WO2008050522A1 - Débitmètre multiphasique - Google Patents
Débitmètre multiphasique Download PDFInfo
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- WO2008050522A1 WO2008050522A1 PCT/JP2007/065796 JP2007065796W WO2008050522A1 WO 2008050522 A1 WO2008050522 A1 WO 2008050522A1 JP 2007065796 W JP2007065796 W JP 2007065796W WO 2008050522 A1 WO2008050522 A1 WO 2008050522A1
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- Prior art keywords
- liquid
- gas
- flow
- phase
- density
- Prior art date
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Classifications
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01F—MEASURING VOLUME, VOLUME FLOW, MASS FLOW OR LIQUID LEVEL; METERING BY VOLUME
- G01F1/00—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow
- G01F1/74—Devices for measuring flow of a fluid or flow of a fluent solid material in suspension in another fluid
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01F—MEASURING VOLUME, VOLUME FLOW, MASS FLOW OR LIQUID LEVEL; METERING BY VOLUME
- 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
Definitions
- the present invention relates to a multiphase flowmeter that measures the flow rates of each phase of a three-phase flow composed of a gas and two types of liquids.
- Oil produced from wells in the deep sea area forms a multiphase flow (three-phase flow, hereinafter abbreviated as multiphase flow) that contains water and gas in oil, and these phases are separated. After being transported to the land without pressure, it is separated and refined through a well collection process. Separated and refined oil • The gas is sent to the destination and sent to the destination, and the water is discharged. In the previous stage of the extraction well extraction process, the flow rate of each phase of the multiphase fluid is measured as necessary for the management of the extraction well, the extraction process or the shipment management.
- the flow rate of oil and water can be measured by adding an additional element for measuring the water content, but the element for measuring the water content is the same as that of the linear densitometer.
- Expensive and field calibration Many of them are premised on the implementation of the project, which has the problem of incurring further costs.
- Japanese Patent Publication No. 2 003-5 1 3234 discloses a technology relating to a density meter and the like. What can be considered by this disclosed technology is to eliminate the above-mentioned problem of high cost by applying the disclosed technology related to the density meter in JP 2003-5 1 3234 in place of the wire density meter. Have the potential to Special Table 2003-5
- the multi-phase flow measurement system (equivalent to a multi-phase flow meter) 100 is an eddy current separator 104 and an inflow multi-phase flow pipe that discharges the multi-phase fluid into this eddy current separator 104 And.
- the vortex separator 104 is configured to discharge gas to the upper gas measurement flow tube 106 and discharge liquid to the lower liquid measurement flow tube 108.
- the gas measurement flow tube 106 and the liquid measurement flow tube 108 are joined again in the discharge line 110 after the flow measurement is performed.
- the discharge line 1 1 0 is configured to extend to the three-phase output separator 1 18 before reaching the point of sale, allowing separation of the gas phase, water phase and oil phase.
- the multi-phase flow measurement system 100 includes an output manifold 1 1 6.
- the output manifold 1 1 6 is a part where multiphase fluid is supplied from multiple oil wells or gas wells.
- the inflow multiphase flow tube 10 2 is adapted to receive multiphase fluid from the output manifold 1 1 6 along the direction of arrow 1 2 0.
- reference numerals 1 2 2 are bench lily sections, 1 2 4 are inclined increase / decrease sections, and 1 2 6 is a horizontal discharge element for the vortex separator 10 4.
- the horizontal discharge element 1 2 6 is arranged to discharge a multiphase fluid in a tangential direction to the cylindrical internal separation part of the vortex separator 10 4.
- a multiphase fluid is discharged from the horizontal discharge element 1 2 6, it is said that this discharge causes a tornado effect or a cyclone effect in the liquid portion 1 2 8 in the vortex separator 1 0 4.
- the entire amount of multiphase fluid is discharged via the horizontal discharge element 1 2 6 ⁇
- the liquid portion 1 2 8 is the main liquid phase including the separated aqueous phase, oil phase, and entrained gas phase.
- the entrained gas phase is separated from the liquid portion 1 28 by the centrifugal force generated by the cyclone effect. It should be noted that the entrained gas phase cannot be completely removed except for the relatively low flow rates that allow additional gravity separation of the entrained gas phase. In other words, the entrained gas phase is not removed at high flow rates.
- the liquid portion 1 2 8 is discharged from the vortex separator 10 4 to the liquid measuring flow tube 10 8.
- the gas portion 1 3 2 inside the vortex separator 10 4 is the main gas phase containing gas, together with oil and water mist.
- the vortex separator 10 4 is provided with a mist collecting screen 1 3 4 that causes partial condensation of the mist.
