CN112392460A - Method and system for detecting small-flow oil-gas-water multiphase flow - Google Patents
Method and system for detecting small-flow oil-gas-water multiphase flow Download PDFInfo
- Publication number
- CN112392460A CN112392460A CN202011327780.2A CN202011327780A CN112392460A CN 112392460 A CN112392460 A CN 112392460A CN 202011327780 A CN202011327780 A CN 202011327780A CN 112392460 A CN112392460 A CN 112392460A
- Authority
- CN
- China
- Prior art keywords
- flow
- module
- gas
- information
- venturi tube
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Pending
Links
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 title claims abstract description 45
- 238000000034 method Methods 0.000 title claims abstract description 17
- 238000003325 tomography Methods 0.000 claims abstract description 71
- 238000001514 detection method Methods 0.000 claims abstract description 51
- 238000011144 upstream manufacturing Methods 0.000 claims abstract description 27
- 230000004927 fusion Effects 0.000 claims abstract description 6
- 238000005457 optimization Methods 0.000 claims abstract description 5
- 239000007788 liquid Substances 0.000 claims description 22
- 238000003909 pattern recognition Methods 0.000 claims description 14
- 238000004587 chromatography analysis Methods 0.000 claims description 13
- 230000008602 contraction Effects 0.000 claims description 13
- 238000004364 calculation method Methods 0.000 claims description 10
- 238000010079 rubber tapping Methods 0.000 claims description 3
- 239000007789 gas Substances 0.000 description 41
- 239000012071 phase Substances 0.000 description 36
- 239000007791 liquid phase Substances 0.000 description 11
- 238000005259 measurement Methods 0.000 description 5
- 238000005516 engineering process Methods 0.000 description 4
- 239000012530 fluid Substances 0.000 description 4
- 230000001133 acceleration Effects 0.000 description 2
- 238000009826 distribution Methods 0.000 description 2
- 238000004519 manufacturing process Methods 0.000 description 2
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- 239000003921 oil Substances 0.000 description 2
- 230000003068 static effect Effects 0.000 description 2
- 230000001154 acute effect Effects 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 238000009530 blood pressure measurement Methods 0.000 description 1
- 239000003795 chemical substances by application Substances 0.000 description 1
- 239000000839 emulsion Substances 0.000 description 1
- 230000005484 gravity Effects 0.000 description 1
- 238000003384 imaging method Methods 0.000 description 1
- 239000000203 mixture Substances 0.000 description 1
- 239000003345 natural gas Substances 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 230000009466 transformation Effects 0.000 description 1
- 238000000844 transformation Methods 0.000 description 1
- 230000005514 two-phase flow Effects 0.000 description 1
Images
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling 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
-
- 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
Landscapes
- Physics & Mathematics (AREA)
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Fluid Mechanics (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Environmental & Geological Engineering (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- General Physics & Mathematics (AREA)
- Geophysics (AREA)
- Measuring Volume Flow (AREA)
Abstract
The invention relates to the technical field of multiphase flow testing, in particular to a method and a system for detecting small-flow oil-gas-water multiphase flow, which comprise a Venturi tube and sensing systems arranged at the upstream, the throat and the downstream of the Venturi tube, wherein the sensing systems comprise a capacitance tomography module, a resistance tomography module, a microwave detection module and at least one pressure taking module, and the method comprises the following steps: receiving sensing information transmitted by a sensing system; importing the sensing information into a preset model for processing, and determining processing information; and transmitting the processing information to the multi-sensing fusion optimization model to obtain the corrected oil, gas and water three-phase flow. The invention provides a method and a system for detecting small-flow oil-gas-water multiphase flow, which solve the problem that the existing detection method is difficult to detect multiphase flow with different flow patterns.
Description
Technical Field
The invention relates to the technical field of multiphase flow testing, in particular to a method and a system for detecting small-flow oil-gas-water multiphase flow.
