An asymmetric herringbone two-phase metering system and method

Abstract

The present application provides an asymmetric H-shaped two-phase metering system, which comprises: an asymmetric H-shaped device with an inlet end higher than an outlet end for realizing gas-liquid separation; a data acquisition and detection module arranged on the asymmetric H-shaped device for acquiring cyclone signal, water cut data, pressure difference data, gas data and liquid data; a metering module in communication with the asymmetric H-shaped device and the detection module for realizing online real-time metering of gas-liquid two-phase according to flow state combined with gas volume calculation model and / or gas-liquid two-phase calculation model. The present application realizes secondary separation metering of gas-liquid by using simple "H-shaped" structure, and has advantages of simple structure, low cost, small occupation, wide application range and the like. A multi-condition gas and liquid multi-factor comprehensive identification method of cyclone signal, pressure difference and water cut is proposed, which improves the accuracy of fluid determination. The signals of various sensors are used to respectively solve, correct and calculate the two-phase flow, which improves the accuracy of flow determination.

Description

TECHNICAL FIELD

[0001] The present application relates to the technical field of oil and gas production and transportation, in particular to an asymmetrically shaped two-phase metering system and method. BACKGROUND

[0002] Wellhead metering is one of the important technical problems in the field of natural gas production. Real-time monitoring of gas well production rate, liquid production rate and other production data is important dynamic data for gas reservoir development, and is an important basis for development geology analysis and development of and optimization of production decisions. The most mature method for natural gas single well metering is to separate each phase with a separator and then meter each phase separately. The gas phase metering accuracy is high, but the production process is complex and the equipment is large.

[0003] In recent years, in order to simplify the station and reduce investment, many gas fields use gas-liquid mixed transportation mode, which cannot meet the demand for high-precision separation metering. Therefore, how to realize low-cost and online real-time metering of gas and liquid two-phase flow without separation is the direction of technical development. At present, the general solution to two-phase flow metering is "gas-liquid rough separation and phase metering and then mixing" or "calculating by measuring components and pressure difference", but in the process, the separation process is long and the equipment is large, and it is difficult to determine whether the single-factor identification and determination of the flow pattern and the correction model are consistent with the total liquid-gas ratio. Therefore, how to realize two-phase flow metering without separation, miniaturization and low cost is still a major technical problem in the industry. The related patents of the prior art are: "A small multi-phase metering integrated device" (publication number: CN204782979U), "A multi-phase flow metering and detecting system" (publication number: CN106840294A), "A multi-phase flow metering device based on an arc-shaped pipe and a metering method" (publication number: CN103090917B).

[0004] However, the above prior art has three problems when applied to the field:

[0005] (1) The two-phase flow metering device of the gas-liquid rough separation and phase metering and then mixing mode generally includes a liquid separation tank (pressure vessel, large volume), so it occupies a large area, the process is complex and the investment is high;

[0006] (2) The two-phase flow metering device for measuring fluid components by radiation includes radioactive elements, which poses a safety and environmental risk;

[0007] (3) The single pressure difference method for identifying two-phase flow has limitations and low compliance rate for some liquid-gas ratios (especially in the case of intermittent water discharge and slug flow).

[0008] For the above situations, the prior art has not yet found a good solution. Therefore, the present application provides an asymmetrically shaped two-phase metering system and method. SUMMARY

[0009] To solve the above problems, the application provides an asymmetric H-shaped two-phase metering system, which comprises:

[0010] The asymmetric H-shaped device is used for realizing gas-liquid separation, with the inlet end being higher than the outlet end.

[0011] The data acquisition and detection module is arranged on the asymmetric H-shaped device and is used for acquiring the cyclone signal, the water cut data, the pressure difference data, the gas data and the liquid data.

[0012] The metering module communicates with the asymmetric H-shaped device and the detection module, and is used for realizing online real-time metering of the gas-liquid two-phase according to the flow state and combining the gas volume calculation model and / or the gas-liquid two-phase calculation model.

[0013] According to an embodiment of the application, the asymmetric H-shaped device comprises:

[0014] The first variable-diameter pipe section comprises a first transverse pipe section and a second longitudinal pipe section, which are combined into a shape of and are used for realizing primary gas-liquid separation.

[0015] The second variable-diameter pipe section comprises a third transverse pipe section and a fourth longitudinal pipe section, which are combined into a shape of and the fourth longitudinal pipe section is used for realizing secondary gas-liquid separation.

