CN113405616A - Multiphase flow fluid measurement system based on riser differential pressure - Google Patents

Multiphase flow fluid measurement system based on riser differential pressure Download PDF

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CN113405616A
CN113405616A CN202110668659.4A CN202110668659A CN113405616A CN 113405616 A CN113405616 A CN 113405616A CN 202110668659 A CN202110668659 A CN 202110668659A CN 113405616 A CN113405616 A CN 113405616A
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module
differential pressure
flow
phase
densimeter
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CN113405616B (en
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张茂懋
薛皓白
伍国柱
万昌智
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Shenzhen Leengstar Technology Co ltd
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Shenzhen Leengstar Technology Co ltd
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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
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01F—MEASURING VOLUME, VOLUME FLOW, MASS FLOW OR LIQUID LEVEL; METERING BY VOLUME
    • G01F1/00—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow
    • G01F1/05—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow by using mechanical effects
    • G01F1/34—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow by using mechanical effects by measuring pressure or differential pressure
    • G01F1/36—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow by using mechanical effects by measuring pressure or differential pressure the pressure or differential pressure being created by the use of flow constriction
    • G01F1/40—Details of construction of the flow constriction devices
    • G01F1/44—Venturi tubes
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01F—MEASURING VOLUME, VOLUME FLOW, MASS FLOW OR LIQUID LEVEL; METERING BY VOLUME
    • 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
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N22/00—Investigating or analysing materials by the use of microwaves or radio waves, i.e. electromagnetic waves with a wavelength of one millimetre or more
    • G01N22/04—Investigating moisture content
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N9/00—Investigating density or specific gravity of materials; Analysing materials by determining density or specific gravity
    • G01N9/26—Investigating density or specific gravity of materials; Analysing materials by determining density or specific gravity by measuring pressure differences

Abstract

The application belongs to the technical field of flow measurement, and particularly relates to a multiphase flow fluid measurement system based on riser differential pressure. The existing oil-gas-water three-phase flow meter has certain harmfulness to the environment and human bodies, and the later cost is higher. The application provides a multiphase flow fluid measuring system based on riser differential pressure, which comprises a flowmeter module, a densimeter module and a data acquisition and processing module, wherein the flowmeter module is connected with the densimeter module, the flowmeter module is in data communication with the data acquisition and processing module, and the densimeter module is in data communication with the data acquisition and processing module; the flow meter module is used for measuring the virtual high flow of the fluid; the densimeter module is used for measuring the mixed density and the volume liquid content of the fluid; and the data acquisition and processing module is used for acquiring data and then calculating to obtain the flow of each phase. Mutual coupling between errors is avoided, and detection precision is improved.

Description

Multiphase flow fluid measurement system based on riser differential pressure
Technical Field
The application belongs to the technical field of flow measurement, and particularly relates to a multiphase flow fluid measurement system based on riser differential pressure.
Background
The petroleum and the natural gas are used as important strategic resources for supporting the nation and people, and the exploration, the exploitation, the transportation, the processing and other technical processes all relate to the measurement problem of multiphase flow, so that the method has very important significance for accurately measuring the multiphase flow.
At present, a multiphase flow measurement method commonly used in oil fields mostly adopts a test well separator to carry out oil-gas-water three-phase separation, and then single-phase instruments are used for carrying out measurement respectively. Although this mode can ensure a certain accuracy, since the separator is generally large in size and expensive, and the separation process is time-consuming, this method cannot realize real-time online measurement of each well. In addition, as most onshore oil fields are exploited to enter a stable production period, people throw more eyes to the ocean. The offshore platform with the small size of earth puts higher requirements on the size of the multiphase flowmeter.
The existing oil-gas-water three-phase flow meter adopts a combination form of a venturi tube and a gamma densimeter. The gamma densitometer utilizes the characteristic that the attenuation rates of gamma rays in media with different densities are different to estimate the mixed density of the fluid, and the technical scheme has the defects that: the radioactive source has certain harm to the environment and human body, and the production and the use of the radioactive source are mostly approved by a supervision department, so the later cost is higher.
Disclosure of Invention
1. Technical problem to be solved
The flowmeter is based on an existing oil-gas-water three-phase flowmeter adopting a combination form of a venturi tube and a gamma densimeter. The gamma densitometer utilizes the characteristic that the attenuation rates of gamma rays in media with different densities are different to estimate the mixed density of the fluid, and the technical scheme has the defects that: the radioactive source has certain harm to the environment and human body, and the production and the use of the radioactive source are mostly approved by a supervision department, so the later cost is higher. In view of the above, the present application provides a multiphase flow fluid measurement system based on riser differential pressure.