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. In a new generation of non-separated multiphase flow metering technology, manufacturers at home and abroad adopt a technical solution of multi-sensor fusion. However, the main application range of the prior art is single well or confluence metering with large production, and no effective solution for a small-production well exists at present. The reason for this is that in small flow flows, sensors of all types cannot produce reliable and stable signals. Most of onshore oil and gas fields in China have low single-well yield, so that a multiphase flow metering technology aiming at different flow patterns and suitable for small-yield single wells is urgently needed.
Disclosure of Invention
The invention provides a method and a system for detecting small-flow oil-gas-water multiphase flow, which aim to solve the problem that the existing detection method is difficult to detect multiphase flows of different flow types.
The technical scheme for solving the problems is as follows: a detection method for small-flow oil-gas-water multiphase flow comprises a Venturi tube and sensing systems arranged at the upstream, the throat and the downstream of the Venturi tube, wherein the sensing systems comprise a capacitance tomography module, a resistance tomography module, a microwave detection module and at least one pressure tapping module; the method comprises the following steps:
step 1: receiving sensing information transmitted by the sensing system, wherein
The sensing information comprises microwave original signals, water content result information, chromatography signals, temperature signals, pressure signals, gas component information and differential pressure information of each part of the Venturi tube;
step 2: importing the sensing information into a preset model for processing, and determining processing information;
the preset model comprises: a flow pattern recognition sub-model, a gas phase density calculation sub-model and a Venturi comprehensive model;
the processing information includes: liquid film thickness information of the throat part and the downstream of the Venturi tube, flow pattern recognition result information and gas and liquid instantaneous flow information;
and step 3: and transmitting the processing information to a multi-sensing fusion optimization model to obtain the corrected oil, gas and water three-phase flow.
Preferably, the step 2 specifically includes:
transmitting the microwave original signal and the chromatography signal to the flow pattern recognition submodel to obtain flow pattern recognition result information and liquid film thickness information of the throat part and the downstream part of the Venturi tube;
transmitting the temperature signal, the pressure signal and the gas component information to the gas phase density calculation submodel to obtain gas phase density information;
and transmitting the gas phase density information, the differential pressure information of each part of the Venturi tube and the flow pattern identification result information to the Venturi comprehensive model to obtain the gas and liquid instantaneous flow information.
Preferably, step 1 further comprises:
receiving microwave original signals in real time;
and transmitting the microwave original signal to a microwave moisture content submodel to obtain moisture content result information.
Preferably, the step after obtaining the moisture content result information further includes:
and judging whether the water content is lower than 40%, if so, selecting the capacitance tomography module to detect the multiphase flow in the Venturi tube and sending a chromatography signal, and if not, selecting the resistance tomography module to detect the multiphase flow in the Venturi tube and sending the chromatography signal.
Preferably, the microwave raw signal includes amplitude and phase information of the microwave.
The invention also provides an oil-gas-water multiphase flow detection system aiming at small flow, which comprises a Venturi tube, a sensing system and a data acquisition and processing unit,
sensing systems are arranged at the upstream, the throat and the downstream of the Venturi tube, each sensing system comprises a capacitance tomography module, a resistance tomography module, a microwave detection module and at least one pressure taking module, and a differential pressure transmitter is connected between every two adjacent pressure taking modules and used for measuring pressure difference values between the pressure taking modules at different positions;
the data acquisition and processing unit is respectively electrically connected with the pressure acquisition module, the capacitance tomography module, the resistance tomography module, the microwave detection module and the differential pressure transmitter and is used for acquiring and processing data of each functional module.
Preferably, a pressure transmitter is arranged at the upstream of the venturi tube, and a temperature transmitter is arranged at the downstream of the venturi tube.
Preferably, the throat part of the Venturi tube is provided with two pressure taking modules, and the distance between the two pressure taking modules is not less than 100 mm.