[0016] The third variable-diameter pipe section comprises a fifth longitudinal pipe section and a sixth transverse pipe section, which are combined into a shape of .

[0017] The upper transverse straight pipe section has a first end connected with a first end of the fourth longitudinal pipe section and a second end connected with a first end of the fifth longitudinal pipe section.

[0018] The lower transverse primary variable-diameter pipe section has a first end connected with a second end of the fourth longitudinal pipe section and a second end connected with a second end of the fifth longitudinal pipe section.

[0019] The first end of the third transverse pipe section is the inlet end, the second end of the third transverse pipe section is connected with the fourth longitudinal pipe section, the second end of the sixth transverse pipe section is the outlet end, and the first end of the sixth transverse pipe section is connected with the fifth longitudinal pipe section.

[0020] According to an embodiment of the application, the data acquisition and detection module comprises:

[0021] The gas flowmeter is arranged on the upper transverse straight pipe section and is used for measuring the gas data.

[0022] The liquid flowmeter is arranged on the lower transverse primary variable-diameter pipe section and is used for measuring the liquid data.

[0023] According to an embodiment of the present application, the data acquisition and detection module comprises:

[0024] a swirl measurement module arranged upstream of the gas flow meter for measuring the swirl signal;

[0025] a water cut detection module arranged upstream of the liquid flow meter for measuring the water cut data.

[0026] According to an embodiment of the present application, the data acquisition and detection module comprises:

[0027] a first differential pressure transmitter arranged upstream of the swirl measurement module for detecting a first pressure value at an upstream position;

[0028] a second differential pressure transmitter arranged upstream of the water cut detection module for detecting a second pressure value at an upstream position;

[0029] a differential pressure generation unit in communication with the first differential pressure transmitter and the second differential pressure transmitter for calculating the differential pressure data based on the first pressure value and the second pressure value.

[0030] According to an embodiment of the present application, the metering module comprises:

[0031] a flow regime analysis module for determining a flow regime based on the swirl signal, the water cut data and the differential pressure data, wherein:

[0032] when the swirl signal is greater than a preset swirl value and the differential pressure data is greater than a preset differential pressure value, the flow regime is determined to be gas-liquid two-phase, otherwise, the flow regime is determined to be single gas phase;

[0033] when the water cut data is greater than a preset water cut value, the flow regime is determined to be single liquid phase.

[0034] According to an embodiment of the present application, the gas volume calculation model comprises the following formula:

[0035]

[0036] wherein, V gn represents the gas flow at the nth moment, F Z represents the super compression factor, P gn represents the gauge pressure of the gas flow meter at the nth moment, P a represents the local atmospheric pressure, P n represents the standard atmospheric pressure, T n represents the absolute temperature at the nth moment under standard state, T gn represents the absolute temperature of the gas at the nth moment, Q g represents the gas flow measurement value, and t0 represents the measurement frequency.

[0037] According to one embodiment of the present application, the gas-liquid two-phase integration model comprises the following formula:

[0038]

[0039] wherein, V gm represents the gas flow rate at the mth moment, k0 represents the swirl coefficient in the whole gas, k m represents the swirl coefficient at the mth moment, F Z represents the super compression factor, P gm represents the gage pressure of the gas flow meter at the mth moment, P a represents the local atmospheric pressure, P n represents the standard atmospheric pressure, T m represents the absolute temperature at the mth moment under the standard state, T gm represents the absolute temperature of the gas at the mth moment, Q g represents the gas flow measurement value, t0 represents the measurement frequency.

[0040] According to one embodiment of the present application, the liquid flow rate at each moment is calculated by the following formula:

[0041]

[0042] wherein, V ln represents the liquid flow rate at the nth moment, D represents the inner diameter of the liquid flow meter, E represents the induced electromotive force of the liquid flow meter, t0 represents the measurement frequency, K represents the calculation coefficient, and B represents the magnetic induction intensity of the liquid flow meter.

[0043] According to another aspect of the present application, an asymmetrically-shaped U-bend two-phase metering method is also provided, which realizes online real-time metering of gas-liquid two-phase by the asymmetrically-shaped U-bend two-phase metering system according to any one of the above, and the method comprises:

[0044] realizing gas-liquid separation by the asymmetrically-shaped U-bend device with the inlet end position higher than the outlet end;

[0045] collecting swirl signals, water content data, pressure difference data, gas data and liquid data by the data acquisition and detection module arranged on the asymmetrically-shaped U-bend device;

[0046] realizing online real-time metering of gas-liquid two-phase by the metering module in communication with the asymmetrically-shaped U-bend device and the detection module according to the flow state in combination with the gas volumetric calculation model and / or the gas-liquid two-phase integration model.