2. Technical scheme
In order to achieve the above object, the present application provides a multiphase flow fluid measurement system based on riser differential pressure, including a flowmeter module, a densimeter module and a data acquisition and processing module, wherein the flowmeter module is connected to the densimeter module, the flowmeter module is in data communication with the data acquisition and processing module, and the densimeter module is in data communication with the data acquisition and processing module; the flow meter module is used for measuring the virtual high flow of the fluid; the densimeter module is used for measuring the mixed density and the volume liquid content of the fluid; and the data acquisition and processing module is used for acquiring data and then calculating to obtain the flow of each phase.
Another embodiment provided by the present application is: the flowmeter module is differential pressure formula flowmeter module, differential pressure formula flowmeter module includes venturi, be provided with differential pressure sensor, pressure sensor and temperature sensor on the venturi, differential pressure sensor with data acquisition processing module connects, temperature sensor with data acquisition processing module connects.
Another embodiment provided by the present application is: venturi is including the upper reaches pipeline, contraction section, throat, expansion section and the low reaches pipeline that connect gradually, differential pressure sensor set up in the contraction section entrance with between the throat, pressure sensor set up in the upper reaches pipeline, temperature sensor set up in the low reaches pipeline.
Another embodiment provided by the present application is: the device also comprises a water content module, wherein the water content module is used for measuring the volume water content WVF or the WLR of the water content in the liquid, the average value of the microwave phase is utilized when the volume water content WVF is measured, and the maximum value of the microwave phase is utilized when the WLR of the water content in the liquid is measured; the moisture content module comprises a plurality of microwave sensors, and the directions and the angles of the spatial positions of the microwave sensors are different.
Another embodiment provided by the present application is: the microwave sensor comprises a transmission line, a sealing ring and an insulating medium, wherein the transmission line is arranged in the sealing ring, the sealing ring is arranged in the insulating medium, and the insulating medium is arranged in the pipe body.
Another embodiment provided by the present application is: the transmission lines are arranged at intervals or in a staggered manner.
Another embodiment provided by the present application is: the densimeter module is a vertical pipe differential densimeter module, the vertical pipe differential densimeter module comprises a vertical pipe, a vertical pipe differential pressure sensor is arranged on the vertical pipe, and the vertical pipe differential pressure sensor is used for obtaining the gravity pressure drop and the friction pressure drop generated when three-phase fluid flows through the vertical pipe.
Another embodiment provided by the present application is: the liquid collector is of a cyclone separator structure or a blind T-shaped flow mixer structure.
Another embodiment provided by the present application is: the densimeter module, the flowmeter module, the liquid collector and the moisture content module are connected in sequence.
Another embodiment provided by the present application is: the flow calculation device further comprises a display module, wherein the display module is connected with the data acquisition and processing module and is used for displaying and outputting the flow calculation result of the data acquisition and processing module.
3. Advantageous effects
Compared with the prior art, the multiphase flow fluid measurement system based on the riser differential pressure has the beneficial effects that:
the multiphase flow fluid measuring system based on the riser differential pressure can be used for measuring respective flow rates of oil, gas and water in a common oil production well and a gas production well, and can also be used for measuring gas and liquid two-phase flow rates in a high gas content gas production well by omitting a microwave water content module.
The application provides a heterogeneous class fluid measurement system based on riser differential pressure, through venturi differential pressure signal, riser differential pressure signal and the microwave amplitude phase signal that simple structure, low price differential pressure flowmeter module, riser differential pressure densimeter module and microwave moisture content module gathered to calculate through data processing module and obtain the gas phase of oil gas water three-phase flow and empty high flow QtpThe three-phase flow detection system is a non-separation non-radiation three-phase flow detection system, and compared with the existing separation type detection technology, the three-phase flow detection system has the advantages of real-time online detection, accurate detection result and high detection efficiency; compare the combination form of current venturi + gamma densimeter, this application has nonradioactive, can not cause harm to environment and human body, and the advantage that the approval procedure is simple.
The multiphase flow fluid measurement system based on the riser differential pressure utilizes the characteristics that the density of gas is far lower than that of oil and water, and the dielectric constant of water is far higher than that of gas and oil, so that key parameters such as the volume liquid content LVF, the volume water content WVF (or the water content WLR in liquid) and the like are directly obtained as far as possible, mutual coupling between errors is avoided, and the detection precision is improved.
The application provides a multiphase flow fluid measurement system based on riser differential pressure, differential pressure formula flowmeter module, riser differential pressure densimeter module, data acquisition processing module and display module all can be replaced by the existing equipment in scene comparatively easily, and moisture content data also can be got by the on-the-spot chemical examination simultaneously, consequently the oil gas water three-phase flowmeter that mentions in this application can reequip into virtual flowmeter comparatively easily to reduce hardware cost and installation cost.
