- G01F1/845—Coriolis or gyroscopic mass flowmeters arrangements of measuring means, e.g., of measuring conduits
- G01F1/8468—Coriolis or gyroscopic mass flowmeters arrangements of measuring means, e.g., of measuring conduits vibrating measuring conduits
- G01F1/8481—Coriolis or gyroscopic mass flowmeters arrangements of measuring means, e.g., of measuring conduits vibrating measuring conduits having loop-shaped measuring conduits, e.g. the measuring conduits form a loop with a crossing point
- G01F1/8486—Coriolis or gyroscopic mass flowmeters arrangements of measuring means, e.g., of measuring conduits vibrating measuring conduits having loop-shaped measuring conduits, e.g. the measuring conduits form a loop with a crossing point with multiple measuring conduits
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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
- G01F1/76—Devices for measuring mass flow of a fluid or a fluent solid material
- G01F1/78—Direct mass flowmeters
- G01F1/80—Direct mass flowmeters operating by measuring pressure, force, momentum, or frequency of a fluid flow to which a rotational movement has been imparted
- G01F1/84—Coriolis or gyroscopic mass flowmeters
- G01F1/8409—Coriolis or gyroscopic mass flowmeters constructional details
- G01F1/8431—Coriolis or gyroscopic mass flowmeters constructional details electronic circuits
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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
- G01F1/76—Devices for measuring mass flow of a fluid or a fluent solid material
- G01F1/78—Direct mass flowmeters
- G01F1/80—Direct mass flowmeters operating by measuring pressure, force, momentum, or frequency of a fluid flow to which a rotational movement has been imparted
- G01F1/84—Coriolis or gyroscopic mass flowmeters
- G01F1/8409—Coriolis or gyroscopic mass flowmeters constructional details
- G01F1/8436—Coriolis or gyroscopic mass flowmeters constructional details signal processing
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01F—MEASURING VOLUME, VOLUME FLOW, MASS FLOW OR LIQUID LEVEL; METERING BY VOLUME
- G01F1/00—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow
- G01F1/76—Devices for measuring mass flow of a fluid or a fluent solid material
- G01F1/78—Direct mass flowmeters
- G01F1/80—Direct mass flowmeters operating by measuring pressure, force, momentum, or frequency of a fluid flow to which a rotational movement has been imparted
- G01F1/84—Coriolis or gyroscopic mass flowmeters
- G01F1/845—Coriolis or gyroscopic mass flowmeters arrangements of measuring means, e.g., of measuring conduits
- G01F1/8468—Coriolis or gyroscopic mass flowmeters arrangements of measuring means, e.g., of measuring conduits vibrating measuring conduits
- G01F1/849—Coriolis or gyroscopic mass flowmeters arrangements of measuring means, e.g., of measuring conduits vibrating measuring conduits having straight measuring conduits
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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
- G01F15/02—Compensating or correcting for variations in pressure, density or temperature
- G01F15/022—Compensating or correcting for variations in pressure, density or temperature using electrical means
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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
- G01F15/02—Compensating or correcting for variations in pressure, density or temperature
- G01F15/022—Compensating or correcting for variations in pressure, density or temperature using electrical means
- G01F15/024—Compensating or correcting for variations in pressure, density or temperature using electrical means involving digital counting
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01F—MEASURING VOLUME, VOLUME FLOW, MASS FLOW OR LIQUID LEVEL; METERING BY VOLUME
- G01F25/00—Testing or calibration of apparatus for measuring volume, volume flow or liquid level or for metering by volume
- G01F25/10—Testing or calibration of apparatus for measuring volume, volume flow or liquid level or for metering by volume of flowmeters
Definitions
- This description relates to flowmeters.
- Flowmeters provide information about materials being transferred through a conduit, or flowtube.
- mass flowmeters provide an indication of the mass of material being transferred through a conduit.
- density flowmeters, or densitometers provide an indication of the density of material flowing through a conduit.
- Mass flowmeters also may provide an indication of the density of the material.
- Coriolis-type mass flowmeters are based on the Coriolis effect, in which material flowing through a conduit is affected by a Coriolis force and therefore experiences an acceleration. Many Coriolis-type mass flowmeters induce a Coriolis force by sinusoidally oscillating a conduit about a pivot axis orthogonal to the length of the conduit. In such mass flowmeters, the Coriolis reaction force experienced by the traveling fluid mass is transferred to the conduit itself and is manifested as a deflection or offset of the conduit in the direction of the Coriolis force vector in the plane of rotation.
- a system includes a controller that is operable to receive a sensor signal from a first sensor connected to a vibratable flowtube containing a three-phase fluid flow that includes a first liquid, a second liquid, and a gas, the controller being further operable to analyze the sensor signal to determine an apparent flow parameter of the fluid flow, a second sensor that is operable to determine an apparent flow condition of the fluid flow, and a corrections module that is operable to input the apparent flow parameter and the apparent flow condition and determine a corrected flow parameter therefrom.
- Implementations may include one or more of the following features.
- the corrections module may be further operable to input the apparent flow parameter and the apparent flow condition and determine a corrected flow condition therefrom.
- the apparent flow parameter may include an apparent bulk density of the fluid flow, or an apparent bulk mass flow rate of the fluid flow.
- the second sensor may include a liquid fraction probe that is operable to determine a liquid fraction measurement identifying a volume fraction of the first liquid with respect to the second liquid, or a void fraction determination system that is operable to determine a void fraction of the gas within the fluid flow.
- a component flow rate determination system may be included that is operable to determine a flow rate of the first liquid within the fluid flow.
- the component flow rate determination system may be implemented at the controller, the corrections module, the second sensor, or a host computer in communications with the controller, the corrections module, or the second sensor.
- a component flow rate determination system may be included that is operable to determine a flow rate of the gas within the fluid flow.
- Implementation of the corrections module may be associated with a processor of the controller, or with a processor of the second sensor.
- a host computer may be in communication with the controller or the second sensor and operable to implement the corrections module.
- the second sensor may be operable to output a first apparent flow condition value to the controller for use in determination of a first corrected flow parameter value
- the controller may be operable to output the first corrected flow parameter value to the second sensor for determination of a first corrected flow condition value
- the second sensor may be operable to output a second corrected flow condition value to the controller for use in determination of the corrected flow parameter value.
- the correction module may include a neural network that is operable to input the apparent flow parameter and the apparent flow condition and output the corrected flow parameter and a corrected flow condition.
- the neural network may include a first correction model that is particular to a type of the second sensor and flow condition and that is operable to output a corrected flow condition, and a second correction model that is particular to a type of the apparent flow parameter and that is operable to output the corrected flow parameter, wherein the first correction model may be operable to correct the apparent flow condition based on the apparent flow condition and the corrected flow parameter, and the second correction model may be operable to correct the apparent flow parameter based on the apparent flow parameter and the corrected flow condition.
- the controller may be operable to correct the apparent flow parameter based on a theoretical relationship between the apparent flow parameter and the corrected flow parameter.
- the controller may be operable to correct the apparent flow parameter based on an empirical relationship between the apparent flow parameter and the corrected flow parameter.
- the system may include a conduit connecting the second sensor and the vibratable flowtube, such that the fluid flow flows through the second sensor, the pipe, and the vibratable flowtube.
- the first liquid, the second liquid, and the gas may be co-mingled with one another within the fluid flow during determination of the flow condition by the second sensor.
- an apparent bulk density of a multi-phase flow through a flowtube is determined, the multi-phase flow including a first liquid, a second liquid, and a gas.
- an apparent flow condition of the multi-phase flow other than the apparent bulk density and the apparent bulk mass flow rate may be determined, wherein determining the first mass flow rate of the first liquid comprises determining the first mass flow rate based on the apparent flow condition.
- a corrected flow condition may be determined, based on the apparent flow condition.
- a flowmeter includes a vibratable flowtube containing a three-phase flow including a first liquid, a second liquid, and a gas, a driver connected to the flowtube and operable to impart motion to the flowtube, a sensor connected to the flowtube and operable to sense the motion of the flowtube and generate a sensor signal, and a controller connected to receive the sensor signal and determine a first flow rate of a Irst ph ⁇ se within a three-phase flow through the flowtube, based on the sensor sign ⁇ l.
- a method of improving an output of a liquid fraction probe includes determining an apparent bulk density of a multi-phase flow through a flowtube, the multi -phase flow including a first liquid, a second liquid, and a gas, determining an apparent bulk mass flow rate of the multi-phase flow, determining an apparent liquid fraction the first liquid within the multi-phase flow, and correcting the apparent liquid fraction to obtain a corrected liquid fraction, based on the apparent bulk density, the apparent mass flow rate, and the apparent liquid fraction.