- the gas portion 1 3 2 is discharged into the gas measuring flow tube 10 6.
- the gas measurement flow tube 1 0 6 is equipped with a Coriolis mass flow meter 1 5 4 It is.
- the Coriolis mass flow meter 15 4 provides mass flow and density measurements from the gas portion 1 3 2 of the multiphase fluid inside the gas measuring flow tube 10 6.
- the Coriolis mass flow meter 1 5 4 is connected to the flow transmitter 1 5 6, and a signal representing the measured value is output to the control device 1 1 2.
- the gas measurement flow pipe 10 6 is provided with a check valve 160.
- the check valve 160 ensures a reliable flow in the direction of the arrow 16 2, thereby preventing the liquid portion 1 2 8 from entering the gas measuring flow tube 10 6.
- the liquid measuring flow tube 10 8 is provided with a static mixer 1 6 4. Further, a Coriolis mass flow meter 1 6 6 and a moisture monitor 1 7 2 are provided behind the static mixer 1 6 4.
- the Coriolis mass flow meter 1 6 6 is adapted to provide mass flow and density measurements from the liquid portion 1 2 8 inside the liquid measuring flow tube 1 0 8.
- the Coriolis mass flow meter 1 6 6 is connected to the flow transmitter 1 6 8 so that a signal representing the measured value is output to the control device 1 1 2.
- the moisture monitor 1 7 2 measures the moisture content of the liquid portion 1 2 8 inside the liquid measurement flow tube 1 0 8.
- the water content monitor 1 7 2 is connected to the control device 1 1 2.
- the liquid measuring flow pipe 10 8 is provided with a check valve 1 78.
- the check valve 1 78 ensures a reliable flow in the direction of the arrow 1 8 0 and thereby prevents the gas part 1 3 2 from entering the liquid measuring flow tube 1 0 8. Yes.
- Reference numerals 1 5 0 and 1 7 4 indicate valves that are controlled to open and close by the control device 1 1 2.
- the output manifold 1 1 6 has valves 1 8 2 and 1 84 controlled via path 1 90.
- Valves 1 8 2 and 1 8 4 are composed of a single oil well 1 8 6 or a combination (for example, oil well 1 8 6 and gas well 1 8 8) flowing multi-phase fluid to rail 1 9 2 and inflow multi-phase flow pipe 1 0 selectively configured to distribute fluid to 2.
- the other valves pass through the bypass pipe 1 9 4 to bypass the multiphase flow measurement system 1 0 0. Selectively configured to bypass.
- Reference numerals 1 9 6 and 1 9 7 indicate manual valves.
- the bypass lines 1 9 8 inside the valves 1 9 6 and 1 9 7 are designed so that when the valve 1 9 9 is opened and the valves 1 5 0 and 1 7 4 are closed, the flow is a multiphase flow measurement system. 1 0 0 is bypassed.
- the above is a description of the multiphase flow measurement system 100.
- Japanese Patent Application Laid-Open No. 8-210 11 30 discloses a conventional technique for measuring the flow rate of a two-phase fluid of liquid and gas. Specifically, there is disclosed a technique of a turbine-type flow meter that measures the flow rate of a two-phase fluid of liquid and gas in the state of a mixed phase flow of liquid and gas (mixed liquid).
- the turbine-type flow meter has the same function as the ultrasonic flow meter described above, and can be used instead.
- Turbine-type flowmeters are known to have the effect of being able to measure at low cost with a simple structure and excellent durability.
- orifice flow meters are also known.
- the conventional multiphase flow measurement system 100 has a problem in the vortex separator 10 4 that separates the gas phase from the liquid phase and its peripheral configuration.
- the inventor of the present application has found that it cannot be applied instead of the total. That is, in the multiphase flow measurement system 100, the total amount of the multiphase fluid is discharged into the vortex separator 10 4 via the rail 1 92. However, the total amount of the multiphase fluid is Is discharged into the vortex separator 10 4, it means that many bubbles are swirled in a state where the liquid part 1 2 8 is contained.
- the inventor of the present application thinks that if only the cyclone effect of the vortex separator 10 4 is used, relatively small bubbles are entrained in the vortex and flow into the liquid measuring flow tube 10 8 ( Gas bubbles and liquid separation progresses when collisions occur and the bubbles grow larger, however, the free vortex generated inside the separator has a higher rotation ratio near the center and relatively near the center. As the pressure drops, small bubbles may be sucked into the liquid measuring flow tube 10 8 side. This is particularly noticeable when gravity separation is not possible. ) In the state containing a lot of small bubbles, the liquid portion 1 2 8 inside the liquid measurement flow tube 1 2 8 will be subjected to density measurement by the Coriolis mass flow meter 1 6 6. Density measurement with many small bubbles will cause an error because the measured value is different from the value without bubbles. Therefore, it will affect the subsequent calculation of flow rate.