The application provides a multiphase flow fluid measurement system based on riser differential pressure, the flow mixer can be with the sufficient misce bene of oil gas water three-phase flow to convert complicated multiphase flow into simple homogeneous phase flow, also can convert oil gas water three-phase flow into oil water two-phase flow through the liquid trap module and handle, thereby improve equipment's suitability.
Drawings
FIG. 1 is a schematic structural diagram of an oil-gas-water three-phase flow real-time online detection system according to the present application;
FIG. 2 is a schematic diagram illustrating the operation principle of the oil-gas-water three-phase flow real-time online detection system of the present application;
FIG. 3 is a schematic diagram of a sensor spatial position of the microwave moisture content module of the present application;
FIG. 4 is a schematic view of a sensor mounting angle of the microwave moisture content module of the present application;
FIG. 5 is a schematic diagram of the working principle of the microwave moisture content module of the present application;
FIG. 6 shows a gas phase virtual height coefficient phi of the differential pressure flowmeter module of the present applicationgA schematic diagram of the fitting effect;
FIG. 7 is a schematic illustration of the volumetric liquid fraction LVF of a riser differential pressure densitometer module of the present application with a net effect;
FIG. 8 is a schematic diagram illustrating the gas-liquid flow prediction effect of the oil-gas-water three-phase flow real-time online detection system of the present application;
FIG. 9 is a schematic diagram illustrating the fitting effect of the microwave water cut module of the present application on the volumetric water cut WVF;
FIG. 10 is a schematic diagram illustrating the water and oil flow prediction effect of the oil-gas-water three-phase flow real-time online detection system of the present application;
FIG. 11 is a schematic structural diagram of a virtual three-phase flow real-time on-line detection system according to the present application;
FIG. 12 is a schematic structural diagram of a liquid-collecting three-phase flow real-time online detection system according to the present application;
FIG. 13 is a schematic diagram illustrating a WLR fitting effect of the moisture content in liquid of the microwave moisture content module of the present application;
fig. 14 is a schematic diagram of the water and oil flow prediction effect of the liquid-collecting three-phase flow real-time online detection system of the present application.
Detailed Description
Hereinafter, specific embodiments of the present application will be described in detail with reference to the accompanying drawings, and it will be apparent to those skilled in the art from this detailed description that the present application can be practiced. Features from different embodiments may be combined to yield new embodiments, or certain features may be substituted for certain embodiments to yield yet further preferred embodiments, without departing from the principles of the present application.
In the description of the present application, it is to be understood that the terms "center", "upper", "lower", "front", "rear", "left", "right", "vertical", "horizontal", "top", "bottom", "inner", "outer", and the like indicate orientations or positional relationships based on those shown in the drawings, and are only for convenience in describing the present application and simplifying the description, but do not indicate or imply that the referred device or element must have a particular orientation, be constructed in a particular orientation, and be operated, and thus should not be construed as limiting the present application.
In the description of the present application, it is to be noted that, unless otherwise explicitly specified or limited, the terms "mounted," "connected," and "connected" are to be construed broadly, e.g., as meaning either a fixed connection, a removable connection, or an integral connection; the specific meaning of the above terms in the present application can be understood in a specific case by those of ordinary skill in the art.
The terms "first", "second" and "first" are used for descriptive purposes only and are not to be construed as indicating or implying relative importance or implicitly indicating the number of technical features indicated. Thus, a feature defined as "first" or "second" may explicitly or implicitly include one or more of that feature. In the description of the present application, "a plurality" means two or more unless otherwise specified.
Referring to fig. 1 to 14, the present application provides a multiphase flow fluid measurement system based on a riser differential pressure, including a flowmeter module, a densimeter module and a data acquisition and processing module, wherein the flowmeter module is connected with the densimeter module, the flowmeter module is in data communication with the data acquisition and processing module, and the densimeter module is in data communication with the data acquisition and processing module; the flow meter module is used for measuring the virtual high flow of the fluid; the densimeter module is used for measuring the mixed density and the volume liquid content of the fluid; and the data acquisition and processing module is used for acquiring data and then calculating to obtain the flow of each phase.
The detection system measures the virtual high flow Q _ tp of the three-phase flow through the differential pressure type flowmeter module, the vertical pipe differential pressure densimeter module measures the volume liquid content LVF, and finally the volume liquid content LVF is analyzed and processed through the data acquisition and processing module and is output and displayed through the display module, so that the real-time online measurement of the oil-gas-water three-phase flow is realized. Meanwhile, the detection system is in modular design for the sensor, the position of the sensor can be conveniently adjusted according to different metering requirements, the design similar to a virtual flowmeter can be adopted by combining the existing sensor, and a quick, stable and reliable metering detection result can be provided for oil wells under different working conditions. And measuring the gas-liquid two-phase flow in the high gas-containing gas production well.