- Implementations may include one or more of the following features. For example, a gas void fraction of the gas within the multi-phase flow may be determined based on the apparent bulk density, the apparent mass flow rate, and the corrected liquid fraction.
- a method of obtaining a gas void fraction measurement includes determining an apparent bulk density of a multi -phase flow through a flowtube, the multi-phase flow including a first liquid, a second liquid, and a gas, determining an apparent bulk mass flow rate of the multi -phase flow, determining an apparent gas void fraction of the gas within the multi-phase flow, and correcting the apparent gas void fraction to obtain a corrected gas void fraction, based on the apparent bulk density, the apparent mass flow rate, and the apparent gas void fraction. Implementations may include one or more of the following features.
- a liquid fraction of the first liquid within the multi -phase flow may be determined based on the apparent bulk density, the apparent mass flow rate, and the corrected gas void fraction
- a system includes a conduit having a fluid flow therethrough, the fluid flow including at least a first liquid component, a second liquid component, and a gas component, a vibratable flowtube in series with the conduit and having the fluid flow therethrough, a first sensor operable to determine a first apparent property of the fluid flow through the conduit, a second sensor connected to the flowtube and operable to sense information about a motion of the flowtube, a driver connected to the flowtube and operaoie to imp ⁇ rt energy to the flowtube, a control and measurement system operable to measure a second apparent property and a third apparent property of the fluid flow, and a corrections system operable to determine a corrected first property, a corrected second property, and a corrected third property, based on the first apparent property, the second apparent property, and the third apparent property.
- a system includes a controller that is operable to determine a first apparent property of a fluid flow in which a first liquid, a second liquid, and a gas are co-mingled, a meter that is operable to measure a second apparent property of the fluid flow, and a corrections module that is operable to input the first apparent property and output a first corrected property, wherein the meter is operable to input the first corrected property and the second apparent property and output a second corrected property.
- FIG. 1 A is an illustration of a Coriolis flowmeter using a bent flowtube.
- FIG. IB is an illustration of a Coriolis flowmeter using a straight flowtube.
- FIG. 2 is a block diagram of a Coriolis flowmeter.
- FIG. 3 is a flowchart illustrating an operation of the Coriolis flowmeter of FIG. 2.
- FIG. 4 is a flowchart illustrating techniques for determining liquid and gas flow rates for a two-phase flow.
- FIGS. 5 A and 5B are graphs illustrating a percent error in a measurement of void fraction and liquid fraction, respectively.
- FIG. 28 is a flowchart illustrating a third example of the techniques of FIG. 25.
- FIG. 29 is a flowchart illustrating techniques for determining component flow rates for a three-phase flow.
- FIG. 30 is a flowchart illustrating more specific techniques for performing the determinations of FIG. 29.
- FIGS. 31A-31D are graphs illustrating correction of a mass flow rate of a two-phase liquid in a three-phase flow.
- FIG. 32 is a graph showing a mass flow error as a function of mass flow rate for oil and water.
- FIG. 33 is a graph showing a gas void fraction error as a function of true gas void fraction.
- FIG 34 is a graphical representation of a neural network model.
- FIG. 35 is a graphical representation of units of the model of FIG. 34.
- FIGS. 36A, 36B, and 37A-D illustrate results from two-phase flow data to which the model of FIGS. 34 and 35 is applied.
- FIGS. 38-68 are graphs illustrating test and/or modeling results of various implementations described above with respect to FIGS. 1-37, or related implementations.
- DETAILED DESCRIPTION Types of flowmeters include digital flowmeters.
- U.S. Patent 6,311,136 which is hereby incorporated by reference, discloses the use of a digital flowmeter and related tcchnoiogy including signal processing and measurement techniques. Such digital flowmeters may be very precise in their measurements, with little or negligible noise, and may be capable of enabling a wide range of positive and negative gains at the driver circuitry for driving the conduit.
- FIG. 1A is an illustration of a digital flowmeter using a bent flowtube 102.
- the bent flowtube 102 may be used to measure one or more physical characteristics of, for example, a (traveling) fluid, as referred to above.
- a pressure sensor 225 is in communication with the transmitter 104, and is connected to the flowtube 215 so as to be operable to sense a pressure of a material flowing through the flowtube 215. It should be understood that both the pressure of the fluid entering the flowtube 215 and the pressure drop across relevant points on the flowtube may be indicators of certain flow conditions. Also, while external temperature sensors may be used to measure the fluid temperature, such sensors may be used in addition to an internal flowmeter sensor designed to measure a representative temperature for flowtube calibrations. Also, some flowtubes use multiple temperature sensors for the purpose of correcting measurements for an effect of differential temperature between the process fluid and the environment (e.g., a case temperature of a housing of the flowtube).
- a liquid fraction probe 230 refers to a device for measuring a volume fraction of liquid, e.g., water, when a liquid in the flowtube 215 includes water and another fluid, such as oil.
- a probe, or similar probes may be used to measure the volume fraction of a fluid other than water, if such a measurement is preferred or if the liquid does not include water.
- a presence of gas in the fluid flow also may affect both an actual and a measured value of a density of the fluid flow, generally causing the density measurement to be, and to read, lower than if the fluid flow contained only the liquid component. That is, it should be understood that a density p ⁇ ,q U i d of a liquid flowing by itself through a flowtube will be higher than an actual density p trUe of a two-phase flow containing the liquid and a gas, since a density of the gas (e.g., air) will generally be lower than a density of the liquid (e.g., water) in the two-phase flow. In other words, there is a density reduction when gas is added to a liquid flow that previously contained only the liquid.
- a density p ⁇ ,q U i d of a liquid flowing by itself through a flowtube will be higher than an actual density p trUe of a two-phase flow containing the liquid and a gas, since a density of the gas (e.g.
- the resonant frequency used by the flowmeter may be correct for a situation in which only the liquid component is present, but, due to relative motion of the gas in the fluid flow, which serves to mask an inertia of the flowtube (i.e., causes an amount of inertia to be less than would be expected for a liquid-only flow), the density measurement may read low. It should be understood that many conventional prior art flowmeters were unconcerned with this problem, since most such Coriolis meters fail to continue operating (e.g. stall or output inaccurate measurements) at even the slightest amounts of void fraction.
- a measured ⁇ apP arent may be corrected to obtain an actual bulk density p COrrected> which is, at least approximately, equal to ptrue-
- an indicated bulk mass flow rate MF apparent i.e., a mass flow rate of the entire two-phase flow
- correction techniques for corrected bulk mass flow rate MF true may be different than the techniques for correcting for density.
- various techniques for correcting a measured MF appare nt to obtain an actual MFtrue (or, at least, MF corre cted) are discussed in U.S. Patent No.
- the digital transmitter is shown as including a density correction system 240, which has access to a density correction database 245, and a mass flow rate correction system 250, which has access to a mass flow correction database 255.
- the databases 245 and 255 may contain, for example, correction algorithms that have been derived theoretically or obtained empirically, and/or correction tables that provide corrected density or mass flow values for a given set of input parameters.
- the databases 245 and 255 also may store a variety of other types of information that may be useful in performing the density or mass flow corrections.
- the void fraction determination/correction system 260 may determine an actual void fraction ⁇ trUe from the corrected density p cor r ec t e d- In another implementation, the void fraction determination/correction system 260 may input an apparent or indicated void fraction measurement obtained by the void fraction sensor 235, and may correct this measurement based on an error characterization similar to the density and mass flow techniques referred to above. In another implementation, the void fraction sensor 235 may be operable to directly measure an actual void fraction ⁇ trU e, in which case the void fraction determination/correction system 260 simply inputs this measurement.
- a flow component mass flow rate determination system 265 operates to simultaneously determine a mass flow rate for the liquid phase component and a mass flow rate for the gas phase component. That is, the transmitter 104 is operable to determine individual flowrates MF ⁇ qU i d and MF gas of the flow components, as opposed to merely determining the bulk flowrate of the combined or total two-phase flow MF true . Although, as just referred to, such measurements may be determined and/or output simultaneously, they also may be determined separately or independently of one another.
- a flow regime is a term that refers to a characterization of the manner in which the two phases flow through the flowtube 215 with respect to one another and/or the flowtube 215, and may be expressed, at least partially, in terms of the superficial velocities just determined.
- one flow regime is known as the "bubble regime,” in which gas is entrained as bubbles within a liquid.
- the "slug regime” refers to a series of liquid “plugs" or “slugs” separated by relatively large gas pockets.
- the gas in a slug flow regime may occupy almost an entire cross-sectional area of the flowtube 215, so that the resulting flow alternates between high-liquid and high-gas composition.
- Other flow regimes are known to exist and to have certain defined characteristics, including, for example, the annular flow regime, the dispersed flow regime, and froth flow regime, and others.
