CN120293241A - Oil and gas fluid metering device with replaceable throat diameter and metering method - Google Patents
Oil and gas fluid metering device with replaceable throat diameter and metering method Download PDFInfo
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- CN120293241A CN120293241A CN202510468977.4A CN202510468977A CN120293241A CN 120293241 A CN120293241 A CN 120293241A CN 202510468977 A CN202510468977 A CN 202510468977A CN 120293241 A CN120293241 A CN 120293241A
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01F—MEASURING VOLUME, VOLUME FLOW, MASS FLOW OR LIQUID LEVEL; METERING BY VOLUME
- G01F1/00—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow
- G01F1/05—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow by using mechanical effects
- G01F1/34—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow by using mechanical effects by measuring pressure or differential pressure
- G01F1/36—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow by using mechanical effects by measuring pressure or differential pressure the pressure or differential pressure being created by the use of flow constriction
- G01F1/40—Details of construction of the flow constriction devices
- G01F1/44—Venturi tubes
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01F—MEASURING VOLUME, VOLUME FLOW, MASS FLOW OR LIQUID LEVEL; METERING BY VOLUME
- 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
- G01F1/86—Indirect mass flowmeters, e.g. measuring volume flow and density, temperature or pressure
- G01F1/88—Indirect mass flowmeters, e.g. measuring volume flow and density, temperature or pressure with differential-pressure measurement to determine the volume flow
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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
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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
- G01F15/18—Supports or connecting means for meters
- G01F15/185—Connecting means, e.g. bypass conduits
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01H—MEASUREMENT OF MECHANICAL VIBRATIONS OR ULTRASONIC, SONIC OR INFRASONIC WAVES
- G01H5/00—Measuring propagation velocity of ultrasonic, sonic or infrasonic waves, e.g. of pressure waves
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- 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
- G01N9/24—Investigating density or specific gravity of materials; Analysing materials by determining density or specific gravity by observing the transmission of wave or particle radiation through the material
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Abstract
The invention provides an oil-gas fluid metering device with changeable throat diameter and a metering method, comprising a venturi tube, a disassembly nozzle, an acoustic velocity measuring mechanism and a density measuring mechanism, wherein the two ends of the venturi tube are provided with an upstream flange and a downstream flange which are used for connecting a pipeline to be tested, the disassembly nozzle is arranged in the middle of the venturi tube and used for controlling the flow of the oil-gas fluid, the acoustic velocity measuring mechanism is arranged at the downstream of the disassembly nozzle of the venturi tube and used for measuring the propagation velocity of the oil-gas fluid, and the density measuring mechanism is arranged at the upstream of the disassembly nozzle of the venturi tube and used for measuring the density of the oil-gas fluid. According to the oil gas fluid metering device and the metering method capable of changing the throat diameter, the throat diameter is changed under the condition that the whole venturi tube is not replaced by arranging the replaceable dismounting nozzle, the flow adaptation range is enlarged, and the problem that the flow adaptation range is narrow due to the fact that the throat size of the venturi tube is fixed in the prior art is solved.
Description
Technical Field
The invention relates to the technical field of multiphase fluid metering, in particular to an oil-gas fluid metering device with a changeable throat diameter. Meanwhile, the invention also relates to an oil-gas fluid metering method applied to the oil-gas fluid metering device with the changeable throat diameter.
Background
Gas-liquid two-phase flow is widely used in many industrial fields such as petroleum, chemical industry, nuclear energy and the like. Flow metering of two-phase fluids in systems where two-phase flow exists is generally difficult to avoid and a problem that has not been well addressed. The multiphase flow measurement method can be generally divided into 3 types according to whether separation is carried out or not, namely a complete separation method, a non-separation method and a split-flow phase separation method.