The water content meter also can comprise a flowmeter module, a densimeter module, a water content module and a data acquisition and processing module, wherein the flowmeter module is connected with the data acquisition and processing module; the flow meter module is used for measuring the virtual high flow of the fluid; the densimeter module is used for measuring the volume liquid content; the water content module is used for measuring the volume water content WVF or the liquid water content WLR; and the data acquisition and processing module is used for acquiring data and then calculating to obtain the flow of each phase. The detection system measures the virtual high flow Q of the three-phase flow through the differential pressure type flowmeter moduletpThe vertical pipe differential pressure densimeter module measures the volume liquid content rate LVF, the water content module measures the volume water content rate WVF or the water content rate WLR in the liquid, and finally the data acquisition and processing module analyzes and processes the volume water content rate and the water content rate WLR in the liquid, and the display module outputs and displays the volume water content rate and the water content rate, so that the real-time online measurement of the oil-gas-water three-phase flow is realized. Meanwhile, the detection system is in modular design for the sensor, the position of the sensor can be conveniently adjusted according to different metering requirements, the design similar to a virtual flowmeter can be adopted by combining the existing sensor, and a quick, stable and reliable metering detection result can be provided for oil wells under different working conditions. For realizing three-phase flow of oil, gas and water in general oil well and gas wellAnd (4) real-time online measurement.
Further, the flowmeter module is differential pressure type flowmeter module 1, differential pressure type flowmeter module 1 includes venturi, be provided with differential pressure sensor 5, pressure sensor 6 and temperature sensor 7 on the venturi, differential pressure sensor 5 with data acquisition processing module connects, pressure sensor 6 with data acquisition processing module connects, temperature sensor 7 with data acquisition processing module connects. The data acquisition and processing module can calculate the gas density of the working condition according to the pressure and temperature signals acquired by the differential pressure type flowmeter module and the components of the gas phase in the oil-gas-water three-phase flow. Meanwhile, the data acquisition and processing module can also receive a differential pressure signal dp output by the differential pressure type flowmeter moduletpAnd establishing a differential pressure signal dp by combining a multiphase flow empirical modeltpFunctional corresponding relation with gas and liquid two-phase flow and gas phase virtual high coefficient phigAnd the corresponding relation between the Lockhart-Martinelli parameter X.
Further, venturi is including the upper reaches pipeline, contraction section, throat, expansion section and the low reaches pipeline that connect gradually, differential pressure sensor set up in the contraction section entrance with between the throat, pressure sensor set up in the upper reaches pipeline, temperature sensor set up in the low reaches pipeline.
Further, still include the moisture content module, the moisture content module is microwave moisture content module 2, microwave moisture content module 2 includes a plurality of microwave sensors, every microwave sensor spatial position direction and angle are different. The microwave water content module can be arranged in an oil-gas-water three-phase flow main trunk, and the volume water content is measured by using the average values of microwave amplitude and phase positions WVF; the device can also be combined with a mixer, a liquid collector and the like, is arranged at a liquid phase accumulation place, and is combined with the maximum values of the microwave amplitude and the phase to measure the water content WLR in the liquid. WVF and WLR satisfy the following functional relationship: WVF, LVF WLR, they can be converted to each other by LVF calculated by the riser differential pressure. The water content module is used for measuring the volume water content WVF or the water content WLR in the liquid, the average value of the microwave phase is utilized when the volume water content WVF is measured, the maximum value of the microwave phase is utilized when the water content WLR in the liquid is measured, and in addition, corresponding liquid collecting devices are generally arranged when the water content WLR in the liquid is measured.
Further, the microwave sensor comprises a transmission line, a sealing ring and an insulating medium, wherein the transmission line is arranged in the sealing ring, the sealing ring is arranged in the insulating medium, and the insulating medium is arranged in the tube body.
Referring to fig. 2, the oil-gas-water three-phase flow real-time online detection system provided by the embodiment of the application utilizes the characteristics that the density of gas is far lower than that of oil and water, and the dielectric constant of water is far higher than that of the gas and the oil, and directly obtains key parameters such as the volume liquid content LVF and the volume water content WVF (or the water content WLR in liquid) as far as possible, thereby avoiding mutual coupling between errors,
referring to fig. 3, there are various possible implementations of the microwave moisture-content module 2, and in some embodiments, the microwave moisture-content module 2 employs two microwave transmission lines spaced apart by a certain distance and perpendicular to each other, so as to ensure that the measured volumetric moisture content WVF has spatial representativeness. In other embodiments, referring to fig. 4, the microwave moisture-containing module 2 employs a plurality of microwave transmission lines arranged at intervals or staggered at a certain angle. Of course, other principles of devices may be used to measure WVF the volumetric water content of the three phase flow, thereby improving the applicability of the apparatus and not limiting the scope of the invention.