- the existence of a particular flow regime is known to be influenced by a variety of factors, including, for example, a gas void fraction in the fluid flow, an orientation of the flowtube 215 (e.g., vertical or horizontal), a diameter of the flowtube 215, the materials included within the two-phase flow, and the velocities (and relative velocities) of the materials within the two phase flow.
- FIG. 3 illustrates techniques by which the flowmeter 200 of FIG. 2 is operable to simultaneously determine liquid and gas flow rates MF
- j qu id liquid and gas flow rates
- MF gas gas/liquid two-phase flow exists in the flowtube 215 (302). This can be done, for example, by an operator during configuration of the mass flowmeter/densitometer for gas/liquid flow. As another example, this determination may be made automatically by using a feature of the Coriolis meter to detect that a condition of two- phase gas-liquid flow exists. In the latter case, such techniques are described in greater detail in, for example, U.S. Patent number 6,311,136 and U.S. Patent number 6,505,519, incorporated by reference above.
- a corrected bulk density p COrrected is established (304) by the density correction system 240, using the density correction database 245 of the transmitter 104. That is, an indicated density p apPa r ent is corrected to obtain ⁇ CO rrected- Techniques for performing this correction are discussed in more detail below.
- a corrected gas void fraction ⁇ co ⁇ -ect e d may be determined (306) by the void fraction determination/correction system 260.
- a corrected bulk mass flow rate MFcorrected is determined (308) by the mass flow rate correction system 250.
- the corrected void fraction ⁇ COrrected is determined based on previously- calculated corrected density p CO rrected > whereupon the corrected mass flow rate MF cor rected is determined based on ⁇ cor rected-
- ⁇ CO rrected and p cor rected may be calculated independently of one another, and/or p CO rrected and MFcorrected may be calculated independently of one another.
- the superficial velocities SV gas and SN ⁇ , qu ,d represent corrected values sv correcte and sv corrected
- the density values ⁇ gas and p iiquid refer, as above, to known densities of the liquid and gas in question, which may be stored in the density correction database 245.
- the density values p gas and p ⁇ , qU ⁇ d may be known as a function of existing temperature or pressure, as detected by temperature sensor 220 and pressure sensor 225.
- FIG. 4 is a flowchart 400 illustrating techniques for determining liquid and gas flow rates MF ⁇ , qu , d and MF gas for a two-phase flow. That is, the flowchart 400 generally represents one example of techniques for determining liquid and gas flow rates (310), as described above with respect to FIG. 3.
- the determination of liquid and gas flow rates (310) begins with inputting the corrected density, void fraction, and mass flow rate factors ⁇ CO rrected, ⁇ corrected, and MF corrected (402).
- the liquid and gas flow rates are determined (406) using Eqs. 3 and 4:
- gas entrained in liquid forms a two-phase flow.
- Measurements of such a two-phase flow with a Coriolis flowmeter result in indicated parameters p app arent, o a pp are ⁇ t , and MF appare nt for density, void fraction, and mass flow rate, respectively, of the two- phase flow. Due to the nature of the two-phase flow in relation to an operation of the
- FIGS. 5 A and 5B are graphs illustrating a percent error in a measurement of void fraction and liquid fraction, respectively.
- the percent error is a density percent error that is dependent on various design and operational parameters, and generally refers to the deviation of the apparent (indicated) density from the true combined density that would be expected given the percentage (%) of gas in liquid.
- true liquid fraction versus indicated liquid fraction is illustrated.
- FIG. 5B shows the results, for the relevant flowmeter design, of several line sizes and flow rates.
- the functional relationship may be more complex and depend on both line size and flowrate.
- FIG. 5B a simple polynomial fit is shown that can be used to correct the apparent liquid fraction.
- Other graphing techniques may be used; for example, true void fraction may be plotted against indicated void fraction.
- FIG. 6 is a graph illustrating a mass flow error as a function of a drop in density for a flowtube having a particular orientation and over a selected flow range.
- FIG. 7 is a flowchart 700 illustrating techniques for correcting density measurements (304 in FIG. 3). In FIG.
- the process begins with an inputting of the type of flowtube 215 being used (702), which may include, for example, whether the flowtube 215 is bent or straight, as well as other relevant facts such as a size or orientation of the flowtube 215.
- a gas-free density of the liquid, p ⁇ , qu , d is determined (704). This quantity may be useful in the following calculation(s), as well as in ensuring that other factors that may influence the density measurement p appar ent, such as temperature, are not misinterpreted as void fraction effects.
- the user may enter the liquid density p ⁇ , qu ⁇ d directly, along with a temperature dependence of the density.
- known fluids may be stored in the density correction database 245, in which case the user may enter a fluid by name.
- the flowmeter 200 may determine the liquid density during a time of single- phase, liquid flow, and store this value for future use.
- An indicated mass flow rate MF apparent is read from the Coriolis meter (706), and then an indicated density ⁇ apparent is read from the Coriolis meter (708).
- the density correction system 240 applies either a theoretical, algorithmic (710) or empirical, tabular correction (712) to determine the true density p trUe of the gas/liquid mixture.
- the quantity p ⁇ e may then be output as the corrected density (714).
- Eq. 1 1 shows the quantity ⁇ p as being positive; however, this quantity could be shown as a negative drop simply by multiplying the right-hand side of the equation by -1, resulting in Eq. 12:
- Eqs. 12 or 13 may thus be used to define the following two quantities: a corrected or true density drop, ⁇ p true , and an indicated or apparent density drop, ⁇ p app .
- Eqs. 14 and 15 this results in Eqs. 14 and 15:
- M generally depends on the complexity of the empirical relationship, but in many cases can be as small as 2 (quadratic) or 3 (cubic).
- the mass flow rate correction system 250 applies either a tabular (1006) or algorithmic correction (1008) to determine the true mass flow rate MF gag of the gas/liquid mixture.
- the quantity MF lrue may then be output as the corrected mass flow rate (1010).
- knowledge of the quantities ⁇ ptme and ⁇ MF appar ent may be used to determine MF tme by employing a table having the form of a table 1100 of FIG. 11.
- the table 1100, as with the table 800 may be, for example, a tabular look-up table that can be, for example, stored in the database 245, or in another memory, for use across multiple applications of the table.
- the table may be populated during an initialization procedure, for storage in the database 255 for an individual application of the table.
- Normalized values MF n0 rm_app and MF n orm_true may be used in place of the actual ones shown above, in order to cover more than one size Coriolis flowtube.
- the entries can be in terms of the correction, where the correction is defined by Eq. 18:
- pi ⁇ qu ⁇ and flowtube cross-section A T are known or entered parameters, and may be real-time corrected for temperature using, for example, the on-board temperature measurement device 220 of the digital controller/transmitter 104.
- either or both of the algorithmic and tabular forms may be extended to include multiple dimensions, such as, for example, gain, temperature, balance, or flow regime.
- the algorithmic or tabular correction also may be extended to include other surface fitting techniques, such as, for example, neural net, radical basis functions, wavelet analyses, or principle component analysis.
- surface fitting techniques such as, for example, neural net, radical basis functions, wavelet analyses, or principle component analysis.
- mass flow rate may be determined as described above.
- the mass flow rate may be further corrected using the flow regime information.
- FIGS. 12-14 are graphs illustrating examples of density co ⁇ ections for a number of flowtubes. In particular, the examples are based on data obtained from three vertical water flowtubes, the flowtubes being: V", 3 / 4 ", and 1" in diameter.
- the Vi" data was taken with a 0.15kg/s flow rate and a 0.30kg/s flow rate; the %" data was taken with a 0.50kg/s flow rate and a l.OOkg/s flow rate; and the 1 " data was taken with a 0.50kg/s flow rate, a 0.90kg/s flow rate, and a 1.20kg/s flow rate.
- FIG. 12 illustrates an e ⁇ or, e d , of the apparent density of the fluid-gas mixture (two-phase flow) versus the true drop in density of the fluid-gas mixture, ⁇ ptr ue :
- both the apparent and true drop in density of the mixture were normalized to values between 0 and 1 by dividing them through by 100, where this normalization is designed to ensure numerical stability of the optimization algorithm.
- the normalized apparent and true drop in mixture density are the apparent and true drop in mixture density defined as a ratio, rather than as a percentage, of the liquid density p ⁇ , qu ,d, as shown in Eq. 24:
- FIGS. 13A and 13B illustrate the model with the experimental data and the residual e ⁇ ors, as shown.
- FIGS. 14A and 14B give the same information, but with each flow rate plotted separately.
- the drop in density co ⁇ ection is performed in the transmitter 104 by calculating the apparent density drop ⁇ p appar ent, using the apparent density value p apparent and the liquid density p ⁇ , qU ⁇ d- The value of the apparent drop in density is normalized to obtain
- FIGS. 15-20 are graphs illustrating examples of mass flow rate co ⁇ ections for a number of flowtubes. In particular, the examples are based on data obtained from three vertical water flowtubes, the flowtubes being: V", 3 / 4 ", and 1" in diameter.