The complete separation method is to separate oil-gas fluid into single-phase gas and single-phase liquid with separating equipment and then to measure the oil-gas fluid with common single-phase flowmeter. Therefore, the two-phase flow measurement is converted into single-phase flow measurement, and the method has the advantages of reliable operation, high measurement accuracy, wide measurement range, no influence of the flow pattern change of the gas-liquid two-phase flow and the like. The biggest disadvantages of the complete separation method are that the separation equipment is bulky, expensive, and requires the establishment of specialized metering stations and test lines, which greatly increases the development costs of the flowmeter.
The method of no separation directly places the measuring instrument in two-phase fluid for measurement is the mainstream mode of multiphase metering in the current industrial field, and the method does not need to adopt a separation device, so the volume is small and the structure is compact. The total gas-liquid flow is usually measured by a throttling device such as venturi, and the phase fraction is measured by a gamma ray phase fraction sensor. In the current non-separation multiphase metering, the venturi tube has a narrow flow adaptation range due to the fixed throat size, and meanwhile, the gamma ray technology has a large radiation risk, so that the popularization and application difficulty is high.
Disclosure of Invention
Therefore, an objective of the present invention is to provide an oil-gas fluid metering device with changeable throat diameter, so as to solve the problems of narrow flow adaptation range caused by the fixed throat size of the venturi tube and high radiation risk caused by adopting gamma ray technology in the prior art.
In order to achieve one of the above purposes, the invention provides an oil-gas fluid metering device with changeable throat diameter, which adopts the following technical scheme:
an oil and gas fluid metering device of replaceable throat size, comprising:
The device comprises a pipeline to be tested, a venturi tube, a disassembly nozzle, an acoustic velocity measuring mechanism and a density measuring mechanism, wherein the two ends of the venturi tube are provided with an upstream flange and a downstream flange which are used for connecting the pipeline to be tested, the disassembly nozzle is arranged in the middle of the venturi tube and used for controlling the flow of the oil-gas fluid, the acoustic velocity measuring mechanism is arranged at the downstream of the disassembly nozzle of the venturi tube and used for measuring the propagation velocity of the oil-gas fluid, and the density measuring mechanism is arranged at the upstream of the disassembly nozzle of the venturi tube and used for measuring the density of the oil-gas fluid.
By adopting the technical scheme, the throat diameter is changed by changing the disassembly nozzle under the condition that the whole venturi tube is not replaced, so that the flow adaptation range is enlarged, the problem of narrow flow adaptation range caused by the fixed throat size of the venturi tube in the prior art is solved, and meanwhile, the sound velocity measuring mechanism and the density measuring mechanism are adopted to replace the gamma ray technology for measurement, so that radiation risks are avoided, and the safety is improved.
Further, the venturi tube sequentially comprises, from upstream to downstream:
The device comprises an inlet straight pipe section fixedly connected with the upstream flange, a density measuring mechanism communicated with the inlet straight pipe section, a convergent section, a throat, an acoustic velocity measuring mechanism, a divergent section, an outlet straight pipe section, a divergent section and a downstream flange, wherein one end of the convergent section is fixedly connected with the inlet straight pipe section, one end of the major diameter of the convergent section is in sealing connection with the dismantling nozzle, one end of the throat is in sealing connection with the dismantling nozzle, the acoustic velocity measuring mechanism is communicated with the throat, one end of the minor diameter of the divergent section is fixedly connected with the other end of the throat, and one end of the outlet straight pipe section is fixedly connected with one end of the major diameter of the divergent section, and the other end of the outlet straight pipe section is fixedly connected with the downstream flange.
By adopting the technical scheme, the structure of the Venturi tube is more reasonable, the flow characteristics of the oil-gas fluid can be better adapted, and the measurement accuracy is improved.
Further, the sound speed measuring mechanism includes:
The ultrasonic transmitting probe and the ultrasonic receiving probe are respectively arranged at the upstream and the downstream of the throat part and are used for measuring the sound velocity of oil-gas fluid, and the temperature sensor is arranged at the inlet straight pipe section and is matched with the ultrasonic transmitting probe and the ultrasonic receiving probe to respectively measure the gas phase sound velocity and the liquid phase sound velocity.