[0047] Compared with the existing two-phase flow meters and methods, the present application has the following advantages:

[0048] 1) Put forward a new idea, using simple "hui" structure to realize gas-liquid secondary separation metering, with simple structure, low cost, small occupation, wide application range and other advantages.

[0049] 2) Put forward the cyclone signal, differential pressure and water content multi-condition gas, liquid multi-factor comprehensive identification method, improve the accuracy of fluid determination.

[0050] 3) Using the signal of each sensor to solve and correct the two-phase flow respectively, improve the accuracy of flow measurement.

[0051] 4) Each sensor is designed as a standardized module, so that its position on the metering device can be adjusted according to the needs.

[0052] Other features and advantages of the present application will be set forth in the following description, and in part will become apparent from the description, or can be learned by practice of the present application. The objects and other advantages of the present application can be achieved and obtained by the structure particularly pointed out in the specification, claims and drawings. BRIEF DESCRIPTION OF DRAWINGS

[0053] The accompanying drawings are included to provide a further understanding of the present application, and constitute a part of the specification, illustrate the embodiments of the present application, and are used to explain the present application together with the embodiments of the present application, and do not constitute a limitation on the present application. In the drawings:

[0054] Figure 1 The asymmetric hui-shaped two-phase metering system according to an embodiment of the present application is shown.

[0055] Figure 2 The asymmetric hui-shaped two-phase metering system according to an embodiment of the present application is shown. The asymmetric hui-shaped two-phase metering system provided by the present application comprises an asymmetric hui-shaped device, a data acquisition and detection module and a metering module.

[0056] Figure 3 The asymmetric hui-shaped two-phase metering system according to an embodiment of the present application is shown. The asymmetric hui-shaped two-phase metering system provided by the present application comprises an asymmetric hui-shaped device, a data acquisition and detection module and a metering module. DETAILED DESCRIPTION

[0057] In order to make the purpose, technical scheme and advantages of the present application more clear, the following will be further detailed according to the embodiments of the present application combined with the drawings.

[0058] Figure 1 The asymmetric hui-shaped two-phase metering system according to an embodiment of the present application is shown. The asymmetric hui-shaped two-phase metering system provided by the present application comprises an asymmetric hui-shaped device, a data acquisition and detection module and a metering module.

[0059] Specifically, the asymmetrically shaped device has an inlet end higher than an outlet end for realizing gas-liquid separation; the data acquisition and detection module is arranged on the asymmetrically shaped device for acquiring cyclone signal, water cut data, differential pressure data, gas data and liquid data; the metering module communicates with the asymmetrically shaped device and the detection module, and realizes online real-time metering of gas-liquid two-phase flow according to flow state and combining with gas volume calculation model and / or gas-liquid two-phase calculation model.

[0060] Further, as shown in Figure 1 , the asymmetrically shaped device comprises a first variable diameter pipe segment 2, a second variable diameter pipe segment 1, a third variable diameter pipe segment 12, an upper horizontal straight pipe segment 3 and a lower horizontal primary variable diameter pipe segment 8.

[0061] The first variable diameter pipe segment 2 comprises a first horizontal pipe segment and a second vertical pipe segment forming an inverted shape, for realizing primary gas-liquid separation; the second variable diameter pipe segment 1 comprises a third horizontal pipe segment and a fourth vertical pipe segment forming a shape, the fourth vertical pipe segment for realizing secondary gas-liquid separation; the third variable diameter pipe segment 12 comprises a fifth vertical pipe segment 11 and a sixth horizontal pipe segment forming a shape; the upper horizontal straight pipe segment 3 has a first end connected with the first end of the fourth vertical pipe segment and a second end connected with the first end of the fifth vertical pipe segment; the lower horizontal primary variable diameter pipe segment 8 has a first end connected with the second end of the fourth vertical pipe segment and a second end connected with the second end of the fifth vertical pipe segment.

[0062] The first end of the third horizontal pipe segment is an inlet end, the second end of the third horizontal pipe segment is connected with the fourth vertical pipe segment, the second end of the sixth horizontal pipe segment is an outlet end, and the first end of the sixth horizontal pipe segment is connected with the fifth vertical pipe segment.