Referring to FIG. 2, the microwave water content module 2 uses the dielectric constant (. epsilon.) of waterw78) is much higher than oil (epsilon)o2.18), qi (epsilon)g1) to measure the volumetric water cut WVF in the three phase stream. Referring to fig. 5, the microwave sensor in the microwave moisture content module 2 is composed of a signal generator, a power divider, an amplitude and phase discriminator, a phase shift circuit, a microwave transmission line and an ARM processor. Microwave signals sent by the signal generator are divided into two paths by the power divider, wherein one path enters the amplitude and phase discriminator through the microwave transmission line, and the other path enters the amplitude and phase discriminator through the phase shifting circuit. Since the operating frequency f of the microwave signal is constant and the water dielectricThe constant is much larger than that of oil and gas, so the wavelength lambda of the microwave passing through the transmission line can be changed as follows:
Figure BDA0003117944540000061
where ε is the dielectric constant of the medium, λ is the microwave wavelength, f is the operating frequency, and c is the speed of light. The microwave wavelength passing through the phase shift circuit cannot be changed, so that the amplitude phase discriminator compares the difference between the amplitude and the phase of two paths of microwave signals, and the volume water content WVF in the three-phase flow is calculated by the ARM processor.
The volumetric water cut WVF in the three phase stream is defined as:
Figure BDA0003117944540000062
in the formula, Qw、Qo、QgRespectively representing the respective volume flow of water, oil and gas. WVF can be obtained by phase fitting of the microwave sensor, and the fitting effect is shown in fig. 9, where the left graph represents the corresponding relationship between the two sets of transmission line phases and the volumetric water content ratio WVF, and the right graph represents the predicted effect of the two sets of transmission line volumetric water content WVF.
Further, the transmission lines are arranged at intervals or staggered. The spatial position and the direction angle of each group of microwave sensors are different, so that the moisture content measured by the microwave moisture content module is representative. The transmission lines are kept at a certain distance to avoid electromagnetic interference.
The data acquisition processing module can receive the microwave amplitude and phase signals output by the microwave water content module 2, and establishes a function corresponding relation among the microwave amplitude, the phase signals and the water content by combining an empirical model between the microwave amplitude and the phase signals and a dielectric constant and a theoretical model between the dielectric constant and the water content.
Further, the densitometer module is a riser differential pressure densitometer module 3, the riser differential pressure densitometer module 3 comprises a riser, the riser is provided with a sensor, the sensor is connected with the sensorA riser differential pressure sensor 8 is provided, said riser differential pressure sensor 8 being used to obtain the gravitational and frictional pressure drops of the three phase fluid flowing through the length of riser. The data acquisition and processing module can receive a differential pressure signal dp output by the vertical pipe differential pressure densimeter module 1vertAnd combining a theoretical model or an empirical model between the mean value dp and the LVF to establish the average value dp of the differential pressure of the riservertAnd the volume liquid fraction (LVF). The data acquisition and processing module can obtain the riser differential pressure dp according to real-time measurementvertCalculating to obtain the volume liquid ratio LVF of the fluid, converting the volume liquid ratio LVF into a Lockhart-Martinelli parameter X, substituting the parameter X into a gas phase virtual height formula to obtain a gas phase virtual height coefficient phigThen, a differential pressure signal dp of the venturi tube is combinedrpAnd calculating to obtain the gas phase volume flow Q of the working conditiong. Then combining the volume liquid-containing rate LVF to calculate the liquid phase volume flow rate Ql. Finally, the water flow Q is calculated by combining the volume water content WVF or the liquid phase water content WLR measured by the microwave water content modulewAnd oil flow rate Qo。
The data acquisition and processing module can receive information acquired by the differential pressure type flowmeter module 1, the microwave water content module 2 and the vertical pipe differential pressure densimeter module 3, analyze and process the information to obtain the metering data of the oil-gas-water three-phase flow, and the display module can display the metering data of the oil-gas-water three-phase flow.