By adopting the technical scheme, the sound velocity of the oil-gas fluid can be accurately measured, accurate data support is provided for subsequent flow calculation, meanwhile, the temperature sensor can be set to consider the influence of temperature on the sound velocity, and the measurement accuracy is further improved.
Further, the density measurement mechanism includes:
The pressure sensor is arranged on the upstream pressure guiding pipe and used for measuring the pressure at the inlet straight pipe section.
By adopting the technical scheme, the density of the oil gas fluid can be accurately measured, and accurate data support is provided for subsequent flow calculation.
The venturi tube pressure difference measuring device further comprises a differential pressure sensor, wherein the differential pressure sensor is used for measuring the pressure difference of the venturi tube, the high pressure end of the differential pressure sensor is communicated with the upstream pressure guiding tube, the throat part is provided with a middle pressure guiding tube, and the low pressure end of the differential pressure sensor is communicated with the middle pressure guiding tube.
By adopting the technical scheme, the pressure difference of the venturi tube can be measured, important parameters are provided for flow calculation, and the accuracy of flow measurement is further improved.
Furthermore, the disassembly nozzle mainly comprises a throttle pipe and an expansion pipe, wherein the outlet of the throttle pipe is communicated with the inlet of the expansion pipe, the throttle pipe is arranged on the straight pipe section of the inlet, and the expansion pipe is arranged on the throat part.
Through adopting above-mentioned technical scheme for dismantle the structure of nozzle more reasonable, can control the fluidic flow of oil gas better, improve the precision of flow regulation.
Compared with the prior art, one of the purposes of the invention has the following beneficial effects:
The oil-gas fluid metering device with the changeable throat diameter changes the throat diameter under the condition that the whole venturi tube is not replaced, the flow adaptation range is enlarged, the problem that the throat size of the venturi tube is fixed to cause the flow adaptation range to be narrow in the prior art is solved, the sound velocity measuring mechanism and the density measuring mechanism are adopted to replace gamma ray technology for measurement, radiation risks are avoided, safety is improved, the structural design of the venturi tube is reasonable, the flow characteristics of oil-gas fluid can be better adapted, measurement accuracy is improved, the sound velocity measuring mechanism and the density measuring mechanism are arranged, sound velocity and density of the oil-gas fluid can be accurately measured, accurate data support is provided for flow calculation, the differential pressure sensor is arranged, the differential pressure of the venturi tube can be measured, flow measurement accuracy is further improved, the structural design of the dismounting nozzle is reasonable, the flow of the oil-gas fluid can be better controlled, and flow regulation accuracy is improved.
The second purpose of the invention is to provide an oil-gas fluid metering method, which solves the problems of low metering precision and poor adaptability of gas-liquid two-phase flow in the prior art.
In order to achieve the second purpose, the invention provides an oil-gas fluid metering method, which adopts the following technical scheme:
A method of metering an oil and gas fluid comprising the steps of:
S1, determining a relation of the diameter D of a pipeline to be tested, the sound path L between an ultrasonic transmitting probe and an ultrasonic receiving probe, the propagation speed C L of ultrasonic waves in a liquid phase and the propagation speed C G of ultrasonic waves in a gas phase along with the change of temperature, the density rho L of the liquid phase and the density rho G of the gas phase along with the change of temperature and pressure;
S2, collecting pressure P measured by a pressure sensor, temperature T measured by a temperature sensor and propagation time delta T of ultrasonic waves from an ultrasonic transmitting probe to an ultrasonic receiving probe;
S3, calculating gas phase density and liquid phase density according to a relation between pressure P and temperature T combined with the temperature and pressure in S1, and calculating the transmission speed C L of ultrasonic waves in the liquid phase and the transmission speed C G of the ultrasonic waves in the gas phase according to the relation between temperature T combined with the temperature in S1;
S4, calculating the velocity of sound of the throat oil-gas fluid according to the following steps:
S5, bringing the sound velocity of the oil-gas fluid into a volume gas-containing rate calculation formula to calculate the volume gas-containing rate beta;
S6, calculating the gas phase quality air-content x G by utilizing a quality air-content calculation formula according to the relation between the volume air-content and the quality air-content;
S7, calculating the mass flow M G+L of the oil-gas fluid by using an oil-gas fluid mass flow formula according to the relation between the gas phase mass gas content x G and the differential pressure DeltaP G+L;
S8, calculating a gas phase flow M G and a liquid phase flow M L according to the following two formulas:
MG＝MG+LxG
ML＝MG+L(1-xG)。
By adopting the technical scheme, the influence of various parameters on the flow is comprehensively considered, the mass flow, the gas phase flow and the liquid phase flow of the oil-gas fluid can be accurately calculated, and the accuracy and the reliability of flow measurement are improved.