Preferably, the pipe diameter of the Venturi pipe is less than 50mm, and the inner diameter of the Venturi pipe is 20-49 mm; the diameter ratio of the throat part of the Venturi tube to the upstream pipeline and the diameter ratio of the throat part of the Venturi tube to the downstream pipeline are both 0.3-0.7; the contraction angle range of the contraction section of the Venturi tube is 16-25 degrees, the expansion angle range of the expansion section is 5-15 degrees, and the length range of the throat part is 150-500 mm.
Preferably, the distance between the pressure taking module arranged upstream of the Venturi tube and the starting end of the contraction section is more than 0.5D; the distance between the pressure-taking module arranged at the downstream and the tail end of the expansion section is more than 2D, wherein D is the inner diameter of the upstream pipeline or the downstream pipeline.
Compared with the prior art, the invention has the beneficial effects that:
1) the method of the invention can provide accurate measurement for multiphase flow of different flow patterns.
2) The invention combines the electrical tomography technology which can directly detect the multiphase distribution information on the section of the pipeline with the Venturi flowmeter and simultaneously assists the microwave detection technology which can measure the water content to measure the oil-gas-water multiphase flow.
3) The invention can identify the local section phase distribution and the water content by the electrical imaging sensor and the microwave sensor which are arranged at different key positions of the Venturi tube, and judge the cause of pressure drop of the multiphase flow in the Venturi tube.
Drawings
FIG. 1 is a schematic flow chart of the detection method of the present invention.
FIG. 2 is a schematic view of the structure of the detection system of the present invention.
In the figure: 100-venturi tube, 2-first pressure taking module, 3-first capacitance tomography module, 4-first resistance tomography module, 5-first microwave detection module, 6-second pressure taking module, 7-second capacitance tomography module, 8-second resistance tomography module, 9-second microwave detection module, 10-third pressure taking module, 11-fourth pressure taking module, 12-third capacitance tomography module, 13-third resistance tomography module, 14-third microwave detection module, 15-pressure transmitter, 16-first differential pressure transmitter, 17-second differential pressure transmitter, 18-third differential pressure transmitter, 19-temperature transmitter, 21-upstream pipeline, 1-constriction segment, 22-throat, 23-expansion section, 24-downstream pipeline.
Detailed Description
In order to make the objects, technical solutions and advantages of the embodiments of the present invention more apparent, the technical solutions of the embodiments of the present invention will be described clearly and completely with reference to the accompanying drawings of the embodiments of the present invention, and it is obvious that the described embodiments are some, but not all embodiments of the present invention. All other embodiments, which can be obtained by a person skilled in the art without any inventive step based on the embodiments of the present invention, are within the scope of the present invention. Thus, the following detailed description of the embodiments of the present invention, presented in the figures, is not intended to limit the scope of the invention, as claimed, but is merely representative of selected embodiments of the invention.
A detection method for oil-gas-water multiphase flow aiming at small flow comprises a Venturi tube 100 and a sensing system arranged on an upstream pipeline 21, a throat 22 and a downstream pipeline 24 of the Venturi tube 100, wherein the sensing system comprises a capacitance tomography module, a resistance tomography module, a microwave detection module and at least one pressure taking module. The method comprises the following steps:
step 1: receiving sensing information transmitted by the sensing system, wherein
The sensing information comprises microwave original signals, water content result information, chromatography signals, temperature signals, pressure signals, gas component information and differential pressure information of each part of the Venturi tube 100;
step 2: importing the sensing information into a preset model for processing, and determining processing information;
the preset model comprises: a flow pattern recognition sub-model, a gas phase density calculation sub-model and a Venturi comprehensive model;
the processing information includes: liquid film thickness information of the throat part and the downstream of the Venturi tube, flow pattern recognition result information and gas and liquid instantaneous flow information;
and step 3: and transmitting the processing information to the multi-sensing fusion optimization model to obtain the corrected oil, gas and water three-phase flow.