[0063] As shown in Figure 1 , the connection relationship of each pipe segment of the asymmetrically shaped device is as follows: the second variable diameter pipe segment 1 and the first variable diameter pipe segment 2 are connected through a variable diameter tee; the second variable diameter pipe segment 1 and the upper horizontal straight pipe segment 3 are connected through an elbow; the third variable diameter pipe segment 12 and the upper horizontal straight pipe segment 3 are connected through an elbow; the second variable diameter pipe segment 1 and the lower horizontal primary variable diameter pipe segment 8 are connected through an elbow; and the third variable diameter pipe segment 12 and the lower horizontal primary variable diameter pipe segment 8 are connected through a variable diameter tee.

[0064] The first variable diameter pipe segment 2 is a small diameter pipe segment (a small diameter is adopted to pre-separate gas-liquid two-phase flow) of an inverted shape, for realizing primary gas-liquid separation (the fifth vertical pipe segment 11 is thick at the top and thin at the bottom, to avoid liquid upflow or gas downflow) in a large diameter pipeline (the fifth vertical pipe segment 11); the second variable diameter pipe segment 1 is a "U" variable-diameter riser section, the vertical pipeline (fourth longitudinal pipe section) is used for secondary gas-liquid separation (the upper part of the fourth longitudinal pipe section is wider than the lower part to perform secondary separation, and gas-liquid separation is performed) "U" variable-diameter riser section, the vertical pipeline (fourth longitudinal pipe section) is used for secondary gas-liquid separation (the upper part of the fourth longitudinal pipe section is wider than the lower part to perform secondary separation, and gas-liquid separation is performed) "U" variable-diameter riser section, the vertical pipeline (fourth longitudinal pipe section) is used for secondary gas-liquid separation (the upper part of the fourth longitudinal pipe section is wider than the lower part to perform secondary separation, and gas-liquid separation is performed) "U" variable-diameter riser section, the vertical pipeline (fourth longitudinal pipe section) is used for secondary gas-liquid separation (the upper part of the fourth longitudinal pipe section is wider than the lower part to perform secondary separation, and gas-liquid separation is performed)

[0065] Further, as shown in Figure 1 The data acquisition and detection module includes the gas flow meter 6, the liquid flow meter 10, the swirl determination module 5, the water cut detection module 9, the first differential pressure transmitter 4, the second differential pressure transmitter 7, and the differential pressure generation unit 13.

[0066] The gas flow meter 6 is arranged on the upper horizontal straight pipe section 3 and is used to measure gas data, and a pressure and temperature taking module is arranged in the middle of the gas flow meter 6. The liquid flow meter 10 is arranged on the lower horizontal primary variable-diameter pipe section 8 and is used to measure liquid data, and a pressure and temperature taking module is arranged in the liquid flow meter 10.

[0067] The swirl determination module 5 is arranged upstream of the gas flow meter 6 and is used to measure a swirl signal. The water cut detection module 9 is arranged upstream of the liquid flow meter 10 and is used to measure water cut data.

[0068] The first differential pressure transmitter 4 is arranged upstream of the swirl determination module 5 and is used to detect a first pressure value at the upstream position. The second differential pressure transmitter 7 is arranged upstream of the water cut detection module 9 and is used to detect a second pressure value at the upstream position. The differential pressure generation unit 13 communicates with the first differential pressure transmitter 4 and the second differential pressure transmitter 7 and is used to calculate differential pressure data based on the first pressure value and the second pressure value.

[0069] The first differential pressure transmitter 4 and the second differential pressure transmitter 7 are used to determine the difference between the differential pressure of the fluid and the single gas phase / single liquid phase, and to review and correct the flow state determined by the swirl determination module 5 and the water cut detection module 9.

[0070] Further, as shown in Figure 1As shown, the metering module comprises a data acquisition and processing unit 14. The data acquisition and processing unit 14 is electrically connected with the gas flow meter 6, the liquid flow meter 10, the cyclone measurement module 5, the water cut detection module 9 and the differential pressure generation unit 13 through signal lines, for collecting, processing, correcting and accumulating data of each functional module.