Further, the volume air content β in S5 is calculated by the following formula:
Wherein, C m is the sound velocity of oil-gas fluid, the unit m/s, C G is the sound velocity of gas phase, the unit m/s, C L is the sound velocity of liquid phase, the unit m/s, beta is the gas content, ρ G is the gas phase density, the unit kg/m3, and ρ L is the liquid phase density, the unit kg/m3.
By adopting the technical scheme, the volume air-content can be calculated more accurately, and accurate basic data is provided for subsequent mass air-content and flow calculation.
Further, the gas phase mass gas content x G in S6 is calculated by the following formula:
Wherein x G is mass air content, beta is volume air content, rho G is gas phase density in kg/m3, rho L is liquid phase density in kg/m3.
By adopting the technical scheme, the gas content of the gas phase quality can be calculated more accurately, and the accuracy of flow calculation is further improved.
Further, the mass flow rate M G+L of the hydrocarbon fluid in S7 is calculated by the following formula:
Wherein DeltaP G+L is the differential pressure of the oil-gas fluid, the unit Pa, M G+L is the mass flow of the oil-gas fluid, the unit kg/s and A, B is the coefficient, and the oil-gas fluid is obtained through experimental calibration.
By adopting the technical scheme, the mass flow of the oil-gas fluid can be calculated more accurately, and a reliable method is provided for metering the oil-gas fluid.
Compared with the prior art, the second purpose of the invention has the following beneficial effects:
The oil-gas fluid metering method comprehensively considers the influence of various parameters on flow, can accurately calculate the mass flow, gas phase flow and liquid phase flow of the oil-gas fluid, improves the accuracy and reliability of flow measurement, can more accurately calculate the volume air-content by a calculation formula of the volume air-content, provides accurate basic data for subsequent mass air-content and flow calculation, can more accurately calculate the gas phase mass air-content by a calculation formula of the gas phase mass air-content, further improves the accuracy of flow calculation, can more accurately calculate the mass flow of the oil-gas fluid by a calculation formula of the mass flow of the oil-gas fluid, provides a reliable method for metering the oil-gas fluid, is suitable for various working conditions, has wide applicability, and can further improve the accuracy of flow calculation by a coefficient A, B obtained through experimental calibration.
Drawings
The accompanying drawings, which are included to provide a further understanding of the invention and are incorporated in and constitute a part of this specification, illustrate embodiments of the invention and together with the description serve to explain the invention.
In the drawings:
FIG. 1 is a schematic view of an oil-gas fluid metering apparatus with changeable throat diameter according to an embodiment of the present invention;
FIG. 2 is a front cross-sectional view of a nozzle according to an embodiment of the invention;
Fig. 3 is a side cross-sectional view of a disassembly nozzle according to an embodiment of the invention.
Reference numerals illustrate:
1. Venturi tube, 2, upstream flange, 3, downstream flange, 4, temperature sensor, 5, pressure sensor, 6, differential pressure sensor, 7, ultrasonic transmitting probe, 8, ultrasonic receiving probe, 9, inlet straight tube section, 10, convergent section, 11, throat, 12, divergent section, 13, outlet straight tube section, 14, upstream pressure guiding tube, 15, middle pressure guiding tube, 16, dismounting nozzle, 17, throttle tube, 18, expansion tube, 19, screw thread, 20, groove.