- the present invention has been made in view of the above-described circumstances, and is intended to provide a multi-phase flow meter capable of accurately measuring a flow rate.
- Claim 1 was made to solve the above-described problem.
- the multi-phase flowmeter of the present invention described is a gas-liquid two-phase flow rate measuring unit that measures each phase flow rate of a gas-liquid two-phase flow in a three-phase flow composed of a gas and two kinds of liquids, and the gas-liquid two-phase flow meter
- a mixed liquid density measuring unit for measuring a mixed density of the mixed liquid as a liquid phase in the flow; a mixing ratio of the mixed liquid is obtained from the mixed density; and each flow rate of the mixed liquid is determined from the mixed ratio and the mixed liquid flow rate.
- Each phase flow rate calculation unit for calculating the mixed liquid density measurement unit includes a mixed liquid extraction unit and a density measurement unit coupled to the mixed liquid extraction unit, the mixed liquid extraction unit includes: A differential pressure generator provided in a pipeline for three-phase flow; A pair of communication pipes connected upstream and downstream of the differential pressure generator, and a place to take in a part of the three-phase flow by connecting to the pair of communication pipes, and using a pressure change before and after the differential pressure generator A gas-liquid extraction tank serving as a place for forcibly stirring a part of the three-phase flow; a gas-liquid discharge pipe connected to the gas-liquid extraction tank for discharging a gas containing a liquid phase; and the gas-liquid extraction Connect to the tank and mix at least the density measurement required by the density measurement unit.
- a liquid flow rate adjusting valve provided at least on the downstream side of the liquid storage tank, and the density measuring unit uses the liquid mixture for density measurement to measure the density. It has a density measuring unit main body for measuring, and a gas-liquid return pipe connected to the density measuring unit main body and the pipeline.
- a state in which a part of the three-phase flow taken into the gas-liquid extraction tank is forcibly agitated by a pressure change before and after the orifice (differential pressure generating device). become.
- a part of the three-phase flow taken in is forcibly shaken left and right and up and down and stirred.
- the bubbles contained in the mixed liquid grow into large bubbles due to the collision of the bubbles, and are separated from the mixed liquid to the gas phase side. Even small bubbles can be easily separated from the liquid mixture to the gas phase by forced stirring.
- the mixed liquid from which bubbles have been separated is stored by adjusting the liquid flow rate control valve.
- the mixed liquid collected in this reservoir tank is used for density measurement. Since the density measurement is performed on the mixed liquid from which bubbles are separated, highly accurate measurement values are provided.
- the liquid storage tank only needs to be able to take in and store the liquid mixture required by the density measuring unit at least, and for this reason, all of the three-phase flow taken in the gas-liquid extraction tank. There is no need for gas-liquid separation. In the gas-liquid extraction tank, it is sufficient if the gas can be removed to the extent that the liquid mixture required by the density measuring unit can be flowed to the liquid storage tank.
- the multi-phase flow meter of the present invention is the multi-phase flow meter according to claim 1, wherein the gas-liquid two-phase flow is a slag flow, or a bubble flow or a spiral flow. It is said.
- representative ones of the gas-liquid two-phase flow in the oil-water-gas mixed-phase flow (three-phase flow) produced from the well are slag flow, bubble flow or When these flows, the pressure change before and after the orifice in the mixed liquid density measurement section becomes larger and more dramatic.
- the multiphase flowmeter of the present invention according to claim 3 is the multiphase flowmeter according to claim 1 or 2, wherein the mixed liquid density measuring unit, or the mixed liquid density measuring unit and the gas-liquid The two-phase flow rate measuring unit is detachable from the pipeline.
- FIG. 1 is a configuration diagram of a multi-phase flow meter showing an embodiment of the present invention.
- FIG. 2 is a configuration diagram of the mixed liquid density measuring unit.
- Figure 3 is an explanatory diagram of the flow pattern in a horizontal pipe of gas-liquid two-phase flow.
- FIG. 4 is an explanatory view showing a state in the gas-liquid extraction tank.
- FIG. 5 is a configuration diagram showing another example of the gas-liquid two-phase flow rate measuring unit.
- Fig. 6 is a graph showing the measurement results of the oil / water density in the oil / water atmosphere using a corriometer.
- Fig. 7 shows the water content (water Z oil) in oil and water using a corriometer. It is a graph which shows a measurement result.