[0071] The data acquisition and processing unit 14 comprises a flow state analysis module for determining the flow state according to the cyclone signal, the water cut data and the differential pressure data, wherein: when the cyclone signal is greater than a preset cyclone value and the differential pressure data is greater than a preset differential pressure value, it is determined that the flow state is gas-liquid two-phase, otherwise it is determined that the flow state is single gas phase; when the water cut data is greater than a preset water cut value, it is determined that the flow state is single liquid phase.

[0072] The present application is suitable for online real-time metering of gas-liquid two-phase without separation of produced fluid of oil and gas wells (especially suitable for full-range liquid-gas ratio and slug flow), which utilizes the upper and lower liquid separation of the asymmetric H-shaped variable-diameter pipeline, utilizes the cyclone signal, the differential pressure and the water cut for comprehensive identification of multiple conditions of gas and gas-liquid mixture, and performs gas and liquid accumulation, comparison and correction through a data processing and processing system. Real-time metering of two-phase fluid medium in horizontal and vertical pipelines in industrial sites can be realized.

[0073] Figure 2 A working principle diagram of an asymmetric H-shaped two-phase metering system according to an embodiment of the present application is shown.

[0074] As shown, Figure 2 The flow state analysis module determines the flow state based on the cyclone signal measurement value and the differential pressure data, and when the cyclone signal is greater than a preset cyclone value and the differential pressure data is greater than a preset differential pressure value, it is determined that the flow state is gas-liquid two-phase, otherwise it is determined that the flow state is single gas phase. The single gas phase is calculated by a gas accumulation model, and the gas-liquid two-phase is calculated by a gas-liquid two-phase accumulation model. If the water cut is greater than or equal to a preset water cut value, the liquid accumulation model is used for calculation.

[0075] It should be noted that in the present embodiment, the preset cyclone value is 2000, the preset differential pressure value is 5889 Pa, and the preset water cut value is 98%. Other preset cyclone values and preset differential pressure values that can determine the flow state can also be applied to the present application, and the present application does not limit the specific values of the preset cyclone value and the preset differential pressure value.

[0076] Further, the gas accumulation model comprises the following formula:

[0077]

[0078] wherein, V gn represents the gas flow at the nth moment, F Z represents the supercompression factor, P gn represents the gage pressure of the gas flow meter at the nth moment, Pa represents local atmospheric pressure, P n represents standard atmospheric pressure, T n represents absolute temperature under standard state at the nth moment, T gn represents absolute temperature of the gas at the nth moment, Q g represents gas flow measurement value, t0represents measurement frequency.

[0079] Further, the gas-liquid two-phase accumulation model calculates the gas flow at each moment under the condition of gas phase carrying a small amount of liquid phase by the following formula:

[0080]

[0081] wherein, V gm represents gas flow at the mth moment, k0represents full-gas swirl coefficient, k m represents swirl coefficient at the mth moment, F Z represents over-compression factor, P gm represents table pressure of the gas flowmeter at the mth moment, P a represents local atmospheric pressure, P n represents standard atmospheric pressure, T m represents absolute temperature under standard state at the mth moment, T gm represents absolute temperature of the gas at the mth moment, Q g represents gas flow measurement value, t0represents measurement frequency.

[0082] In one embodiment, the measurement frequency t0is preferably configured as 0.1 s. Of course, in other embodiments of the present application, the measurement frequency t0may also be configured as different reasonable values according to actual needs, and the present application does not limit the specific value of the measurement frequency t0.

[0083] In one embodiment, the over-compression factor F Z may be preferably calculated according to the following expression:

[0084]

[0085] wherein, Z n represents gas compression coefficient under standard state, Z g represents gas compression coefficient under working state.

[0086] After obtaining the pure gas flow detected at each moment, at the same time, considering the condition of gas phase carrying a small amount of liquid phase, the swirl signal is used for correction at this moment, and according to the accumulation calculation principle, the gas accumulation flow required in the period can also be obtained. That is, there is:

[0087]

[0088] V gij The gas cumulative flow of the required period, V gn The gas cumulative flow of the period containing j sampling time points, V gm The gas cumulative flow of the period containing i sampling time points under the condition of gas phase carrying a small amount of liquid phase.

[0089] In one embodiment, the liquid flow at each time point is calculated by the following formula:

[0090]

[0091] V ln The liquid flow at the nth time point, D represents the inner diameter of the liquid flowmeter, E represents the induced electromotive force of the liquid flowmeter, t0 represents the measurement frequency, K represents the calculation coefficient, and B represents the magnetic induction intensity of the liquid flowmeter.