Detailed Description
It should be noted that, without conflict, the embodiments of the present invention and features of the embodiments may be combined with each other.
In the description of the present invention, it should be noted that, if terms indicating an azimuth or a positional relationship such as "upper", "lower", "inner", "back", and the like are presented, they are based on the azimuth or the positional relationship shown in the drawings, only for convenience in describing the present invention and simplifying the description, and do not indicate or imply that the apparatus or element to be referred to must have a specific azimuth, be constructed and operated in a specific azimuth, and thus should not be construed as limiting the present invention. Furthermore, the terms "first," "second," and the like, if any, are also used for descriptive purposes only and are not to be construed as indicating or implying relative importance.
Furthermore, in the description of the present invention, the terms "mounted," "connected," "coupled," and "connected," are to be construed broadly, unless otherwise specifically limited. For example, the components may be fixedly connected, detachably connected or integrally connected, mechanically connected or electrically connected, directly connected or indirectly connected through an intermediate medium, or communicated with each other. The specific meaning of the above terms in the present invention can be understood by those of ordinary skill in the art in combination with specific cases.
The invention will be described in detail below with reference to the drawings in connection with embodiments.
Example 1
The embodiment relates to an oil-gas fluid metering device with changeable throat diameter, which is structurally characterized by comprising a venturi tube 1, a dismounting nozzle 16, a sound velocity measuring mechanism and a density measuring mechanism as shown in fig. 1.
The two ends of the venturi tube 1 are provided with an upstream flange 2 and a downstream flange 3 which are used for connecting a pipeline to be tested, a disassembly nozzle 16 is arranged in the middle of the venturi tube 1 and used for controlling the flow of the oil-gas fluid, an acoustic velocity measuring mechanism is arranged at the downstream of the disassembly nozzle 16 of the venturi tube 1 and used for measuring the propagation velocity of the oil-gas fluid, a density measuring mechanism is arranged at the upstream of the disassembly nozzle 16 of the venturi tube 1 and used for measuring the density of the oil-gas fluid.
It should be mentioned that the pipe to be measured is an output pipe of an oil well, the oil gas fluid metering device is installed on the pipe to be measured, the flow rate of the gas phase and the flow rate of the liquid phase can be measured, the venturi tube 1 is installed on the pipe to be measured, the principle of the venturi tube 1 is the same as that of the venturi tube 1 in the prior art, and needless to say, flanges are needed to be welded on the pipe to be measured, the sound velocity measuring mechanism and the density measuring mechanism which are convenient for installing the upstream flange 2 and the downstream flange 3 are installed on the venturi tube 1, when the oil gas fluid passes through the venturi tube 1, the sound velocity and the density are measured, the data are brought into a series of formulas, so that the flow rate of the gas phase and the flow rate of the liquid phase are calculated, and the purpose of adding the disassembly nozzle 16 in the middle part of the venturi tube 1 is ensured to control the flow rate of the oil gas fluid by replacing nozzles with different sizes.
Based on the above general description, an exemplary structure of the electromagnetic wire dewatering and drying apparatus of the present embodiment, as shown in fig. 1, the venturi tube 1 includes, in order from upstream to downstream, an inlet straight tube section 9, a tapered section 10, a throat section 11, a diverging section 12, and an outlet straight tube section 13.
The device comprises an inlet straight pipe section 9, a density measuring mechanism, a converging section 10, a disassembly nozzle 16, a throat 11, a sound velocity measuring mechanism, a throat 11, a diverging section 12, an outlet straight pipe section 13, a converging section 12, a diverging section 3 and a downstream flange 3, wherein the inlet straight pipe section 9 is fixedly connected with the upstream flange 2, the density measuring mechanism is communicated with the inlet straight pipe section 9, one end with the large diameter of the converging section 10 is fixedly connected with the inlet straight pipe section 9, one end with the small diameter is in sealing connection with the disassembly nozzle 16, one end of the throat 11 is in sealing connection with the disassembly nozzle 16, the sound velocity measuring mechanism is communicated with the throat 11, one end with the small diameter of the diverging section 12 is fixedly connected with the other end of the throat 11, and one end of the outlet straight pipe section 13 is fixedly connected with the large diameter end of the diverging section 12.