- FIG. 8 is a configuration diagram of a multi-phase flow meter showing another embodiment of the present invention.
- FIG. 9 is a configuration diagram of the mixed liquid density measuring unit.
- FIG. 10 is an explanatory view showing a state in the gas-liquid extraction tank.
- Fig. 11 is a block diagram of a conventional multiphase flow measurement system. BEST MODE FOR CARRYING OUT THE INVENTION
- FIG. 1 is a configuration diagram of a multi-phase flow meter showing an embodiment of the present invention.
- Fig. 2 is a block diagram of the mixed liquid density measurement unit
- Fig. 3 is an explanatory diagram of the flow pattern in the horizontal pipe of gas-liquid two-phase flow
- Fig. 4 is an explanatory diagram showing the state in the gas-liquid extraction tank.
- Fig. 5 is a configuration diagram showing another example of the gas-liquid two-phase flow rate measurement unit
- Fig. 6 is a graph showing the measurement result of the oil / water density in the oil / water using a Coriolis meter
- Fig. 7 is the moisture content in the oil / water using the Coriolis meter. It is a graph which shows the measurement result of (oil / oil).
- a multi-phase flow meter 1 of the present invention includes a mixed liquid density measuring unit 2, a gas-liquid two-phase flow measuring unit 3, and each phase flow calculating unit 4.
- the mixed liquid density measurement unit 2 in the multiphase flow meter 1 having such a configuration includes a mixed liquid extraction unit 5 and a density measurement unit 6.
- the gas-liquid two-phase flow rate measuring unit 3 has a configuration that can measure each phase flow rate of a gas-liquid two-phase flow in a three-phase flow (for example, gas, oil, water) consisting of a gas and two types of liquids.
- a turbine-type gas-liquid two-phase flow meter is used in this embodiment (for example, a turbine-type flow meter disclosed in Patent Document 3 in the background art column).
- the gas-liquid two-phase flow rate measuring unit 3 includes a homogenizer 1, a turbine meter 8, a differential pressure gauge 9, a pressure gauge 10, and a thermometer 11.
- the measurement value obtained by the gas-liquid two-phase flow rate measurement unit '3 is taken into each phase flow rate calculation unit 4, and the mixed liquid density
- the measurement value obtained by the degree measurement unit 2 is also taken into the respective phase flow rate calculation unit 4, where each phase flow rate of gas / oil / water is calculated.
- the multiphase flow meter 1 of the present invention has a configuration in which a mixed liquid density measuring unit 2 is combined with, for example, a known turbine-type gas-liquid two-phase flow flow meter. It becomes possible to provide a multi-phase flow meter capable of measuring a high flow rate.
- the mixed liquid density measuring unit 2 is configured to take in a part of the three-phase flow instead of the total amount of the three-phase flow in order to measure the density of the liquid phase (mixed liquid) as will be described later. Therefore, a multi-phase flow meter that can be made compact can be provided.
- FIGS each configuration and operation of the multiphase flow meter 1 of the present invention will be described with reference to FIGS.
- the mixed liquid density measuring unit 2 includes the mixed liquid extracting unit 5 and the density measuring unit 6 as described above.
- the mixed liquid extraction unit 5 includes an orifice 1 2, a communication pipe 1 3, a gas / liquid extraction tank 1 4, a gas / liquid discharge pipe 1 5, a gas discharge pipe 1 6, and a liquid storage tank 1 7
- the liquid flow control valves 1 8 and 1 9 are provided.
- the density measuring unit 6 includes a mixed liquid introducing pipe 20, a density measuring part main body 2 1, and a gas-liquid return pipe 2 2.
- the mixed liquid density measuring unit 2 is configured by connecting the mixed liquid extracting unit 5 and the density measuring unit 6 and has a structure that can be attached to and detached from the pipeline (main pipe) 23.
- Peline (main pipe) 2 3 has a structure that can be separated into, for example, a mixed liquid density measuring unit 2 and a gas-liquid two-phase flow rate measuring unit 3).
- the measurement value obtained by the density measuring unit 6 is taken into the respective phase flow rate calculating unit 4.
- the orifice 1 2 is a differential pressure generating device and is attached to the pipeline (main pipe) 2 3.
- a three-phase flow flows through the pipeline (main pipe) 2 3.
- a three-phase flow consists of a gas (gas) and two types of liquids (eg oil and water). This three-phase flow
- the gas-liquid two-phase flow in is not particularly limited, but in this embodiment, slag flow, bubble flow or spiral flow is assumed.
- Figure 3 shows these flow patterns.