Preferably, the step 2 specifically includes:
transmitting the microwave original signal and the chromatography signal to a flow pattern recognition sub-model to obtain flow pattern recognition result information and liquid film thickness information of the throat part and the downstream part of the Venturi tube;
transmitting the temperature signal, the pressure signal and the gas component information to a gas phase density calculation submodel to obtain gas phase density information;
and transmitting the gas phase density information, the differential pressure information of each part of the Venturi tube and the flow pattern identification result information to the Venturi comprehensive model to obtain the gas and liquid instantaneous flow information.
Preferably, step 1 further comprises:
receiving microwave original signals in real time;
and transmitting the microwave original signal to a microwave moisture content submodel to obtain moisture content result information.
Preferably, the step after obtaining the moisture content result information further includes:
and judging whether the water content is lower than 40%, if so, selecting the capacitance tomography module to detect the multiphase flow in the Venturi tube and sending a chromatography signal, and if not, selecting the resistance tomography module to detect the multiphase flow in the Venturi tube and sending the chromatography signal.
Preferably, the microwave raw signal comprises amplitude and phase information of the microwaves.
Example 1: a method for detecting a small flow rate oil-gas-water multiphase flow as shown in fig. 1 comprises the following steps:
1. measuring the average value of the water content of the liquid phase in the multiphase flow by adopting a first microwave detection module 5, a second microwave detection module 9 and a third microwave detection module 14, and transmitting the result to a data processing unit, wherein the data processing unit judges whether the average value of the water content is lower than 40%, if so, a first capacitance tomography module 3, a second capacitance tomography module 7 and a third capacitance tomography module 12 are selected for detecting the medium, and if not, a first resistance tomography module 4, a second resistance tomography module 8 and a third resistance tomography module 13 are selected for detecting the medium;
2. the first microwave detection module 5, the second microwave detection module 9 and the third microwave detection module 14 transmit measured original signals (amplitude and phase information of microwaves) to a flow pattern identification submodel in the data processing unit, and then judge the flow form of multiphase flow in the current pipeline by combining chromatography signals, and simultaneously obtain the average thickness of liquid films of the throat 22 and the downstream pipeline 24 of the venturi tube 100;
3. the pressure transmitter 15 and the temperature transmitter 19 transmit the real-time temperature and pressure information in the pipeline to a gas phase density calculation sub-model in the data processing unit, and the gas phase density calculation sub-model simultaneously receives the gas component information in the current pipeline to calculate the real-time density of the gas phase;
4. transmitting gas phase density information, differential pressure information of each part of the Venturi tube 100 and a flow pattern recognition result to a Venturi comprehensive model of a data processing unit, dividing the current flow into four conditions of single-phase liquid flow, single-phase gas flow, multiphase flow with gas content (GVF) higher than 95% and wet gas flow with gas content (GVF) lower than 95% according to the flow form, and respectively calculating the gas-liquid real-time flow rate by using corresponding flowmeter quantum models;
5. and (4) introducing the flow pattern recognition result, the gas-liquid flow calculation result, the water content information and the liquid film thickness information into a multi-sensing fusion optimization model to obtain the oil-gas-water three-phase flow.
Example 2: as shown in fig. 2, the oil-gas-water multiphase flow detection system for small flow rate includes a venturi tube 100, a first pressure taking module 2, a first capacitance tomography module 3, a first resistance tomography module 4, a first microwave detection module 5, a second pressure taking module 6, a second capacitance tomography module 7, a second resistance tomography module 8, a second microwave detection module 9, a third pressure taking module 10, a fourth pressure taking module 11, a third capacitance tomography module 12, a third resistance tomography module 13, a third microwave detection module 14, and a data acquisition and processing unit.
The venturi 100 comprises an upstream conduit 21, a convergent section 1, a throat 22, a divergent section 23 and a downstream conduit 24. Wherein the contraction section 1 is arranged between the upstream pipeline 21 and the throat 22, and the expansion section 23 is arranged between the throat 22 and the downstream pipeline 24. The upstream pipeline 21, the contraction section 1, the throat part 22, the expansion section 23 and the downstream pipeline 24 are connected through a flange structure.