Referring to fig. 1, a differential pressure dp generated by a differential pressure type flow meter (e.g., a classical venturi tube) when a single phase fluid (e.g., pure gas) flows through a differential pressure type flow meter module 1gWith volume flow QgThe two are in direct proportion, and the corresponding relation between the two is shown as the following formula:
Figure BDA0003117944540000071
wherein A is the flow area of the Venturi throat, beta D/D is the ratio of the diameter of the Venturi throat to the diameter of the inlet, and CdIs the efflux coefficient, ε is the expansion coefficient, CdAnd ε can both be found by looking up a table. dpgDifferential pressure, p, generated by the flow of pure air through the venturigThe density of the gas phase can be calculated according to the national standards based on the measured pressure p and temperature T according to the composition of the natural gas.
When gas-liquid two-phase flow or oil-gas-water three-phase flow flows through the differential pressure type flowmeter module 1, differential pressure dp generated by the differential pressure type flowmeter (such as a classical venturi tube)tpFlow rate Q calculated according to equation (3)tpReferred to as gas phase pseudo-high flow, which is equal to the true gas phase flow QgIs ofgKnown as gas phase pseudo-height coefficient, i.e. phig＝Qtp/Qg. Gas phase virtual height coefficient phigAnd Lockhart-Martinelli parameter X (i.e. the ratio of dimensionless liquid to gas flow,
Figure BDA0003117944540000072
) There are the following correspondences between:
Figure BDA0003117944540000081
wherein S is ug/ulThe sliding speed ratio between gas and liquid phases can be calculated by an empirical correlation formula and can also be obtained by fitting experimental data. X is a Lockhart-Martinelli parameter, and the following corresponding relation exists between the parameter and the volume liquid content LVF:
Figure BDA0003117944540000082
high coefficient of deficiency phi in oil-gas-water three-phase flowgThe correspondence with the L-M parameter X can be seen in FIG. 6, from which it can be seen thatgAnd X have a monotonous and unique corresponding relation.
Referring to FIG. 1, when oil-gas-water three-phase flow flows through the riser differential pressure densitometer module 3, the riser differential pressure dp is based on the split-phase flow modelvertThe calculation can be theoretically made according to the following formula:
Figure BDA0003117944540000083
in the formula, L is the distance between two pressure taking ports of the vertical pipe differential pressure densimeter, D is the diameter of the vertical pipe, lambda is the friction coefficient between gas phase and pipe wall, ugsIs the conversion rate of the gas phase, i.e. ugs＝Qg/AD，AD＝πD2/4，ρgThe density of the gas phase can be calculated according to the national standards based on the measured pressure p and temperature T according to the composition of the natural gas.
The first term on the right side of the equal sign in equation (6) is the gravity pressure drop and the second term is the friction pressure drop. Wherein the gas phase virtual high coefficient of friction pressure drop phigThe calculation can be performed according to the formula (4), and the gas phase imaginary high coefficient of the gravity pressure drop needs to be calculated according to the following formula:
Figure BDA0003117944540000084
wherein S is ug/ulThe sliding speed ratio between gas and liquid phases can be obtained through empirical correlation calculation or fitting experimental data. In particular, if S ═ 1, equation (6) can be written as:
Figure BDA0003117944540000085
theoretical analysis shows that if the sliding speed ratio S is increased, dp isvertIt will increase significantly on the basis of equation (8).
Riser differential pressure dp in oil-gas-water three-phase flowvertThe relationship between LVF and LVF is shown in FIG. 7, where dp is observed for oil and water continuous phasesvertAnd LVF. This is probably because the liquid phase in the oil-gas-water three-phase flow gradually transits from the oil continuous phase of "water-in-oil" to the water continuous phase of "oil-in-water" with the increase of the water content WLR in the liquid, and the equivalent viscosity thereof is also obviously reduced, thereby leading to the slip ratio between gas and liquidS increases and rises, eventually resulting in a riser differential pressure dpvertAnd is increased. Therefore, in the practical application process, the measurement data can be divided into two types, namely oil continuous phase and water continuous phase according to the water content WLR in the liquid, then the data of each type are fitted respectively, the blue line and the red line in the figure 7 are referred, and finally the corresponding volume liquid content LVF is calculated respectively.