- Figure 3 (a) is a stratified flow, (b) is a wavy flow, (c) is an annular flow, (d) is a bubble or spiral flow, (e) is a slag flow, and (f) is different from (c)
- the annular flow (g) is a bubbling flow, (h) is an annular spray flow, and the flow state of the pipeline is generally (d) or (c) in many cases.
- the slag flow has a liquid phase containing bubbles and a phase in which the gas and liquid are separated into upper and lower layers, and these two phases appear alternately. It has become a flow.
- the differential pressure ⁇ P generated when such a slag flow passes through the orifice 12 is larger in the former phase and smaller in the latter phase.
- the differential pressure ⁇ P around the orifice 12 greatly changes periodically due to the slag flow.
- the differential pressure ⁇ P around the orifice 12 is likely to change significantly in a short time (about 3 seconds, but not limited to this time).
- the communication pipe 1 3 is a pipe that is connected to the pipeline (main pipe) 2 3 and allows a part of the three-phase flow to flow, and one end is connected to the upstream side of the orifice 1 2. It consists of a pipe 1 3 a and a gas-liquid extraction pipe or gas-liquid discharge pipe 1 3 b connected to the downstream side of the orifice 1 2
- the communication pipe 1 3 is composed of a gas-liquid extraction pipe or a gas-liquid discharge pipe 1 3 a, 1 3 b, and is paired. In the figure, the communication pipe 1 3 is parallel to a predetermined length.
- Pipeline (main pipe) 2 3 Is formed.
- a valve 24 is provided in the middle of each pair of communication pipes 13 (gas-liquid extraction pipes or gas-liquid discharge pipes 13a, 13b) so that the opening / closing of the valve 24 is automatically controlled. In this way, measurement can be performed at any time zone. In this embodiment, it is assumed that the valve 24 is fully open and measurement is continued while a three-phase flow is flowing in the pipeline (main pipe) 23.
- the gas-liquid extraction tank 14 is a container having an internal space having a desired volume (for example, about 1 L: hereinafter, “LJ” is used to mean “liter”), and a pair of communication pipes 1 3 (gas-liquid The other ends of the extraction pipe or gas-liquid discharge pipe 1 3 a, 1 3 b) are connected in Fig. 2 and Fig. 4 (Fig. 4 is schematically shown).
- LJ liquid
- Fig. 4 Fig. 4 is schematically shown.
- the stirring flow 2 5 generated in the gas-liquid extraction tank 1 4 are combined to grow into large bubbles, and gas separation is promoted and bubbles are collected in the upper part of the gas-liquid extraction tank 14, and the gas-liquid extraction pipe on the downstream side in the state accompanied by the liquid or Gas-liquid discharge pipe 1 3 Press into b to cause discharge to pipeline (main pipe) 2 3.
- the gas-liquid extraction pipe or gas-liquid discharge pipe 1 3 b on the downstream side mainly discharges the gas accompanied by liquid, but due to the fluctuation of the differential pressure ⁇ P around the orifice 1 2, the orifice 1 When the pressure in the downstream side of 2 is high, the gas-liquid extraction tank 1 4 When the pressure in the 4 pressure drops, the gas-liquid extraction pipe or gas-liquid discharge pipe 1 3 b on the downstream side The liquid is sent out and the whole A small stirring stream 26 is formed locally with respect to the stirring stream 25. The small stirring stream 26 contributes to the separation of the gas, as does the overall stirring stream 25.
- the discharge destination in this embodiment is a later-described cross valve 41 provided in the gas-liquid return pipe 22 of the density measuring unit 6 (assumed as an example).
- the mixed liquid extraction pipe 28 is a pipe having a diameter of about 40 mm and standing upright below the gas-liquid extraction tank 14, and is formed to have a length of about 10 O mm, for example. .
- the mixed liquid extraction pipe 28 is provided with a structure 29 in which narrow pipes are bundled, which is about 2 Z 3 in the length direction.
- the structure 29 in which the thin tubes are bundled is bundled so that the thin tubes are circumscribed, for example, with the inner diameter of the thin tubes being about 2 mm.
- the structure 29 in which the thin tubes are bundled is combined in a cylindrical shape (columnar shape) so that it can be inserted and installed in the mixed liquid discharge pipe 28 (the diameter of the mixed liquid discharge pipe 28) Is set to 40 mm, the number of tubules is about 90).
- the structure 2 9 in which the thin tubes are bundled is provided to prevent bubbles in the gas-liquid extraction tank 14 from flowing into the liquid reservoir tank 1 7 (bubbles into the liquid reservoir tank 17). Installation is not necessary if it does not flow In this form, it is installed as a safety measure. The rate is low).