It should be noted that, the inlet straight pipe section 9 and the tapering section 10 may be integrally formed, the upstream flange 2 may be welded on the inlet straight pipe section 9, the throat 11, the diverging section 12 and the outlet straight pipe section 13 may also be integrally formed, the downstream flange 3 may be welded on the outlet straight pipe section 13, so as to improve the strength of the venturi tube 1, the purpose of installing the disassembling nozzle 16 between the tapering section 10 and the throat 11 is to adjust the flow of the venturi tube 1, and by replacing the disassembling nozzle 16 with different apertures, different differential pressures are realized, and the requirement of accurate measurement of differential pressure under different gas-liquid fluid flows may be satisfied, thereby realizing accurate measurement of a larger gas-liquid flow range.
As a preferred embodiment, as shown in fig. 1, the sound speed measuring mechanism of the present embodiment includes an ultrasonic transmitting probe 7, an ultrasonic receiving probe 8, and a temperature sensor 4.
Wherein, ultrasonic emission probe 7 and ultrasonic receiving probe 8 are installed respectively in the upper reaches and the low reaches of throat 11 for measuring the sound velocity of oil gas fluid, temperature sensor 4 installs in entry straight tube section 9 department, cooperates ultrasonic emission probe 7 and ultrasonic receiving probe 8, measures gas phase sound velocity and liquid phase sound velocity respectively.
Specifically, the ultrasonic transmitting probe 7 and the ultrasonic receiving probe 8 are respectively installed at the upstream and downstream of the throat 11, namely at the two sides of the throat 11, so that the ultrasonic wave emitted by the ultrasonic transmitting probe 7 can be received by the ultrasonic receiving probe 8 after passing through the hydrocarbon fluid, thereby obtaining the sound path and the time, the temperature sensor 4 measures the temperature of the hydrocarbon fluid at the position, and the sound velocity of the hydrocarbon fluid is calculated according to the propagation speeds of the ultrasonic wave in the gas phase and the liquid phase at different temperatures.
As a preferred embodiment, as shown in fig. 1, the density measuring mechanism of the present embodiment includes an upstream pressure guiding pipe 14 and a pressure sensor 5. Wherein the upstream pressure guiding pipe 14 is communicated with the inlet straight pipe section 9, the pressure sensor 5 is arranged on the upstream pressure guiding pipe 14, and the pressure at the inlet straight pipe section 9 is measured. Specifically, the upstream pressure guiding pipe 14 may be welded to the inlet straight pipe section 9 of the venturi tube 1, the pressure sensor 5 measures the pressure there, and the temperature measured by the temperature sensor 4 is matched, so that the gas phase density and the liquid phase density are calculated.
Preferably, in this embodiment, the venturi tube 1 is further provided with a differential pressure sensor 6, the throat portion 11 is provided with a middle pressure guiding tube 15, the high pressure end of the differential pressure sensor 6 is communicated with the upstream pressure guiding tube 14, and the low pressure end is communicated with the middle pressure guiding tube 15. The differential pressure sensor 6 is used to measure the differential pressure between the inlet straight pipe section 9 and the throat 11, and due to the principle of the venturi tube 1, a certain differential pressure is generated due to the difference in diameter between the inlet straight pipe section 9 and the throat 11, and the data is carried in according to the differential pressure measured by the differential pressure sensor 6, so that the flow rate of the oil gas fluid is calculated.