The inner diameter of the venturi tube 100 is between 20 and 49 mm; the diameter ratio of the throat 22 to the upstream pipe 21 or the downstream pipe 24 is between 0.3 and 0.7; the contraction angle range of the contraction section 1 is 16-25 degrees; the divergence angle of the divergent section 23 is between 5 and 15 degrees; the length of the throat 22 ranges from 150 mm to 500 mm.
The first pressure taking module 2, the first capacitance tomography module 3, the first resistance tomography module 4 and the first microwave detection module 5 are sequentially arranged on an upstream pipeline 21 of the venturi tube 100 from left to right; the second pressure taking module 6, the second capacitance tomography module 7, the second resistance tomography module 8, the second microwave detection module 9 and the third pressure taking module 10 are sequentially arranged at the throat 22 of the venturi tube 100 from left to right; the fourth voltage-taking module 11, the third capacitance tomography module 12, the third resistance tomography module 13 and the third microwave detection module 14 are sequentially arranged on the downstream pipeline 24 of the venturi tube 100. The upstream 21, throat 22 and downstream 24 venturi pipes are connected. All the modules are connected inside the venturi tube 100 through flange structures, and the positions and the arrangement sequence of the modules can be changed according to requirements.
The detection system further comprises a pressure transmitter 15 and a temperature transmitter 19, the pressure transmitter 15 being arranged on the venturi tube upstream line 21 for detecting a pressure value at a location upstream of the venturi tube 100. A temperature transmitter 19 is provided in particular on the downstream line 24 of the venturi 100, for detecting a temperature value at a position downstream of the venturi 100. The pressure and temperature of the fluid are measured by the pressure transmitter 15 upstream of the venturi 100 and the temperature transmitter 19 downstream of the venturi 100, from which information the gas phase density in the multiphase flow can be calculated.
The data acquisition and processing unit is respectively electrically connected with the first pressure acquisition module 2, the first capacitance tomography module, the first resistance tomography module 4, the first microwave detection module 5, the second pressure acquisition module 6, the second capacitance tomography module 7, the second resistance tomography module 8, the second microwave detection module 9, the third pressure acquisition module 10, the fourth pressure acquisition module 11, the third capacitance tomography module 12, the third resistance tomography module 13, the third microwave detection module 14, the pressure transmitter 15, the first differential pressure transmitter 16, the second differential pressure transmitter 17, the third differential pressure transmitter 18 and the temperature transmitter 19, and is used for acquiring and processing data of each functional module.
After the oil-gas-water multiphase flow passes through the contraction section 1 of the venturi tube 100, the oil-water two phases form emulsion under the acceleration action, so that the multiphase flow is changed into annular or slug-shaped gas-liquid two-phase flow. In this state, the momentum differential equation of the gas-liquid two phases can be expressed by equations (1) and (2).
Wherein, the gas phase density is calculated by the pipeline pressure measured by the pressure transmitter 15; the liquid phase is a mixture of water and oil, and the density of the liquid phase can be obtained through the water content and the oil content measured by the capacitance tomography module and the resistance tomography module. Since in actual measurement there is only a single static pressure measurement across the cross-section of the pipe, the static pressure values of the liquid and gas phases can be considered equal. At this time, the two formulas (1) and (2) are combined to obtain:
wherein A is a gas phase flow area, AG is a gas phase flow area, AL is a liquid phase flow area, UG is a gas phase true flow rate, τ GW is a shear stress between a gas phase and a pipe wall, τ LW is a shear stress between a gas phase and a liquid film, τ i is a shear stress between a liquid phase and a pipe wall, SGW is a length of contact between the gas phase and the pipe wall on a pipe section, SLW is a length of contact between the liquid phase and the pipe wall, Si is a length of contact between the gas phase and the liquid film on the pipe section, and an angle theta refers to an acute angle formed between the pipe and a horizontal plane; x is the length of the flow direction of the fluid, dx is the flow direction space step; g is the acceleration of gravity; ρ is the density and subscript (G/L) indicates either the gas or liquid phase.