- the Vi" data was taken with a 0.15kg/s flow rate and a 0.30kg/s flow rate; the 3 /" data was taken with a 0.50kg/s flow rate and a l.OOkg/s flow rate; and the 1" data was taken with 18 flow rates between 0.30kg/s and 3.0kg/s flow rate, with a maximum drop in density of approximately 30%.
- FIG. 16 illustrates apparent mass flow e ⁇ ors versus co ⁇ ected drop in mixture density and normalized apparent superficial fluid velocity, with safety bounds for the co ⁇ ection mode. That is, FIG.
- FIG. 17 illustrates a scatter plot for the model residuals, together with the model formula and coefficients; i.e., shows model residuals versus the co ⁇ ected drop in mixture density and normalized true fluid velocity.
- FIGS. 18A-18D and Figures 19A-19D give the model residual e ⁇ ors for the whole data set used to fit the model and the actual data alone, respectively.
- FIGS. 20A and 20B illustrate the model surface both interpolating and extrapolating outside the safe fit area. From FIGS.
- mass flow co ⁇ ection in the transmitter 104 is undertaken in this example by calculating an apparent drop in density, co ⁇ ecting it using the method(s) described above, and normalizing the resulting value by dividing it by 100 (or use the obtained normalized co ⁇ ected drop in density from the density model). Then, a normalized superficial fluid velocity v n is calculated, and the model is applied to obtain an estimation of the normalized mass flow e ⁇ or e n , where this value gives the e ⁇ or of the apparent mass flow as a ratio of the true mass flow.
- the obtained value may be un-normalized by multiplying it by 100, to thereby obtain the mass flow e ⁇ or as a percentage of the true mass flow.
- the techniques described above are particularly useful in measurement applications where the mass flow of the liquid phase and the mass flow of the gas phase must be measured and/or co ⁇ ected to a high level of accuracy.
- One exemplary application is the measurement of the mass flow of the liquid phase and the measurement of the gas phase in oil and gas production environments.
- any vibrating or oscillating densitometer or flowmeter, analog or digital, that is capable of measuring multi-phase flow that includes a gas phase of a certain percentage may be used. That is, some flowmeters are only capable of measuring process fluids that include a gas phase when that gas phase is limited to a small percentage of the overall process fluid, such as, for example, less than 5%. Other flowmeters, such as the digital flowmeter(s) referenced above, are capable of operation even when the gas void fraction reaches 40% or more. Many of the above-given equations and calculations are described in terms of density, mass flow rate, and/or void fraction.
- a volumetric flow may be used.
- liquid fraction may be used.
- Flowmeters also may be used to measure further mixed flows.
- a "three-phase" flow or “mixed two-phase flow” refers to a situation in which two types of liquid are mixed with a gas.
- a flowing mixture of oil and water may contain air (or another gas), thus forming a "three-phase flow,” where the terminology refers to the three components of the flow, and does not generally imply that a solid material is included in the flow.
- the flowmeter system 2100 may be used, for example, to determine individual component flow rates within a three-phase flow. For example, the system 2100 may be used to determine an amount of oil within an oil, water, and gas flow that travels through a pipe at an oil extraction facility, during a given period of time.
- the flowmeter system 2100 also may be used to obtain highly-accurate measurements from the digital transmitter 104, such as, for example, density measurements or mass flow rate measurements.
- the system 2100 also may be used, for example, to obtain an improved measurement from an external sensor, such as, for example, the liquid fraction probe 230, or the void fraction sensor 235, relative to what measurements might be obtained using the external sensor(s) alone.
- the digital transmitter 104 includes a void fraction determination system
- the systems 2102, 2104, and 2106 may be used to measure conesponding parameters of a fluid flow within the flow 215. Further, as also explained above, to the extent that the fluid flow contains gas and/or mixed liquids, the measurements output by the systems 2102, 2104, and 2106 generally represent raw or apparent values for the conesponding parameters, which ultimately may be co ⁇ ected with a co ⁇ ections system 2108.
- an apparent mass flow rate of a three-phase fluid flow within the flowtube 215 may be output to the co ⁇ ections system 2108 for co ⁇ ection using a mass flow rate co ⁇ ection module 2112, while an apparent density of the three-phase fluid flow within the flowtube 215 may be output to the co ⁇ ections system 2108 for co ⁇ ection using a density co ⁇ ection module 2118.
- a measurement or determination of an apparent void fraction within the fluid flow may be co ⁇ ected using a density co ⁇ ection module 2114, while a measurement or determination of an apparent liquid fraction (e.g., water cut from probe 230) may be co ⁇ ected using a water cut co ⁇ ection module 2116.
- the various co ⁇ ection modules 2112-2118 may work in conjunction with one ⁇ r-othcr, and/or with other components, in order to obtain their respective co ⁇ ected values.
- co ⁇ ected values such as mass flow rate, density, water cut, or void fraction (or some combination thereof) may be output to a host computer2110 for determination of individual mass flow rates of each of the three components of the three- phase fluid flow, using a component flow rate determination system 2120.
- a host computer2110 for determination of individual mass flow rates of each of the three components of the three- phase fluid flow, using a component flow rate determination system 2120.
- an example of the system 2100 includes three general elements used to obtain co ⁇ ected measurement values and/or individual component flow rates: the transmitter 104, one or more of the individual external sensors identified generically with a reference numeral 2122, and one or more elements of the co ⁇ ections system 2108.
- the digital transmitter 104 may not include the void fraction determination system 2102.
- the void fraction determination system 2102 may be included with, or associated with, the liquid fraction probe 230, or may be unneeded depending on a type or configuration of the void fraction sensor 235.
- the void fraction may be determined from outputs of the co ⁇ ection modules 2112, 2116, and/or 2118.
- the external sensors 2122 are shown in FIG. 21 to be in communication with the digital transmitter 104 and the flowtube 215, it should be understood that the external sensors 2122 may obtain their respective measurements in a number of different ways.
- examples of the temperature sensor 220, the pressure sensor 225, and the void fraction sensor 230 are described above, with respect to, for example, FIG 2.
- the liquid fraction probe 235 may be in series with the flowtube 215 with respect to a primary pipe for transporting the three-phase fluid flow, and may maintain separate communication with the transmitter 104, the co ⁇ ections system 2108, and/or the host computer 2110.
- the co ⁇ ections system 2108 is shown as being separate from the digital transmitter 104 and the host computer 2110. In some implementations, however, the co ⁇ ections system 2108 may be located within the digital transmitter 104, the host computer 2110, or may be associated with one or more of the external sensors 2122. In still other implementations, portions of the co ⁇ ections system 2108 may be included within different sections of the system 2100.
- the co ⁇ ections system 2108 may include all of the modules 2112-2118 (as shown), or some subset thereof, or may include other modules, not specifically illustrated in FIG. 21 (e.g., a co ⁇ ections module for co ⁇ ecting a density of the two-liquid component within the three-phase flow, such as the oil/water mixture in an oil/water/gas fluid flow). Further, some or all of any such co ⁇ ection modules may be integrated with one another.
- the mass flow rate and density co ⁇ ections may be incorporated into one module, while the water cut co ⁇ ection module 2116 may be separate.
- the component flow rate determination system 2120 may be situated in a number of places within the system 2100.
- the component flow rate determination system 2120 may be located within the co ⁇ ections system 2108, or may be located within the digital transmitter 104.
- the system 2100 and other implementations thereof allows for all or substantially all of the three-phase fluid flow to flow continuously through the flowtube 215 and through an associated pipe or other conduit for transporting the three-phase flow material.
- determinations of individual component flow rates do not require separation of the three-phase fluid flow into separate flows containing one or more of the constituent components.
- the three-phase flow contains oil, water, and gas
- reliable measurements of an amount of oil produced for example, at an oil production facility, may be made easily, quickly, inexpensively, and reliably.
- FIG. 22 is a diagram of a first implementation of the system 2100 of FIG. 21.
- the liquid fraction probe 230 is illustrated as a water cut probe that is in series with the digital transmitter 104 with respect to three-phase fluid flow through a pipe 2202. Examples of using measurements from the water cut probe 230 in determining flow measurements are provided in more detail below.
- a static mixer-sampler 2204 is illustrated that serves to homogenize the three-phase fluid.
- the mixer-sampler 2204 also may be used for other measurements, "or example, the mixer-sampler 2204 may be used to validate measurements of the water cut probe 230, or other measurements.
- the mixer-sampler 2204 may be used to siphon off a portion of a three-phase flow of oil/water/gas for evaporation of the gas therefrom, for independent confirmation of a water fraction within the resulting two-liquid composition.