[0092] After obtaining the liquid flow at each time point, the liquid cumulative flow of the required period under the condition of pure liquid phase can be obtained according to the accumulation calculation principle, and the liquid phase volume under the condition of gas phase carrying a small amount of liquid phase is added to obtain the total liquid phase volume flow. That is, there is:

[0093]

[0094] V lj The liquid cumulative flow of the period containing j sampling time points, V li The liquid phase volume cumulative flow of the period containing i sampling time points under the condition of gas phase carrying a small amount of liquid phase, V lij The liquid phase volume cumulative flow of the whole period.

[0095] As Figure 1 shown, the gas flowmeter 6, the liquid flowmeter 10, the cyclone determination module 5, the water content detection module 9, and the pipe section are connected by flanges. The first differential pressure transmitter 4, the cyclone determination module 5, the gas flowmeter 6, the water content detection module 9, the liquid flowmeter 10, the differential pressure generation unit 13, and the data acquisition and processing unit 14 are connected by electrical signal lines / wireless connections.

[0096] In one embodiment, the pipe section upstream of the gas flowmeter 6 is reduced in diameter at a distance greater than 10D, where D is the inner diameter of the pipeline at the downstream end of the pipe section, and the pipe section downstream of the gas flowmeter 6 is reduced in diameter at a distance greater than 5D, where D is the inner diameter of the pipeline at the upstream end of the pipe section.

[0097] where the asymmetric back-shaped device is reduced in diameter at the inlet end, the asymmetric back-shaped device is reduced in diameter at the lower transverse pipeline end, and the asymmetric back-shaped device is reduced in diameter at the outlet vertical pipeline end.

[0098] Different fluids generate different pressure drops in the diameter-changing section. This invention uses pressure measurement modules integrated in the first differential pressure transmitter 4, the second differential pressure transmitter 7, the gas flow meter 6, and the liquid flow meter 10 to measure the pressure drop before and after the diameter change in the lower transverse primary diameter-changing pipe section 8, transmitting the differential pressure data through the differential pressure generation unit 13; measuring the swirling signal generated by the forced rotation of the fluid at the gas flow meter 6 through the swirling flow measurement module 5; measuring the water content of the fluid at the inlet of the liquid flow meter 10 through the water content detection module 9; and finally, using the data acquisition and processing unit 14 to comprehensively determine, select, and calibrate an accurate measurement model.

[0099] Figure 3 A flowchart of an asymmetric two-phase metering method according to an embodiment of the present invention is shown.

[0100] like Figure 3 As shown, in step S301, gas-liquid separation is achieved through an asymmetric U-shaped device with the inlet end positioned higher than the outlet end. The asymmetric U-shaped device performs secondary gas-liquid separation, resulting in a fluid with a liquid volume ratio greater than 98%.

[0101] like Figure 3 As shown, in step S302, the data acquisition and detection module installed on the asymmetric U-shaped device collects swirling signals, water content data, pressure difference data, gas data, and liquid data. Flow regime identification is then performed using the swirling signals, pressure difference data, and water content data.

[0102] like Figure 3 As shown, in step S303, the metering module, which communicates with the asymmetric U-shaped device and the detection module, achieves online real-time metering of the gas-liquid two-phase flow based on the flow regime and in conjunction with a gas volume calculation model and / or a gas-liquid two-phase integration model. The metering module performs integration and correction according to the liquid and gas flow formulas respectively, thus achieving online real-time metering of the gas-liquid two-phase flow.

[0103] This invention combines the U-tube principle with a multi-factor flow pattern identification method, utilizing sensor signals to solve, correct, and integrate the two-phase flow rates separately, thereby improving the accuracy of flow measurement. It boasts advantages such as simple structure, low cost, small footprint, and wide application range. This invention enables real-time measurement of two-phase media in horizontal and vertical pipelines in industrial settings, and simultaneously achieves online calibration of the measuring instruments through a bypass.

[0104] In summary, compared with existing two-phase flow meters and methods, the advantages of this invention are:

[0105] 1) A new approach is proposed, which uses a simple "U-shaped" structure to achieve secondary gas-liquid separation and metering. It has the advantages of simple structure, low cost, small footprint and wide application range.

[0106] 2) Put the cyclone signal, differential pressure and water content of multi-condition gas, liquid multi-factor comprehensive identification method, improve the fluid determination accurate.