In the above formula, except for the gas phase and liquid phase mass flow WG and WL, other parameters are obtained from measurement signals of the second capacitance tomography module 7, the second resistance tomography module 8, the second microwave detection module 9, the third pressure taking module 10, the third capacitance tomography module 12, the third resistance tomography module 13, and the third microwave detection module 14. Using the above equation to describe the pressure drop across the throat 22 and the diverging section 23, two independent equations for WG and WL can be obtained. Meanwhile, the pressure drop of the lengthened throat 22 is measured by using a second differential pressure transmitter 17, so that the unrecoverable pressure drop of the fluid in the straight pipe is obtained; the differential pressure of the diverging section 21 of venturi 100 is measured using third differential pressure transmitter 18. The values of the gas phase flow and the liquid phase flow can be obtained by solving the equation system.
On the basis, the water content in the liquid phase is detected by using a second capacitance tomography module 7, a second resistance tomography module 8 and a second microwave detection module 9 of the throat part and a third capacitance tomography module 12, a third resistance tomography module 13 and a third microwave detection module 14 at the downstream of the venturi tube 100, so that the water flow in the liquid phase can be obtained, and the oil-gas-water three-phase flow can be obtained.
Different flow patterns will produce different pressure drops in the constriction 1 of the venturi 100. The total pressure drop of the fluid in the section can be obtained by measuring the pressure drop of the venturi constriction 1 by the first differential pressure transmitter 16. The incoming flow condition of the multiphase flow can be accurately judged through the pressure drop measurement of the first capacitance tomography module 3, the first resistance tomography module 4, the first microwave detection module 5 of the upstream pipeline 21 of the Venturi tube 1 and the contraction section 1 of the Venturi tube 100, so that the flow calculation model can be optimized in a targeted manner.
Because the signal coverage ranges of the capacitance tomography module and the resistance tomography module are different, the moisture content information is required to be used for distinguishing. Therefore, the average moisture content information detected by the first microwave detection module 5, the second microwave detection module 9, and the third microwave detection module 14 is used to determine which type of chromatographic sensor is used. Specifically, when the average water content is less than 40%, the capacitance tomography module is used for tomography, otherwise, the resistance tomography module is used for tomography.
The distance between the first pressure taking module 2 arranged on the upstream pipeline 21 of the venturi tube 100 and the starting end of the contraction section 1 is more than 0.5D; the fourth pressure tapping module 11 arranged on the downstream pipeline 24 is away from the tail end of the expansion section 23 by more than 2D, wherein D is the inner diameter of the upstream pipeline 21 or the downstream pipeline 24. The throat 22 of the venturi tube 100 is provided with the second pressure taking module 6 and the third pressure taking module 10, and the distance between the second pressure taking module 6 and the third pressure taking module 10 is not less than 100 mm.
The above description is only an embodiment of the present invention, and not intended to limit the scope of the present invention, and all equivalent structures or equivalent flow transformations made by using the contents of the specification and the drawings, or applied directly or indirectly to other related systems, are included in the scope of the present invention.
Claims (10)
1. A detection method for oil-gas-water multiphase flow aiming at small flow comprises a Venturi tube and sensing systems arranged at the upstream, the throat and the downstream of the Venturi tube, wherein the sensing systems comprise a capacitance tomography module, a resistance tomography module, a microwave detection module and at least one pressure tapping module, and the detection method is characterized by comprising the following steps of:
step 1: receiving sensing information transmitted by the sensing system, wherein
The sensing information comprises microwave original signals, water content result information, chromatography signals, temperature signals, pressure signals, gas component information and differential pressure information of each part of the Venturi tube;
step 2: importing the sensing information into a preset model for processing, and determining processing information;
the preset model comprises: a flow pattern recognition sub-model, a gas phase density calculation sub-model and a Venturi comprehensive model;
the processing information includes: liquid film thickness information of the throat part and the downstream of the Venturi tube, flow pattern recognition result information and gas and liquid instantaneous flow information;
and step 3: and transmitting the processing information to a multi-sensing fusion optimization model to obtain the corrected oil, gas and water three-phase flow.