- the portion of the mixed liquid discharge pipe 28 has a function as a filter.
- the above-mentioned narrow tube can be replaced with a plate with small holes.
- the liquid flow rate control valve 18 is provided in the middle of the connecting pipe 30 that connects the gas-liquid extraction tank 14 and the liquid reservoir tank 17.
- the opening of the liquid flow control valve 18 is adjusted so that, for example, the flow rate of the mixed liquid is about 2 to 6 L / min.
- the liquid flow rate control valve 18 is provided to supply an appropriate amount of the mixed liquid to the liquid storage tank 17.
- the liquid storage tank 17 is formed as a container for temporarily storing the mixed liquid (the volume is set to 0.5 L, for example).
- the liquid storage tank 17 has a structure in which the mixed liquid stays, for example, for about 1 minute.
- Reservoir tank 17 is designed to allow gas and bubbles to pass through valve 3 1 and gas discharge pipe 16 in cases where the internal gas cannot be completely removed or the mixed liquid contains extremely small bubbles. As a result, it can be discharged to a cross valve 4 1 described later.
- the liquid storage tank 17 has a structure that can take in and store at least the mixed liquid for density measurement required by the density measuring section 6.
- the liquid flow rate control valve 19 is provided in the middle of the connecting pipe 32 connecting the liquid reservoir tank 17 and the mixed liquid introducing pipe 20 of the density measuring unit 6.
- the opening of the liquid flow rate adjusting valve 19 is adjusted so that the flow rate of the mixed liquid becomes an appropriate amount.
- the opening degree is adjusted so that the time required to pass through a later-described corriometer 38 in the density measuring unit main body 21 of the density measuring unit 6 is, for example, about 10 to 30 seconds. (When using a Coriolis meter 3 8 with a diameter of 25 mm, it is about 0.5 to 1.5 LZ min).
- the mixed liquid for example, oil / water
- valve 3 3 and the discharge valve 3 4 are provided. Further, a valve 36 is also provided in the sub-bypass pipe 35 having one end connected to the mixed liquid introduction pipe 20 to bypass the density measuring unit main body 21 and the other end connected to the gas-liquid return pipe 22. .
- valve 3 3 is fully open, and discharge valve 3 4 and valve 3 6 are fully closed.
- the valve 33 is provided on the density measuring unit main body 2 1 side.
- the density measuring unit main body 21 includes a homogenizer 3 7, a collimator 3 8, and a mixed liquid return pipe 3 9. It is configured.
- the homogenizer 37 is provided to homogenize the mixed liquid and make the mixed liquid uniform.
- the homogenizer 37 is provided upstream of the collimator 38.
- the homogenizer 3 7 is provided in the vicinity of the Coriolis meter 3 8 to make the measurement of the mixing density by the Coriolis meter 3 8 more reliable.
- the Coriolis meter 38 should have a configuration capable of measuring density in a known Coriolis mass flowmeter (or a device capable of measuring density on the same principle as this is acceptable).
- a known Coriolis mass flow meter is used as the Coriolis meter 3 8.
- the Coriolis meter 3 8 does not depend on the flow rate of the mixed liquid (the measurement is performed by vibrating the mixed liquid filled in the built-in tube), so it can be measured at a low flow rate. .
- the gas-liquid return pipe 2 2 is provided with a valve 40, a cross valve 4 1, and a check valve 4 2 in order from the Coriolis meter 3 8 side. Valve 40 is fully open. As the cross valve 4 1 and the check valve 4 2, known ones are used, and the explanation of the operation and the like is omitted.
- the gas-liquid return pipe 2 2 is connected to the pipeline (main pipe) 2 3 on the downstream side of the orifice 1 2 of the mixed liquid extraction part 5 (reference numeral 4 3 indicates the joining part).
- the gas-liquid two-phase flow rate measuring unit 3 includes the homogenizer 7, the turbine meter 8, the differential pressure gauge 9, the pressure gauge 10 and the thermometer 11. It is prepared for.
- the gas-liquid two-phase flow rate measuring unit 3 having such a configuration is the same as the turbine-type flow meter disclosed in Patent Document 3 in the background art column (Japanese Patent Laid-Open No. Hei 8-2-1001). Therefore, the specific description of the configuration is omitted here (the measurement method will be described later).
- the gas-liquid two-phase flow rate measuring unit 3 may be configured to include a volumetric flow meter 4 4, a bench lily tube 4 5, a differential pressure meter 4 6, etc. as shown in FIG.