As a preferred embodiment, as shown in fig. 2 and 3, the disassembly nozzle 16 of the present embodiment is mainly composed of a throttle pipe 17 and a divergent pipe 18, the outlet of the throttle pipe 17 is communicated with the inlet of the divergent pipe 18, the throttle pipe 17 is installed at the inlet straight pipe section 9, and the divergent pipe 18 is installed at the throat 11. Specifically, the throttle pipe 17 is a circular pipe with equal diameter, the expansion pipe 18 is a gradually expanding structure, the diameter of the inlet of the expansion pipe is the same as that of the throttle pipe 17, the diameter of the outlet of the expansion pipe is the same as that of the throat 11 of the venturi pipe 1, when the throttle pipe 17 is installed, the outer surface of the expansion pipe is attached to the inner surface of the tapered section 10 of the venturi pipe 1, interference fit can be adopted, when the expansion pipe 18 is installed, the outer surface of the expansion pipe 18 is attached to the inner surface of the throat 11 of the venturi pipe 1, threads 19 are arranged on the outer surface of the expansion pipe 18, installation is completed through engagement of the two threads 19, and meanwhile, a groove 20 is further formed on the outer surface of the disassembly nozzle 16, so that the large flat screwdriver is conveniently installed at a designated position.
According to the oil-gas fluid metering device with the changeable throat diameter, the changeable dismounting nozzle 16 is arranged, so that the throat diameter is changed under the condition that the whole venturi tube 1 is not changed, the flow adaptation range is enlarged, the problem that the flow adaptation range is narrow due to the fact that the throat 11 of the venturi tube 1 is fixed in size in the prior art is solved, the sound velocity measuring mechanism and the density measuring mechanism are adopted to replace gamma ray technology for measurement, radiation risks are avoided, safety is improved, the structural design of the venturi tube 1 is reasonable, the flow characteristics of oil-gas fluid can be better adapted, measurement accuracy is improved, the sound velocity measuring mechanism and the density measuring mechanism are arranged, sound velocity and density of the oil-gas fluid can be accurately measured, accurate data support is provided for flow calculation, the differential pressure sensor 6 is arranged, the differential pressure of the venturi tube 1can be measured, flow measurement accuracy is further improved, the dismounting nozzle 16 is reasonable in structural design, the flow of the oil-gas fluid can be better controlled, and flow adjustment accuracy is improved.
Example two
The embodiment relates to an oil-gas fluid metering method, which comprises the following steps in an integral structure.
S1, determining a relation of the diameter D of a pipeline to be tested, the sound path L between an ultrasonic transmitting probe 7 and an ultrasonic receiving probe 8, the propagation speed C L of ultrasonic waves in a liquid phase and the propagation speed C G of ultrasonic waves in a gas phase along with the change of temperature, the density rho L of the liquid phase and the density rho G of the gas phase along with the change of temperature and pressure;
s2, collecting pressure P measured by the pressure sensor 5, temperature T measured by the temperature sensor 4 and propagation time difference Deltat between ultrasonic waves from the ultrasonic transmitting probe 7 to the ultrasonic receiving probe 8;
S3, calculating gas phase density and liquid phase density according to a relation between pressure P and temperature T combined with the temperature and pressure in S1, and calculating the transmission speed C L of ultrasonic waves in the liquid phase and the transmission speed C G of the ultrasonic waves in the gas phase according to the relation between temperature T combined with the temperature in S1;
S4, calculating the velocity of sound of the throat oil-gas fluid according to the following steps:
S5, bringing the sound velocity of the oil-gas fluid into a volume gas-containing rate calculation formula to calculate the volume gas-containing rate beta;
S6, calculating the gas phase quality air-content x G by utilizing a quality air-content calculation formula according to the relation between the volume air-content and the quality air-content;
S7, calculating the mass flow M G+L of the oil-gas fluid by using an oil-gas fluid mass flow formula according to the relation between the gas phase mass gas content x G and the differential pressure DeltaP G+L;
S8, calculating a gas phase flow M G and a liquid phase flow M L according to the following two formulas:
MG＝MG+LxG
ML＝MG+L(1-xG)。
It should be noted that, after the ultrasonic wave is generated by the ultrasonic transmitting probe 7, the ultrasonic wave is received by the ultrasonic receiving probe 8 after the time Δt passes, and if the path (i.e. the sound path L) that the ultrasonic wave between the ultrasonic transmitting probe 7 and the ultrasonic receiving probe 8 passes through, the ultrasonic propagation speed C m in the hydrocarbon fluid may be calculated in step S4.