2. The method for detecting the small-flow oil-gas-water multiphase flow according to claim 1, wherein the step 2 specifically comprises:
transmitting the microwave original signal and the chromatography signal to the flow pattern recognition submodel to obtain flow pattern recognition result information and liquid film thickness information of the throat part and the downstream part of the Venturi tube;
transmitting the temperature signal, the pressure signal and the gas component information to the gas phase density calculation submodel to obtain gas phase density information;
and transmitting the gas phase density information, the differential pressure information of each part of the Venturi tube and the flow pattern identification result information to the Venturi comprehensive model to obtain the gas and liquid instantaneous flow information.
3. The method for detecting the small-flow oil-gas-water multiphase flow according to claim 1, wherein the step 1 is preceded by the steps of:
receiving microwave original signals in real time;
and transmitting the microwave original signal to a microwave moisture content submodel to obtain moisture content result information.
4. The method for detecting the small-flow oil-gas-water multiphase flow according to claim 3, wherein the step after obtaining the water-cut result information further comprises:
and judging whether the water content is lower than 40%, if so, selecting the capacitance tomography module to detect the multiphase flow in the Venturi tube and sending a chromatography signal, and if not, selecting the resistance tomography module to detect the multiphase flow in the Venturi tube and sending the chromatography signal.
5. The method for detecting the oil-gas-water multiphase flow with the small flow rate as claimed in claim 3, wherein the microwave raw signal comprises amplitude and phase information of microwaves.
6. A detection system for oil-gas-water multiphase flow with small flow is characterized by comprising a Venturi tube, a sensing system and a data acquisition and processing unit,
sensing systems are arranged at the upstream, the throat and the downstream of the Venturi tube, each sensing system comprises a capacitance tomography module, a resistance tomography module, a microwave detection module and at least one pressure taking module, and a differential pressure transmitter is connected between every two adjacent pressure taking modules and used for measuring pressure difference values between the pressure taking modules at different positions;
the data acquisition and processing unit is respectively electrically connected with the pressure acquisition module, the capacitance tomography module, the resistance tomography module, the microwave detection module and the differential pressure transmitter and is used for acquiring and processing data of each functional module.
7. An oil-gas-water multiphase flow detection system for small flow according to claim 6, characterized in that a pressure transmitter is arranged upstream of the venturi tube, and a temperature transmitter is arranged downstream of the venturi tube.
8. The oil-gas-water multiphase flow detection system for the small flow rate as claimed in claim 6, wherein the throat part of the venturi tube is provided with two pressure taking modules, and the distance between the two pressure taking modules is not less than 100 mm.
9. A small flow rate oil-gas-water multiphase flow detection system as claimed in claim 6, wherein the venturi tube has a tube diameter of less than 50mm and an inner diameter of 20-49 mm; the diameter ratio of the throat part of the Venturi tube to the upstream pipeline and the diameter ratio of the throat part of the Venturi tube to the downstream pipeline are both 0.3-0.7; the contraction angle range of the contraction section of the Venturi tube is 16-25 degrees, the expansion angle range of the expansion section is 5-15 degrees, and the length range of the throat part is 150-500 mm.