- the turbine-type flow meter is used in this embodiment (not limited to the turbine-type flow meter in the above publication) is that the turbine-type flow meter maintains the gas-liquid two-phase flow in a mixed phase state, and the total volume. This is because the flow rate and the gas-liquid volume flow rate ratio can be obtained efficiently at the same time.
- the turbine type flow meter is excellent in cost and handling (in addition to using general industrial instruments, adapting only to the flange standards for high pressure specifications such as oil fields, etc.) Has strength).
- each phase flow rate calculation unit 4 takes in the measurement value obtained by the gas-liquid two-phase flow rate measurement unit 3 and the measurement value obtained by the mixed liquid density measurement unit 2 to obtain a three-phase flow (for example, It has a configuration that can calculate the flow rate of each phase (gas, oil, water).
- Each phase flow rate calculation unit 4 can be configured, for example, as a part of a control device (not shown) or as a combination of the calculation parts of the gas-liquid two-phase flow rate measurement unit 3 and the corriometer 38. Assuming that it is possible, the flow rate of each phase is calculated by functions such as a microcomputer.
- Each phase flow rate calculation unit 4 calculates a mixing ratio of the mixed liquid from the mixed liquid density, and calculates each flow rate of the mixed liquid from the mixing ratio and the mixed liquid flow rate.
- the gas-liquid in the mixed phase is homogenized like a single fluid by the homogenizer 7 installed on the upstream side and flows into the turbine rotor of the turbine meter 8. Since the density of the mixed fluid is homogenized by the homogenizer 7, the momentum of the mixed fluid acting on the turbine bin rotor is constant in the rotor radial direction. It becomes. The turbine rotor rotates efficiently.
- the differential pressure ⁇ P generated before and after the homogenizer 7 depends on the gas-liquid flow rate QM and the ratio of the gas flow rate QG to this QM (gas void ratio) 3).
- the mixed liquid is considered as an oil / water mixture. Also, it is assumed that the density of oil and water in each single phase is known.
- Water content ⁇ (mixed density of oil / water / density of oil) / (density of water / density of oil).
- the expression of the moisture content ⁇ will be specifically described. If the water flow rate is QW, the oil flow rate is QO, the combined flow rate of water and oil is QL, the water density is p W, the oil density is ⁇ , and the combined density of water and oil is PL, then oil And the mass flow rate of water and water and the total mass flow rate of oil water are equal, so the following equation (1) is obtained.
- the oil flow rate QO and the water flow rate QW are finally calculated with high accuracy.
- a pair of communication pipes 1 3 gas-liquid extraction pipes or gas-liquid discharge pipes 1 3 a and 1 3 b connected to the upstream and downstream of the orifice 1 2 by bypass, and gas-liquid Extraction tanks 1 and 4 are used.
- the pressure difference around the orifice 12 changes periodically.
- the pair of communication pipes 13 gas-liquid extraction pipes or gas-liquid discharge pipes 13a, 13b
- gas-liquid extraction tank 14 gas-liquid extraction and gas-based exhaust (Pipeline (main pipe) 2 3 discharge).
- the gas-liquid is forcibly shaken and stirred left and right and up and down, and the gas with liquid is discharged.
- the gas-liquid extraction tank 14 As a result, a gas-liquid with a high liquid phase ratio remains in the gas-liquid extraction tank 14. Then, the gas is removed from the gas-liquid having a high liquid phase ratio, and the mixed liquid is extracted and accumulated in the liquid storage tank 17. The necessary amount of mixed liquid flows from the liquid tank 1 7 using the Coriolis meter 3 8, and the density of the mixed liquid is homogenized using the homogenizer 3 7. As a result, the Coriolis meter 3 8 provides high-precision density measurement. Done.
- the test specification includes a pipeline including turbine meter 8
- Fig. 6 is a graph showing the measurement results of oil / water density in the oil / water atmosphere using the Coriolis meter 38. ⁇ 3 Kg / m 3 in the graph indicates the density measurement accuracy. Equivalent to just over 0.3%. In general, the conventional multiphase flow rate system requires a density measurement accuracy higher than ⁇ 0.5%, which means that the present invention has obtained good results.
- Fig. 7 is a graph showing the measurement results of the moisture content (water Z oil) in oil and water using Coriolis meter 38, and the measurement accuracy of moisture content ⁇ is as good as ⁇ 2.5%. That's right.
- the density measurement accuracy is ⁇ 0.5%, which is close to seven times ⁇ 2.5%, which is theoretically consistent.
- the present invention has an effect that it is possible to provide the multiphase flow meter 1 capable of measuring the flow rate with high accuracy.