- a pressure transmitter 2206 may be used in various post- processing techniques for validating or confirming measurements of the system.
- FIG. 23 is a block diagram of a second implementation of the system of FIG. 21.
- the liquid fraction probe 230 is illustrated as a microwave water-cut probe 230a and/or an infrared water-cut probe 230b.
- a power supply 2302 for supplying power to the system also is illustrated.
- FIG. 23 should be understood to contain, for example, the bent flowtube 102 of FIG. 1A, although, of course, the straight flowtube 106 of FIG. IB, or some other flowtube, also may be used.
- the sensors 230a, 230b, and/or 2206 are illustrated as being in bidirectional communication with the transmitter 104, including a standard 4-20m A control signal.
- the transmitter 104 is in communication with the host computer 2110 by way of a Modbus RS485 connection.
- FIG. 23 illustrates several possible locations for the co ⁇ ections system 2108.
- the co ⁇ ections system 2108 may be located at, or associated with, a processor associated with the host computer 2110, or with the digital transmitter 104, and/or with the water-cut probe 230a (and/or other external sensor 230b).
- FIG. 24 is a block diagram of an implementation of the co ⁇ ections system 2108 of FIGS. 21-23.
- the co ⁇ ections system 2108 inputs, from the transmitter 104, measurements such as an apparent (or raw) measurement of a liquid fraction (e.g., water cut) of the three-phase flow, along with an apparent bulk mass flow rate and apparent bulk density.
- the conections system 2108 in this example includes a water cut enor model 2402 and a Coriolis e ⁇ or model 2404.
- the models 2402 and 2404 allow for calculations of the co ⁇ ected, or the estimation of the true, conesponding measurements of water cut, mass flow rate, and density.
- 2402 and 2404 model known configurations and flow parameters, so that subsequently measured flow parameters may be conelated with the modeling results by way of, for example, interpolation.
- the models 2402 and 2404 may be implemented to provide polynomial fittings of measured (app ⁇ xent) flow parameters.
- the models 2402 and 2404 may represent neural net co ⁇ ection models for co ⁇ ecting water cut and mass flow/density.
- the available measurement includes an apparent water cut
- the resulting co ⁇ ected measurements allow for the calculation of the additional parameter of gas void fraction.
- the co ⁇ ections system may output a co ⁇ ected void fraction measurement (thereby allowing subsequent estimation of a true water cut).
- the co ⁇ ections system 2108 may output the co ⁇ ected measurements to the component flow rate determination system 2120 for calculation of individual component mass flow rates.
- each model 2402 and 2404 illustrates an example in which the outputs of each model 2402 and 2404 are fed back into one another, in order to obtain sequentially better results, before outputting a final value for conected water cut, (bulk) mass flow rate, and (bulk) density, and, thereafter, calculating individual component flows.
- the initial determination of an apparent water cut may be dependent on, and vary with, an amount of gas within the three-phase fluid flow (i.e., the gas void fraction).
- an accurate value of the gas void fraction may not generally be available until after an estimate of the true water cut measurement has been determined.
- the models 2402 and 2404 may be orthogonal to one another, so that one may be replaced without affecting an operation of the other. For example, if a new water cut probe is used (e.g., the probe 230a instead of the probe 230b of FIG.
- a conesponding water cut e ⁇ or model may similarly be substituted, while the Coriolis e ⁇ or model may continue to be used.
- a specific water cut probe, Coriolis meter, and configuration thereof with respect to one another are known and assumed to be unchanging, then it may be possible to construct a single enor model that inputs all three measurements of water cut, mass flow rate, and density, and outputs co ⁇ ected values of all thres (along w.tl , possibly, a conected gas void fraction). In such implementations, it may not be necessary to feed sequential results back into the enor model in order to obtain all three (or four, or more) conected values.
- FIG 25 is a flowchart 2500 illustrating a first operation of the flowmeter of FIGS. 21- 23. More particularly, FIG. 25 represents a high-level description of many different techniques and combinations of techniques, specific examples of some of which (along with other examples) are presented in more detail, below.
- existence of a three-phase flow is determined and apparent measurements are obtained (2502). For example, the transmitter 104 may obtain an apparent bulk density and an apparent mass flow rate, and the liquid fraction probe 230 may obtain an apparent water cut measurement. As shown in FIG. 21, these measurements may then be output to the co ⁇ ections system 2108.
- a co ⁇ ected water cut 2504
- conected bulk density 2506
- conected bulk mass flow rate 2508
- conected gas void fraction 2510
- the co ⁇ ected mass flow rate may be determined based only on apparent measurements, such as apparent mass flow rate, or may be determined based on these factors along with an already-co ⁇ ected density and/or gas void fraction measurement. Similar comments apply, for example, to techniques for obtaining conected density and/or gas void fraction measurements.
- a given conection may be obtained multiple times, with later conections being based on intervening co ⁇ ections of other parameters.
- a first-co ⁇ ected water cut measurement may be obtained, and may then be revised based on a following void fraction determination, to obtain a second-conected water cut measurement.
- individual component flow rates for one or more of the first liquid component, second liquid component, and gas component may be obtained (2512).
- FIG. 26 is a flowchart 2600 illustrating a first example of the techniques of FIG. 25.
- conecting bulk density may be associated with determining a water cut measurement, using the water cut probe 230.
- an existence of a three-phase flow having a first liquid, a second liquid, and a gas is assumed, and the process begins with a determination of an apparent water cut measurement (2602).
- the density of the mixture of the two liquids is determined (2604).
- an apparent gas void fraction apparent is determined (2606).
- the process 2600 continues with a determination of conected values of, for example, bulk density and bulk mass flow rate (2608). Once these values are known, a conection for gas void fraction corrected may be performed (2610), resulting in a new, revised determination of gas void fraction (2606). In this way, a conection of the initial water cut measurement may be performed (2612), so as to take into account an effect of the gas within the three-phase flow on the initial water cut measurement (2602), and thereby obtain an improved water cut measurement. Then, the improved water cut measurement may be used to determine and improve the liquid density measurement (2604), which, in turn, may be used to determine a co ⁇ ected or improved gas void fraction measurement (2606).
- a conection for gas void fraction corrected may be performed (2610), resulting in a new, revised determination of gas void fraction (2606).
- a conection of the initial water cut measurement may be performed (2612), so as to take into account an effect of the gas within the three-phase flow on the initial water cut measurement
- the Coriolis flowmeter may measure the mixture (bulk) density, p ⁇ , qu id, and the mixture mass flow rate, MF.
- the water cut of the mixture is then calculated based on Eq. 29. This technique is described in more detail in, for example, U.S. Patent No. 5,029,482, assigned to Chevron Research Company, and may be useful in deriving water cut from a density measurement using a Coriolis flowmeter.
- the volumetric flow rate of the liquid (oil-water) mixture may be derived using Eq. 30:
- the two independent measurements of bulk (mixture) density and mass flow rate by the Coriolis flowmeter provide sufficient information to satisfy the mathematical closure requirement where two components are present in the combined stream.
- Eqs. 29 and 30 cannot be directly applied when three distinct phases (i.e., oil, water and gas) are in a co-mingled stream, i.e., a three-phase flow, as discussed above with respect to FIGS. 21-25, because the Coriolis flowmeter may measure the density and massflow of the mixture of the two liquids and gas.
- a third component is introduced which benefits from a third independent source of information to satisfy mathematical closure for three-phase flow.
- the independent information is provided by another device installed in-line with the Coriolis flowmeter, which encounters the same three- phase mixture, i.e., the water cut probe 230.
- the water cut probe 230 as described above with respect to FIGS. 21-25, may be of any possible technologies including microwave, capacitance, capacitance-inductance, nuclear magnetic resonance, infrared, and near infrared, and may be implemented using a combination of these types of water cut probes. The use of other types of water cut probes (or, more generally, liquid fraction probes) is envisioned within the scope of the present description, as well.
- the transmitter 104 may be used to provide an apparent bulk density, p aPpar e n t as well as an apparent bulk mass flow rate, MF a pp arer ,t.
- the water cut probe 230 may be used to obtain an apparent water cut measurement C appar e n t-
- the density of the oil-water liquid portion only of the three-phase mixture may thus be derived from the water cut information as shown in Eq. 31 , where, as above, component liquid densities are known or may be obtained, for example, according to techniques that also are described above.
- P liquid ⁇ " ⁇ apparent )P OIL + " ⁇ appar nt Pw " '
- the gas void fraction, a is defined as the volume fraction occupied by the gas phase in the three-phase mixture.
- a definition of ⁇ in terms of apparent or non-conected values, is provided above and repeated here as Eq. 32: apparent "liqui apparent r vas r ⁇ liquid Eq. 32
- the density of the gas phase in Eq. 32 above may be calculated based on an independent measurement of process pressure and temperature.