10. The detection system according to claim 9, wherein the pressure taking module arranged upstream of the venturi tube is spaced from the start end of the contraction section by a distance greater than 0.5D; the distance between the pressure-taking module arranged at the downstream and the tail end of the expansion section is more than 2D, wherein D is the inner diameter of the upstream pipeline or the downstream pipeline.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202011327780.2A CN112392460A (en) | 2020-11-24 | 2020-11-24 | Method and system for detecting small-flow oil-gas-water multiphase flow |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202011327780.2A CN112392460A (en) | 2020-11-24 | 2020-11-24 | Method and system for detecting small-flow oil-gas-water multiphase flow |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CN112392460A true CN112392460A (en) | 2021-02-23 |
Family
ID=74607657
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN202011327780.2A Pending CN112392460A (en) | 2020-11-24 | 2020-11-24 | Method and system for detecting small-flow oil-gas-water multiphase flow |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN112392460A (en) |
Cited By (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN113124949A (en) * | 2021-04-06 | 2021-07-16 | 深圳市联恒星科技有限公司 | Multiphase flow detection method and system |
| CN115628783A (en) * | 2022-10-21 | 2023-01-20 | 深圳市联恒星科技有限公司 | Gas-liquid two-phase flow metering system based on multiple sensors |
-
2020
- 2020-11-24 CN CN202011327780.2A patent/CN112392460A/en active Pending
Cited By (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN113124949A (en) * | 2021-04-06 | 2021-07-16 | 深圳市联恒星科技有限公司 | Multiphase flow detection method and system |
| CN115628783A (en) * | 2022-10-21 | 2023-01-20 | 深圳市联恒星科技有限公司 | Gas-liquid two-phase flow metering system based on multiple sensors |
| CN115628783B (en) * | 2022-10-21 | 2023-09-12 | 深圳市联恒星科技有限公司 | Gas-liquid two-phase flow metering system based on multiple sensors |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| JP3150985B2 (en) | Monitoring method of multiphase fluid flow in pipe | |
| EP3494278B1 (en) | Monitoring hydrocarbon fluid flow | |
| RU2499229C2 (en) | Method and apparatus for determining composition and flow rate of wet gas | |
| CN112392460A (en) | Method and system for detecting small-flow oil-gas-water multiphase flow | |
| RU2498230C2 (en) | Method and device for measuring flow rate of wet gas and determination of gas characteristics | |
| CN106092236B (en) | A kind of multiphase flow metering detection system | |
| CN110514257B (en) | Venturi-based low liquid content moisture two-phase flow measuring device and method | |
| CN106840294A (en) | A kind of multiphase flow metering detecting system | |
| WO2017091522A1 (en) | A stratified flow multiphase flowmeter | |
| US20230417583A1 (en) | Wide range multi-phase flow meter | |
| CN113389540B (en) | Multiphase flow fluid measuring system | |
| CN204330035U (en) | A kind of electromagnetism crosscorrelation measurement sensor | |
| CN101539016A (en) | Method for measuring gas-liquid multiphase flow rate by utilizing thermal diffusion and device | |
| CN101339060B (en) | Heavy caliber electrical flow meter for user to send it to be checked | |
| CN214464099U (en) | Oil-gas-water multiphase flow detection system for small flow | |
| CN108369213A (en) | A method of improving detection oxygen concentration accuracy | |
| CN201032457Y (en) | Low gas content gas-liquid dual-phase flow measuring apparatus based on standard Venturi tube and vortex flowmeter | |
| CN104198000A (en) | Oil-gas-water three-phase flow array type electromagnetic correlation flow measurement method | |
| CN105841760A (en) | Insert-type electromagnetic flowmeter | |
| Han et al. | Measurement of velocity of sand-containing Oil–Water two-phase flow with super high water holdup in horizontal small pipe based on thermal tracers | |
| CN201081747Y (en) | Electromagnetic flow meter | |
| CN1105448A (en) | Method for measuring three-phase flow of oil, gas and water and apparatus thereof | |
| US7726185B2 (en) | System and method for measuring flow in a pipeline | |
| CN102262105B (en) | Dryness and flow measurement system for wet steam pipe network | |
| CN105628108B (en) | The device and method of biphase gas and liquid flow flow in a kind of measurement vertical pipeline |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| SE01 | Entry into force of request for substantive examination | ||
| SE01 | Entry into force of request for substantive examination |