- FIG. 8 is a configuration diagram of a multi-phase flow meter showing an embodiment of the present invention
- FIG. 9 is a configuration diagram of a mixed liquid density measuring unit
- FIG. 10 is an explanatory diagram showing a state in a gas-liquid extraction tank . Note that the same reference numerals are given to basically the same components as those described above, and the description thereof will be omitted.
- a multiphase flow meter 1 ′ includes a mixed liquid density measurement unit 2 ′, a gas-liquid two-phase flow measurement unit 3, and each phase flow rate calculation unit 4. It is configured to include.
- Mixed liquid density measuring unit 2 ' A mixed liquid extraction unit 5 ′ and a density measurement unit 6 are provided.
- the mixed liquid extraction section 5 ′ includes an orifice 1 2, a pair of communication pipes 1 3 (gas-liquid extraction pipes or gas-liquid discharge pipes 1 3 a and 1 3 b), a gas-liquid extraction tank 1 4, and a gas-liquid discharge It has a pipe 15, a gas discharge pipe 16, a liquid reservoir tank 17, a liquid flow rate control valve 19, and a pair of communication pipes 5 1.
- the mixed liquid extraction unit 5 ′ differs from the mixed liquid extraction unit 5 of the above-described form only in the connection method of the gas-liquid extraction tank 14 and the liquid storage tank 17. That is, a gas-liquid extraction tank 14 and a liquid tank 1 7 are paired in place of the mixed liquid outlet pipe 28, connecting pipe 30 and liquid flow rate control valve 18 existing in FIGS. It is drowned in the communication pipe 5 1.
- the mixed liquid extraction section 5 ′ there is gas-liquid extraction and liquid generated in a pair of communication pipes 1 3 (gas-liquid extraction pipes or gas-liquid discharge pipes 1 3 a, 1 3 b) and gas-liquid extraction tanks 14. The purpose is to perform gas-based exhaust in multiple stages.
- the mixed liquid extraction section 5 ′ has a plurality of stages of a pair of communication pipes and tanks (the pair of communication pipes 5 1 and the liquid reservoir tank 17 in the figure is the second stage.
- the mixture liquid that has achieved the separation of small bubbles can be sent to the density measuring unit 6 (because the basic operation and effect are the same as those described above). Explanation is omitted.)
- the mixed density measuring unit 2 (mixed density measuring unit 2 ′) may be arranged downstream of the gas-liquid two-phase flow rate measuring unit 3.
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- Physics & Mathematics (AREA)
- Fluid Mechanics (AREA)
- General Physics & Mathematics (AREA)
- Measuring Volume Flow (AREA)
Description
Claims
Priority Applications (3)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US12/309,349 US7827869B2 (en) | 2006-10-27 | 2007-08-07 | Multiphase flowmeter for measuring each phase flow rate of a three-phase flow consisting of gas and two kinds of liquid |
CN2007800398731A CN101529215B (zh) | 2006-10-27 | 2007-08-07 | 多相流量计 |
EP07792439A EP2077440A1 (en) | 2006-10-27 | 2007-08-07 | Multi-phase flowmeter |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
JP2006-292835 | 2006-10-27 | ||
JP2006292835A JP4137153B2 (ja) | 2006-10-27 | 2006-10-27 | 多相流量計 |
Publications (1)
Publication Number | Publication Date |
---|---|
WO2008050522A1 true WO2008050522A1 (fr) | 2008-05-02 |
Family
ID=39324333
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/JP2007/065796 WO2008050522A1 (fr) | 2006-10-27 | 2007-08-07 | Débitmètre multiphasique |
Country Status (6)
Country | Link |
---|---|
US (1) | US7827869B2 (ja) |
EP (1) | EP2077440A1 (ja) |
JP (1) | JP4137153B2 (ja) |
CN (1) | CN101529215B (ja) |
RU (1) | RU2428662C2 (ja) |
WO (1) | WO2008050522A1 (ja) |
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RU2505790C1 (ru) * | 2012-06-29 | 2014-01-27 | Федеральное государственное унитарное предприятие Всероссийский научно-исследовательский институт расходометрии (ФГУП ВНИИР) | Устройство воспроизведения расходов газожидкостных потоков |
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Also Published As
Publication number | Publication date |
---|---|
RU2009120017A (ru) | 2010-12-10 |
US20090199653A1 (en) | 2009-08-13 |
CN101529215A (zh) | 2009-09-09 |
US7827869B2 (en) | 2010-11-09 |
CN101529215B (zh) | 2011-09-07 |
JP4137153B2 (ja) | 2008-08-20 |
RU2428662C2 (ru) | 2011-09-10 |
JP2008107298A (ja) | 2008-05-08 |
EP2077440A1 (en) | 2009-07-08 |
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