- pressure may be measured with the pressure transmitter 225, while the temperature is either measured independently using a temperature transmitter or obtained from the Coriolis flowmeter's temperature, e.g., the temperature sensor 220, such as a Resistance Temperature Detector
- RTD gas phase density
- AGA American Gas Association
- AGA American Gas Association
- the calculated liquid phase density (2604) and gas void fraction (2606) based on the water cut input are approximations, since the water cut measurement itself is affected by the presence of gas, which heretofore is unknown.
- a solution technique to converge to the conect liquid phase density and gas void fraction may thus be used, as shown in FIG. 26. Specifically, following application of mass flow and bulk density co ⁇ ections, an updated gas void fraction is obtained (2610, 2606). This updated gas void fraction value is then applied to the water cut reading to correct for the effect of the presence of gas (2612,
- an apparent water cut measurement may be a function of many different parameters, so that a co ⁇ ected water cut measurement WC corre ct ed may generally be a function of the same parameters, co ⁇ ected values of those parameters, and/or of the apparent water cut measurement itself.
- the process is repeated, starting with Eq. 31, until suitable convergence criteria has been satisfied. Then, the co ⁇ ected three-phase mixture (bulk) mass flow rate, density, and gas void fraction may be reported at process temperature.
- the individual volumetric flow rate of each phase/component is then calculated and co ⁇ ected to standard temperature using, for example, the American Petroleum Institute (API) equations for crude oil and produced water, and the AGA algorithms for produced gas.
- API American Petroleum Institute
- the water cut meter 230 may be operable to feed its measurement signal and information directly into either an analog or digital communications port (input/output) of the transmitter 104.
- the water cut meter is capable of communicating with the transmitter 104 in a bi-directional communications mode. As part of this implementation, the water cut meter is able to feed its measured signal and information directly into the communications port of the transmitter 104 as just described.
- the transmitter 104 also may be capable of sending signals and information to the water cut probe 230.
- FIG. 27 is a flowchart 2700 illustrating a second example of the techniques of FIG. 25.
- the process 2700 begins with a determination of an apparent water cut measurement (2702). Then, the water cut measurement may be used to determine a density of the total liquid component (e.g., a density of a combined oil and water portion of the three-phase flow), perhaps using Eq. 31 (2704).
- a density of the total liquid component e.g., a density of a combined oil and water portion of the three-phase flow
- Eq. 31 e.g., a density of a combined oil and water portion of the three-phase flow
- An apparent bulk density of the multiphase flow, or an apparent density drop as described above, may be determined (2706), and an apparent gas void fraction may be determined, either independently of, or based on, the apparent bulk density (2708).
- an apparent mass flow rate of the total liquid component may then be calculated (2710), using some or all of the previously-calculated parameters.
- first values for co ⁇ ected and bulk density and co ⁇ ected bulk mass flow rate may be determined (2712). Then, values for a conected gas void fraction (2714), a co ⁇ ected total liquid component mass flow rate (2716), and a revised or co ⁇ ected water cut measurement (2718) may be determined. With the revised water cut measurement and other parameters, a revised gas void fraction measurement may be obtained. Then, as shown, further co ⁇ ections to the bulk mass flow rates and bulk density may be performed, and this process may be repeated until a suitable level of co ⁇ ection is reached. And, as described above with respect to FIGS.
- FIG. 28 is a flowchart 2800 illustrating a third example of the techniques of FIG. 25.
- the process of FIG. 28 begins, as in the process 2700, with determinations of water cut measurements, total liquid density, and apparent bulk density (2702, 2704, 2706). Then, an apparent bulk mass flow rate is determined (2802). Based on this information, co ⁇ ected values for bulk density and bulk mass flow rate may be determined (2804).
- a gas density may be determined, as, for example, a function of pressure and temperature (2806). Accordingly, a gas void fraction can be determined (2808) and co ⁇ ected (2810). Using the co ⁇ ected gas void fraction, a revised water cut measurement can be determined (2812), and used to calculate an improved liquid density, and the process repeated until a satisfactory result is reached.
- a gas void fraction can be determined (2808) and co ⁇ ected (2810).
- a revised water cut measurement can be determined (2812), and used to calculate an improved liquid density, and the process repeated until a satisfactory result is reached.
- specific examples, equations, and techniques are presented below for implementing the processes of FIGS. 27 and 28. Of course, other techniques also may be used.
- the water cut probe 230 or other instrument, as described above, provides a measurement of the volumetric ratio of water to bulk liquid in the liquid phase, as shown in
- the water cut value WC initially represents an apparent water cut value (i.e., calculated based on apparent values of mass flow and density) that may be improved or co ⁇ ected as the processes continue, as already described:
- FIG. 29 is a flowchart 2900 illustrating techniques for determining component flow rates for a three-phase flow. That is, FIG. 29 co ⁇ esponds to a more detailed view of determining component flow rates, as shown in FIG. 25 (2512).
- FIG. 29 is a flowchart 2900 illustrating techniques for determining component flow rates for a three-phase flow. That is, FIG. 29 co ⁇ esponds to a more detailed view of determining component flow rates, as shown in FIG. 25 (2512).
- FIG. 29 co ⁇ esponds to a more detailed view of determining component flow rates, as shown in FIG. 25 (2512).
- a co ⁇ ected liquid flow rate is determined (2904), i.e., a flow rate of the mixture of the two liquids (e.g., oil and water) in the three-phase flow.
- a mass flow rate of a first liquid component e.g., water
- a mass flow rate of the second liquid component e.g., oil
- the co ⁇ ected density, gas void fraction, and/or water cut value may be used to determine a mass flow rate of the gas component of the three-phase flow (2910).
- FIG. 30 is a flowchart 3000 illustrating examples of more specific techniques for performing the determinations of FIG. 29.
- the co ⁇ ected mass flow rates of the liquid and its components are determined independently of the co ⁇ ected density or gas void fraction measurements. Specifically, an apparent gas void fraction is determined (3002), using Eq. 32, above. Then, an apparent gas flow rate is determined (3004), using Eq. 36:
- an apparent superficial gas velocity is determined (3006).
- the apparent liquid flow rate may then be determined (3008).
- Apparent superficial liquid velocity can then be determined (3010).
- the volume flowrate of the liquid may be divided by the flowtube cross sectional area A j , as shown above and reproduced here in Eq. 2: r ⁇ liquid
- an e ⁇ or rate for liquid mass flow measurement is determined (3012). This e ⁇ or in the apparent liquid mass flowrate may be defined as a fraction of the true liquid mass flow, as shown in Eq. 38:
- Eq. 39 refers to a normalized apparent liquid flow (replacing "1" with "g” in the subscript for the conesponding gas parameter), where normalization is based on, for example, a maximum possible flowrate(s), as indicated by v ⁇ max and V gmax .
- a co ⁇ ected liquid mass flow rate measurement may be determined (3014), using Eqs. 38 and 39, expressed here as Eq. 40:
- the water cut and component densities may be determined (3016), or obtained using the above-described techniques, and used to determine a co ⁇ ected oil flow rate and a co ⁇ ected water flow rate (3018). Then, using the conected bulk density and co ⁇ ected gas void fraction (3020), a co ⁇ ected gas flow rate may be determined (3022). For example, the water and oil mass flowrates may be calculated, using Eqs. 41 and 42:
- the gas mass flowrate may be determined using Eqs. 43 and 44:
- Such a calculation also may be used in 2-phase flow modeling results as described above, to consider resulting residual e ⁇ or in the modeling.
- the model least square fit may be modified to minimize the resultant mass flow e ⁇ or rather than the model e ⁇ or.
- a flowtube may be expected to exhibit small mass flow e ⁇ ors, so that if a flowmeter is expected to co ⁇ ect for large e ⁇ ors, then the e ⁇ or modeling (and hence experimental data) becomes relatively more important.
- apparent superficial velocities are used to carry out mass flow co ⁇ ections, so as to decouple the bulk density correction from the liquid mass flow conection.
- FIGS. 31A-31D are graphs illustrating conection of a mass flow rate of a two-phase liquid in a three-phase flow.
- FIGS. 31 A-31D show the predicted liquid mass flow e ⁇ ors when the 3-phase flow co ⁇ ection algorithm is applied to data obtained from four oil+water+gas trials using a vertical orientation.
- FIGS. 31 A-31D show that the basic co ⁇ ection curve does work within 5% for all but the highest gas flows, which are outside the range of data used for modeling.
- FIG. 32 is a graph showing a mass flow e ⁇ or as a function of mass flow rate for oil and water.
- FIG. 33 is a graph showing a gas void fraction enor as a function of true gas void fraction.
- 32 and 33 illustrate the e ⁇ ors in estimating the three mass flow fractions by spreadsheet implementation of the above algorithms.