Preferably, the formula for calculating the volumetric air content β in S5 is as follows:
Wherein, C m is the sound velocity of oil-gas fluid, the unit m/s, C G is the sound velocity of gas phase, the unit m/s, C L is the sound velocity of liquid phase, the unit m/s, beta is the gas content, ρ G is the gas phase density, the unit kg/m 3;ρL is the liquid phase density, and the unit kg/m 3.
Specifically, the relationship between the propagation speed C L of the ultrasonic wave in the liquid phase and the propagation speed C G of the ultrasonic wave in the gas phase in the S1 with temperature, the relationship between the liquid phase density ρ L, and the relationship between the gas phase density ρ G with temperature and pressure can be obtained by experiments.
For the liquid phase, the relationship of sound velocity to temperature generally uses a linear empirical formula of vt=v0+α (t-t 0).
Wherein vt is the sound velocity at the temperature t, in m/s, v is the reference temperature, and at t0, in m/s, α is the temperature coefficient, which represents the variation of the sound velocity per 1 degree centigrade, in m/(s·centigrade), and t0 is the reference temperature, in centigrade.
For the gas phase, if considered as ideal gas, the sound velocity expression is c=γrt.
Wherein, gamma is the adiabatic index (specific heat ratio) of air, the diatomic gas (such as air) takes gamma=1.4, R is the gas constant, R=287J/(kg.K) of air, T is absolute temperature, and unit K.
And calculating the sound velocity C m of the oil-gas fluid according to the sound velocity of the single-phase medium, and taking the calculation result into the formula to obtain the volume gas fraction beta.
Preferably, the formula for calculating the gas phase mass gas content x G mentioned in S6 is:
Wherein x G is gas phase mass gas content, beta is volume gas content, ρ G is gas phase density, unit kg/m 3;ρL is liquid phase density, unit kg/m 3.
Specifically, the gas phase mass gas content is a function of the volume gas content and the densities of the gas phase and the liquid phase, and the mass gas content x G can be obtained by introducing the calculation result of the volume gas content beta into the formula.
Preferably, the formula for calculating the mass flow rate M G+L of the hydrocarbon fluid mentioned in S7 is:
Wherein DeltaP G+L is the differential pressure of the oil-gas fluid, the unit Pa, M G+L is the mass flow of the oil-gas fluid, the unit kg/s and A, B is the coefficient, and the oil-gas fluid is obtained through experimental calibration.
Specifically, a pressure drop (i.e., differential pressure Δp G+L) is generated when the hydrocarbon fluid passes through the venturi tube, and the hydrocarbon fluid differential pressure Δp G+L and the gas phase mass air content x G are brought into the above formula to obtain the hydrocarbon fluid mass flow M G+L, where A, B is a coefficient. The A, B coefficient can be obtained by least square fitting after the actual gas-liquid mass flow rate M G+L, the gas-phase mass gas content x G, and the differential pressure Δp G+L are measured.
According to the oil-gas fluid metering method, the influence of various parameters on the flow is comprehensively considered, the mass flow, the gas phase flow and the liquid phase flow of the oil-gas fluid can be accurately calculated, the accuracy and the reliability of flow measurement are improved, the volume gas content can be more accurately calculated according to a calculation formula of the volume gas content, accurate basic data are provided for subsequent mass gas content and flow calculation, the gas phase mass gas content can be more accurately calculated according to a calculation formula of the gas phase mass gas content, the accuracy of flow calculation is further improved, the mass flow of the oil-gas fluid can be more accurately calculated according to a calculation formula of the mass flow of the oil-gas fluid, a reliable method is provided for metering the oil-gas fluid, the method is suitable for various working conditions, wide applicability is achieved, and the accuracy of flow calculation can be further improved through coefficients A, B obtained through experimental calibration.
The foregoing description of the preferred embodiments of the invention is not intended to be limiting, but rather is intended to cover all modifications, equivalents, alternatives, and improvements that fall within the spirit and scope of the invention.
Claims (10)
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