Referring to FIG. 1, the data acquisition and processing module can be based on the riser differential pressure dp measured by the riser differential pressure densitometer module 3vertThe volume liquid content LVF of the oil-gas-water three-phase flow is obtained by combining the formula (6), converted into a Lockhart-Martinelli parameter X and substituted into a Venturi tube gas phase virtual height formula (4) to obtain a gas phase virtual height coefficient phigThen, a differential pressure signal dp of the venturi tube is combinedtpAnd calculating to obtain the gas phase volume flow Q of the working conditiong＝Qtp/φg. Finally, the liquid phase volume flow is calculated by combining the volume liquid content LVF or X
Figure BDA0003117944540000091
The prediction effect of the gas-liquid two-phase flow under the oil-gas-water three-phase flow working condition can be referred to fig. 8, wherein a red dotted line represents an error band of +/-10%, a black dotted line represents an error band of +/-20%, and a black solid line represents a standard value. By summing the gas-liquid two-phase flows: qtot＝Qg+QlAnd by combining the predicted value of the volume water content WVF and the predicted value LVF of the volume liquid content, the predicted effect of the water-oil two-phase flow can be calculated as shown in FIG. 10, wherein the red dotted line in the graph represents a plus or minus 10% error band, the black dotted line represents a plus or minus 20% error band, and the black solid line represents a standard value.
Further, the liquid collector 9 and the flow mixer 4 are also included, and the liquid collector 9 is of a cyclone separator structure or a blind T-shaped flow mixer structure or other common structures facilitating liquid collection.
Further, the densimeter module, the flowmeter module, the liquid collector 9 and the moisture content module are connected in sequence. But the relative position and spatial arrangement between each module can be adjusted according to the requirements of users, and the existing structures and sensors on the site can be fully utilized, even the flow meter is virtualized, so that the hardware cost of the product is reduced.
Further, the data acquisition processing module can calculate key parameters such as volume liquid content, volume water content and water content in liquid according to the original signals acquired by the water content module and the densimeter module, and calculate respective flow rates of oil, gas and water phases by combining the original signals acquired by the flowmeter module; the flow calculation device also comprises a display module, wherein the display module is connected with the data acquisition processing module and is used for displaying and outputting the flow calculation result of the data acquisition processing module.
Examples
Referring to fig. 11, another embodiment of the present application provides an oil-gas-water three-phase flow virtual metering device based on existing sensors in an oilfield field, the meaning of the numbers in fig. 11 is the same as that in fig. 1, but the venturi tube in the differential pressure type flowmeter module 1 in the embodiment is replaced by the throttle member similar to a valve, the pressure sensor 6, the temperature sensor 7 and the riser differential pressure sensor 8 in the riser differential pressure flowmeter module 3, which are already in the field, and the data of the sensors are replaced as much as possible, so that the hardware cost and the installation cost of the field are reduced as much as possible. The data processing and collecting module and the display module can also be replaced by a microcomputer existing on the spot. By combining the data provided by the differential pressure type flowmeter module 1 and the vertical pipe differential pressure densimeter module 3, the respective flow rates of the gas phase and the liquid phase can be calculated by using field equipment, so that the method is used for measuring the working conditions of high gas content and high moisture content of the gas production well. If the WLR data of the water content can be provided on site, or the WLR is obtained by additionally installing the microwave water content module 2 for measurement, the respective flow rates of oil and water can be continuously calculated, and therefore the WLR data can be used for measuring the oil-gas-water three-phase flow of a common oil-gas well.
Referring to fig. 12, another embodiment of the present application provides a real-time online detection system for oil-gas-water three-phase flow with a liquid collector, where the numbering meaning in fig. 12 is basically the same as that in fig. 1, but the blind T-shaped flow mixer 4 in fig. 1 is replaced by a liquid collector 9 similar to a cyclone separator, so as to ensure that the gas fraction of the separated liquid path is low, and of course, devices of other principles can be used to reduce the volume gas fraction in the three-phase flow, so as to improve the applicability of the device, which is not limited herein. In addition, the microwave water content module 2 is placed in a liquid path of the liquid collector, so that the microwave water content module 2 can directly establish a functional relation between the microwave water content module and the WLR (water content in liquid) by utilizing the microwave amplitude and the maximum value of the phase signal. The water content in the liquid is defined as:
Figure BDA0003117944540000101
because the dielectric constant of the gas phase is the minimum in three phases of oil, gas and water, the influence of residual gas on the WLR fitting of the water content in the liquid can be avoided as much as possible by using the maximum values of microwave amplitude and phase signals. In other embodiments, referring to fig. 1, the microwave water cut module 2 is disposed at the blind end of the blind T-shaped mixer 4, where the gas void is also low, so that the microwave water cut module 2 can also directly establish a functional relationship between the microwave water cut module and the liquid water cut WLR by using the maximum value of the microwave amplitude and phase signals. Of course, the microwave water cut module 2 may also be disposed at other places with low gas void, so as to improve the applicability of the device, which is not limited herein.