- the actual determination of the gas mass flow may be affected by uncertainty in the mixture density and a relative difference in density between the liquid and gas phase.
- the density conection polynomial discussed above may be more or less applicable depending on, for example, flowtube orientation. As a result, for example, horizontal flow may result in a lower enor than vertical flow, or vice- versa.
- the use of superficial liquid and gas velocities may enable the conection algorithms to include knowledge of the multi-phase flow regimes encountered, which may lead to better co ⁇ ection algorithms.
- a sampling system may be used that takes a representative sample of the mixture, de-gasses it and uses a Coriolis meter to determine the water cut.
- knowledge of the liquid and gas densities at the operation temperature and pressure may be used with the co ⁇ ected density and massflow measurements to calculate each of the liquid and gas mass flow rates, and, thereby, the liquid and gas volumetric flow.
- extra, external measurements may be used to enable the estimation of gas mass flow and the mass flow of each of the two liquids.
- the water cut of the mixture may be measured up-stream of the Coriolis meter, as explained and illustrated above.
- This assumption makes the three-phase flow an extension of the single-liquid two-phase flow, the extra measurements being used to determine the mixed liquid density and to decouple the separate liquid massflows, after two-phase flow calculations are applied.
- a Coriolis meter will generally under-read both the mixture density and the mixture massflow of a liquid/gas mixture.
- a model for the e ⁇ or surfaces may be used so as to find a mapping between the raw density and massflow measurements, and the value of the raw measurement e ⁇ ors, for both massflow and density measurements, i.e., to perform a data fitting.
- both the density and massflow enor curve may depend on many factors, such as, for example, meter size, meter orientation (e.g., horizontal vs. vertical), and a nominal liquid mass flow. Accordingly, co ⁇ ections may be developed for each individual meter size and orientation. In other implementations, the compensations may be scaled according to meter size and/or adjusted according to meter alignment. others. For example, FIG.
- neural network models present at least the following advantageous features.
- such models provide the ability to derive a non-linear functional mapping from a sufficiently large and representative database of relevant measurements, without prior knowledge of the underlying physical model of the process.
- Such a feature may be particularly advantageous in the example of the two/three-phase flow compensation problem, where actual physical processes inside the tube may be difficult to obtain.
- a viable solution for a particular problem may be significantly reduced compared with other data fitting techniques, which may rely on domain expertise.
- changing meter size/orientation/type might completely change the shape of the raw measurements surface, and for a conventional data technique, this may imply a process of finding another form for the functional mapping that is not guaranteed to find a solution in a reasonable time.
- the neural network training may find the "best" (in the sense of the cost function chosen to control the network training) solution for the data available by adjusting its internal parameters during the training process.
- the following discussion provides explanation of one example of a neural network, i.e., an MLP model. Specifically, FIG.
- FIG. 34 is a graphical representation of the MLP model.
- MeasError F(dd, m) , with dd the apparent drop in mixture density and m the apparent massflow of the liquid. It should be noted that this notation is slightly different from the above notation for the same parameters, i.e., ⁇ p and MF, respectively.
- FIG. 34 thus illustrates a multi-layer perceptron (MLP) model with two inputs (dd 3402 and m 3404) and one output (MeasE ⁇ or 3406). The behavior of each unit is graphically represented in Figure 35.
- MLP multi-layer perceptron
- an MLP is a feed-forward neural network architecture with several layers of units. Being feed-forward means that the data flows monotonically from inputs to outputs, without inner loops; this ensures that the outputs function is deterministic.
- the MLP used for two-phase flow measurement e ⁇ or compensation may be a two-layer architecture with sigmoidal activation functions for hidden units 3308 and linear activation function for the output unit 3410.
- Eq. 47 represents a non-linear function in apparent drop in mixture density and massflow, with nh the number of hidden units 3408.
- the network parameters W" pul , w 0l " p ⁇ " and nh may be determined during a process called network training, essentially, an optimization of a cost function.
- nh has to be sufficiently large (it actually dictates the degree of freedom for the model, hence its complexity).
- its value should be chosen appropriately; a value too small may lead to a poor fit to the training data, while too large a value may lead to poor generalisation capabilities due to over-fitting the training data (the parallel in the field of conventional polynomial data fitting is the degree of the polynomial).
- the training set used to iteratively change the values of the MLP weights to minimize the cost function
- the validation set used to stop the training early to avoid over-fitting the training data
- the test set used to choose the number of hidden units
- a pre-defined cost function e.g., the mean square e ⁇ or.
- the outputs of the MLP conesponding to the data in the training set may be evaluated, and the values of the weights are updated according to a specific "learning rule," as known in the field of neural network design, in order to minimize the cost function value over the training set.
- the cost function also may be evaluated over the validation set, and the training stopped when this starts increasing, so that a suitable compromise between the fit of the training data and the generalization capabilities may be achieved.
- a test set also may be used to assess the performance of several MLP trained, as described, but with different numbers of hidden units to choose the architecture that gives the minimum cost function over the test set.
- massflow compensation for a low GVF region, the compensation accuracy may be increased if this area is considered separate from the rest and modeled accordingly.
- Such approach(es) suggest the use of a "committee of models,” also refe ⁇ ed to as a “mixture of experts,” with separate but overlapping areas of expertise to enable soft switching between the models.
- Model 1 0-1.5.kg/s
- Model 2 0-1.5kg/s
- Model 3 1.2kg/s upwards
- Model 4 1.2kg/s upwards
- a different model, refened to as a "blanket model,” also may be trained using the whole range of flows and GVFs.
- the blanket network may be used to provide a rough idea about the true liquid massflow.
- FIGS. 36A, 36B, and 37A-D illustrate results from two-phase flow data collected for a 1" Coriolis flowmeter, in both horizontal and vertical alignment, with water and air. Fifty- five flowlines were used, with nominal flow ranging from 0.35 kg/s to 3.0 kg/s in steps of 0.025kg/s, with typical GVF steps of 0.5% and 1%GVF (depending on the nominal flow value), giving a total of 3400 experimental points, for an average of 45 points per flowline.
- FIGS. 36A and 36B The conesponding surfaces for raw density and massflow e ⁇ ors are given in FIGS. 36A and 36B, respectively. Based on this data, compensation solutions for density and liquid massflow e ⁇ ors as described above may be derived and validated online, using independent test data, as shown in FIGS. 37A-37D.
- the test data in this example included thirteen flowlines, with nominal flows ranging from 0.6kg/s to 3 kg/s, in steps of 0.25kg/s, with GVF steps of 2%, giving a total of 266 experimental points, an average of 20 points per flowline.
- FIGS. 38-68 are graphs illustrating test and/or modeling results of various implementations described above with respect to FIGS. 1-37, or related implementations. More specifically, FIGS. 38-68, unless stated otherwise below, are graphs reflecting results from three-phase trials in which the fluids used were crude oil with a 35° API gravity, simulated brine (i.e., salt-water mixture) with 2% by weight NaCl, and nitrogen. The tests were conducted at a pressure of approximately 150 psig and temperature of 100° F.
- FIGS. 38 A and 38B illustrate gas-induced enor resulting from the raw density and mass flow measurements, respectively, of the Coriolis meter.
- FIG. 39 illustrates the observed response of the water cut probe used in these trials. For this particular device, the presence of free gas reduces the observed water cut compared to the true value (for the gas-free oil-water mixture), decreasing monotonically as gas void increases.
- the response also may be a function of the total mass rate and the intrinsic water cut of the liquid phase, among other factors. For a given gas void fraction (GVF) level, the observed water cut generally decreases as total mass rate and intrinsic water cut increases.
- the water cut response surface also may be affected by parameters such as, for example, fluid properties and flow regime.
- FIGS. 40A-40C illustrate residual e ⁇ ors for a bulk mixture mass flow and density, and water cut measurements, after a neural-net based modeling has been completed, based on the data sets shown in FIGS. 38A, 38B, and 39, with water cuts ranging from 0 to 50%.
- FIG. 41 illustrates how these results are mapped into the conesponding volumetric flow enors for the oil, water, and gas streams. Note that for both the gas and water volumes, low absolute volumetric flow (for water at low water cuts, and gas at low GVFs) may lead to large percentage e ⁇ ors as a proportion of the reading. As the oil flow rate may be significant in these trials, the e ⁇ ors in percentage terms remain mostly within 5% FIGS.
- FIGS. 42-47 are graphs demonstrating techniques for extending mass flow calculations to generate volumetric oil, water and gas readings.
- FIGS. 42-47 also demonstrate how e ⁇ ors in water cut reading may impact on the oil, water and gas volumetric measurements.
- massflow and density enor co ⁇ ections are based on the above- described oil data, with 6%> water-cut and a reference water cut value of 5.5%. Since the graphs themselves also are based on this data set, the mass flow and density e ⁇ or predictions are relatively small, which is not necessarily pertinent to the demonstration of how water cut accuracy affects volumetric measurements.