According to different water content WLR in liquid, the oil-water two-phase flow can be divided into two different flow states of water-in-oil and oil-in-water. WLR and mixed dielectric constant epsilon of water content in liquid under different flow statesmixThe correspondence between them also differs, in that in the oil continuous phase ("water-in-oil"):
Figure BDA0003117944540000102
and in the water continuous phase ("oil-in-water"):
Figure BDA0003117944540000103
therefore, the water content WLR in the liquid is mostly measured by adopting a method of sectional calibration and fitting, and the actual fitting effect refers to fig. 13, wherein the left graph represents the corresponding relation between the maximum value of the phases of the two groups of transmission lines and the water content WLR in the liquid, and the right graph represents the prediction effect of the water content WLR in the liquid of the two groups of transmission lines.
The gas-liquid flow prediction result of the oil-gas-water three-phase flow real-time online detection system (figure 12) with the liquid collector 9 is the same as the gas-liquid flow prediction result of the oil-gas-water three-phase flow real-time online detection system (figure 1), and the gas-liquid two-phase flow obtained by calculation is shown in figure 8. However, the WLR calculated by using the maximum value of the microwave phase after the combination of the collected liquid is used, and the calculated oil-water two-phase flow is shown in fig. 14, from which it can be seen that the measurement accuracy of the oil-water flow is greatly improved compared with fig. 10 calculated by using WVF.
Although the present application has been described above with reference to specific embodiments, those skilled in the art will recognize that many changes may be made in the configuration and details of the present application within the principles and scope of the present application. The scope of protection of the application is determined by the appended claims, and all changes that come within the meaning and range of equivalency of the technical features are intended to be embraced therein.

Claims (10)

1. A multiphase flow fluid measurement system based on riser differential pressure is characterized in that: the device comprises a flowmeter module, a densimeter module and a data acquisition and processing module, wherein the flowmeter module is connected with the densimeter module, the flowmeter module is in data communication with the data acquisition and processing module, and the densimeter module is in data communication with the data acquisition and processing module;
the flow meter module is used for measuring the virtual high flow of the fluid;
the densimeter module is used for measuring the mixed density and the volume liquid content of the fluid;
and the data acquisition and processing module is used for acquiring data and then calculating to obtain the flow of each phase.
2. The system of claim 1, wherein: the flowmeter module is differential pressure formula flowmeter module, differential pressure formula flowmeter module includes venturi, be provided with differential pressure sensor, pressure sensor and temperature sensor on the venturi, differential pressure sensor with data acquisition processing module connects, temperature sensor with data acquisition processing module connects.
3. The system of claim 2, wherein: venturi is including the upper reaches pipeline, contraction section, throat, expansion section and the low reaches pipeline that connect gradually, differential pressure sensor set up in the contraction section entrance with between the throat, pressure sensor set up in the upper reaches pipeline, temperature sensor set up in the low reaches pipeline.
4. The system of claim 1, wherein: the device also comprises a water content module, wherein the water content module is used for measuring the volume water content WVF or the WLR of the water content in the liquid, the average value of the microwave phase is utilized when the volume water content WVF is measured, and the maximum value of the microwave phase is utilized when the WLR of the water content in the liquid is measured; the moisture content module comprises a plurality of microwave sensors, and the directions and the angles of the spatial positions of the microwave sensors are different.
5. The system of claim 4, wherein: the microwave sensor comprises a transmission line, a sealing ring and an insulating medium, wherein the transmission line is arranged in the sealing ring, the sealing ring is arranged in the insulating medium, and the insulating medium is arranged in the pipe body.
6. The system of claim 5, wherein: the transmission lines are arranged at intervals or in a staggered manner.
7. The system of claim 1, wherein: the densimeter module is a vertical pipe differential densimeter module, the vertical pipe differential densimeter module comprises a vertical pipe, a vertical pipe differential pressure sensor is arranged on the vertical pipe, and the vertical pipe differential pressure sensor is used for obtaining the gravity pressure drop and the friction pressure drop generated when three-phase fluid flows through the vertical pipe.
8. The system of any one of claims 1 to 7, wherein: the liquid collector is of a cyclone separator structure or a blind T-shaped flow mixer structure.
9. The system of claim 8, wherein: the densimeter module, the flowmeter module, the liquid collector and the moisture content module are connected in sequence.
10. The system of claim 8, wherein: the flow calculation device further comprises a display module, wherein the display module is connected with the data acquisition and processing module and is used for displaying and outputting the flow calculation result of the data acquisition and processing module.
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JPH09311061A (en) * 1996-05-23 1997-12-02 Sekiyu Kodan Multiphase-flow flowmeter
CN101479575A (en) * 2006-05-05 2009-07-08 多相仪表公司 A method and apparatus for tomographic multiphase flow measurements
CN101509795A (en) * 2008-02-15 2009-08-19 天津瑞吉德科技有限公司 On-line instant measuring method and apparatus for oil-gas-water three phase flow quantity
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