- the Coriolis principle and relate techniques, as described above, provide estimates for an overall mass flow and density of the three-phase, mixed fluid.
- FIGS. 42-47 final calculations are illustrated, in which, given the fluid-only mass flow rate and the water cut, the volumetric flowrates of the oil and gas components are obtained, while the GVF yields the gas volumetric flowrate.
- FIGS. 42-44 illustrate the calculations of volumetric water, oil, and gas flow rates, respectively, assuming the water cut is known perfectly.
- FIG 45 illustrates the water volumetric e ⁇ or with a +1% water cut absolute encr.
- the large mean enor is about 16%.
- an e ⁇ or of 1% absolute in the water cut estimate may result in approximately 16% over-estimate of the water volumetric flowrate.
- FIG. 46 illustrates that conesponding enors for oil volumetric flow are much smaller, reflecting the smaller impact the 1% water cut enor has on the 94% oil cut measurement.
- FIG 47 illustrates the impact of the water cut enor on the gas volume measurement.
- FIGS. 49-50 are graphs illustrating a conection of reading from a water-cut meter (i.e., the Phase Dynamics water cut meter) for gas-induced e ⁇ ors.
- the data for FIGS. 48-50 is based on the oil data described above, with nominal water-cut values of 0.0, 5.5, 13.1, 24.8, 35.6 and 50.0%. Although an actual water cut output is cutoff is generally zero, raw frequency data and characteristic equations associated with operations of the water cut meter allow for extended water cut readings which fall below zero%, as shown.
- the water-cut meter has an e ⁇ or even at 0%> GVF, due to the presence of residual amounts of gas 'carry-under' from the process, as follows (in absolute water-cut units) with respect to the specified test results refened to above:
- FIGS. 48 and 49 a neural net, along the lines described above, was built with inputs of: raw water cut reading, true mass flow reading, and true void fraction.
- the outputs include water cut enor (in absolute units of water cut - in this case percentage). Accordingly, successive calculations between this neural network and mass flow/density conections, as described above, lead to a converged overall solution.
- the water-cut meter reading may be co ⁇ ected from e ⁇ ors as large as —40% to mainly within 2 percent absolute e ⁇ or, as shown in FIG. 48, which, as referenced above with respect to FIGS. 42-47, may impact the water and oil co ⁇ ections for the Coriolis meter.
- FIG. 48 which, as referenced above with respect to FIGS. 42-47, may impact the water and oil co ⁇ ections for the Coriolis meter.
- FIG. 50-54 are graphs illustrating successive co ⁇ ection of liquids and gas massflow and using the water-cut co ⁇ ection, as generally described above with respect to FIG. 27. In FIGS.
- FIGS. 50A and 50B illustrate raw mixture density and massflow enors, respectively.
- FIGS. 51A-51C illustrate raw e ⁇ ors for the water, oil, and gas massflows, respectively.
- FIG. 52 illustrates convergence after two repetitions of FIG. 27, with the water-cut measurement co ⁇ ected within 3%, the mixture density mainly within 1% 0 and massflow mainly within 2%>.
- FIGS. 53A-53C illustrate the co ⁇ ected water-cut behavior during the process. Water, oil, and gas co ⁇ ection accuracies are illustrated in FIGS. 54A-54C, respectively.
- the oil massflow is conected to within 3%.
- FIGS. 54A-54C the water massflow is most affected, with 2-3%o enor in water-cut yielding +/- 40% e ⁇ or in water massflow.
- FIGS. 55-63 are graphs illustrating a "3-dimensional" conection for liquid massflow and density, which takes into account variations in the enor due to variations in the water-cut measurement(s). This technique may be used to obtain acceptable enors over a wider range of water cuts (as opposed to the above examples, in which flow data reported on is generally limited to about 6%> water cut).
- FIGS. 55-63 illustrate the use of a true water-cut reading as an extra input parameter, alongside apparent drop in mixture density and apparent massflow.
- the data is based on the oil data discussed above, but with nominal water-cut values of 0, 5.5, 13.1, 24.8, 35.6 and 49%.
- FIGS. 55A and 55B illustrate raw fluid mixture density and massflow e ⁇ ors, respectively.
- FIGS. 56-61 illustrate residual fluid mixture massflow e ⁇ ors after the previously used "6%> water cut" model is applied. It is apparent that while some of the enors (especially for the 6%> water cut data itself, FIG.
- FIGS. 64-68 are graphs illustrating results from embedding the three-dimensional liquid massflow and density co ⁇ ection of FIGS. 55-63 into the process described above with respect to FIGS. 50 and 54 and FIG. 27. By successive generations of the water-cut, density and massflow co ⁇ ections, volumetric e ⁇ ors resulting in the use of this model and the water cut e ⁇ or model may be shown.
- FIGS. 64-68 illustrate results of successive co ⁇ ections of water-cut, liquid(s), and gas massflow co ⁇ ection using the density and massflow co ⁇ ections that take into account the variations due to water-cut.
- the end results are calculations of volumetric flows for oil, water and gas, as may be used by, for example, the oil and gas industry. These illustrated calculations represent a "complete" set, suitable for oil continuous applications.
- the data is based on the oil data as described above, with nominal water-cut values of 0, 5.5, 13.1, 24.8, 35.6 and 49%.
- the water-cut, massflow and density co ⁇ ections used are based on the whole data set for the range of water-cut from 0 to 50%>.
- FIG. 39 illustrates the raw gas-induced water-cut meter enors.
- FIGS. 64A, 64B, 65A, 65B, and 65C give the raw mixture density and massflow gas-induced e ⁇ or, and raw water, oil and gas enor, respectively.
- FIG. 67A-67C illustrates an example of the co ⁇ ected water-cut behavior during the process(es).
- a massflow meter may be capable of maintaining operation in the presence of a high percentage of gas in a measured flow, both with a single or a mixed liquid (i.e., in two-phase or three-phase flow).
- Estimates and/or apparent measurements of the liquid-gas mixture density and massflow may thus be obtained.
- these estimates have enors that depend on various factors, including, for example, the gas void fraction and/or the true liquid massflow, which may be so large as to render the raw measurements useless.
- an additional measurement parameter such as, for example, a water cut or gas void fraction measurement, along with the apparent mass flow rate and density measurements, co ⁇ ected values for all of these parameters, and others, may be obtained.
- by cycling through these measurements and calculations with ever-improved conections successively improved values may be obtained, as, for example, the conections converge to specific values.
- techniques for performing these co ⁇ ections may be based on data- fitting techniques that seek to determine, for example, existing e ⁇ or rates in a particular setting or configuration, so that these e ⁇ ors may be accounted for in future measurements and conections. As such, these techniques may be dependent on an extent of a co ⁇ elation between the settings/configurations in which the data was obtained, and the settings/configurations in which they are ultimately applied.
- Related or other co ⁇ ection techniques may be used that seek to characterize fluid flow(s) in a more general sense, i.e., using fluid flow equations that seek to describe a behavior of the flow as a physical matter. For example, the well-known Navier-Stokes equations may be used in this sense.
- the three-dimensional unsteady form of the Navier-Stokes equations describe how the velocity, pressure, temperature, and density of a moving fluid are related.
- the equations are a set of coupled differential equations and may, in theory, be solved for a given flow problem by using methods from calculus, or may be solved analytically, perhaps using certain simplifications or adjustments that may be determined to be helpful and applicable in a given circumstance.
Abstract
Description
Claims
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CN200580012694XA CN1946990B (en) | 2004-03-03 | 2005-03-03 | Multi-phase coriolis flowmeter |
RU2006134705/28A RU2406977C2 (en) | 2004-03-03 | 2005-03-03 | Coriolis multi-phase flow metre |
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US11/069,931 US7188534B2 (en) | 2003-02-10 | 2005-03-02 | Multi-phase coriolis flowmeter |
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-
2005
- 2005-03-02 US US11/069,931 patent/US7188534B2/en not_active Expired - Lifetime
- 2005-03-03 WO PCT/US2005/006623 patent/WO2005093381A1/en active Application Filing
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US20110016988A1 (en) | 2011-01-27 |
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US7698954B2 (en) | 2010-04-20 |
US8117921B2 (en) | 2012-02-21 |
CN1946990A (en) | 2007-04-11 |
BRPI0508447A (en) | 2007-07-24 |
US7188534B2 (en) | 2007-03-13 |
US20080034892A1 (en) | 2008-02-14 |
CN1946990B (en) | 2010-05-26 |
US20050193832A1 (en) | 2005-09-08 |
RU2406977C2 (en) | 2010-12-20 |
RU2006134705A (en) | 2008-04-10 |
BRPI0508447B1 (en) | 2018-01-02 |
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