[0107] 3) Using the signal of each sensor to solve and correct the two-phase flow respectively and to accumulate, improve the accuracy of flow measurement.

[0108] 4) Design each sensor as a standardized module, so that its position on the measuring device can be adjusted according to the needs.

[0109] It should be understood that the embodiments disclosed herein are not limited to the specific structure, processing steps or materials disclosed herein, but extend to equivalent alternatives of these features understood by those skilled in the relevant art. It should also be understood that the terms used herein are for the purpose of describing specific embodiments only and are not meant to be limiting.

[0110] In the description of the present application, unless otherwise specified, the meaning of "a plurality of" is two or more; the orientation or positional relationship indicated by the terms "upper", "lower", "left", "right", "inner", "outer", "front end", "rear end", "head", "tail" and the like is based on the orientation or positional relationship shown in the drawings, and is only for the purpose of facilitating the description of the present application and simplifying the description, and does not indicate or imply that the device or element referred to must have a particular orientation, be constructed and operated in a particular orientation, and therefore cannot be understood as a limitation on the present application. In addition, the terms "first", "second", "third" and the like are only for the purpose of description and cannot be understood as indicating or implying relative importance.

[0111] In the description of the present application, it should be noted that, unless otherwise specified and limited, the terms "connected", "connected" should be understood broadly, for example, it can be fixedly connected, or it can be detachably connected, or integrally connected; it can be mechanically connected, or it can be electrically connected; it can be directly connected, or it can be indirectly connected through an intermediate medium. For those skilled in the art, the specific meaning of the above terms in the present application can be understood according to the specific circumstances.

[0112] The phrase "one embodiment" or "an embodiment" appearing in the specification means that the specific features, structures or characteristics described in connection with the embodiment are included in at least one embodiment of the present application. Therefore, the phrase "one embodiment" or "an embodiment" appearing throughout the specification does not necessarily refer to the same embodiment.

[0113] Embodiments of the application are presented by way of example and description only, and are not intended to limit the application to the forms disclosed. Many modifications and variations will be apparent to those skilled in the art. Embodiments are chosen and described in order to best explain the principles of the application and its practical application, and to thereby enable others skilled in the art to best utilize the application in various embodiments and with various modifications as are suited to the particular use contemplated.

[0114] Although the present application has been disclosed with reference to the embodiments described above, it is not the intention to limit the application to what has been disclosed. Any modifications and variations that are obvious to those skilled in the art are considered to be within the scope of the present application. The scope of the patent protection is defined by the appended claims.

Claims

1. An asymmetrically shaped H-shaped two-phase metering system, characterized in that, The system includes: An asymmetric U-shaped device, with its inlet end positioned higher than its outlet end, is used to achieve gas-liquid separation; The data acquisition and detection module, which is installed on the asymmetric U-shaped device, is used to acquire swirling signals, water content data, pressure difference data, gas data, and liquid data; The metering module communicates with the asymmetric U-shaped device and the data acquisition and detection module to realize online real-time metering of gas and liquid phases based on the flow state and combined with the gas volume calculation model and / or the gas-liquid two-phase accumulation model. The asymmetric H-shaped device comprises: a first variable diameter pipe section comprising a first horizontal pipe section and a second vertical pipe section, for realizing primary gas-liquid separation; a second variable diameter pipe section comprising a third horizontal pipe section and a fourth vertical pipe section, the fourth vertical pipe section being used for realizing secondary gas-liquid separation; a third variable diameter pipe section comprising a fifth vertical pipe section and a sixth horizontal pipe section; an upper horizontal straight pipe section, a first end of which is connected with a first end of the fourth vertical pipe section, and a second end of which is connected with a first end of the fifth vertical pipe section; and a lower horizontal primary variable diameter pipe section, a first end of which is connected with a second end of the fourth vertical pipe section, and a second end of which is connected with a second end of the fifth vertical pipe section. ​​​ The third transverse pipe section has a first end as an inlet and a second end as a connection to the fourth longitudinal pipe section. The sixth transverse pipe section has a second end as an outlet and a first end as a connection to the fifth longitudinal pipe section. The fourth longitudinal pipe section is wider at the top and narrower at the bottom, and the fifth longitudinal pipe section is wider at the top and narrower at the bottom. The gas volume calculation model includes the following formulas: ； wherein, represents the gas flow rate at the time represents the super compression factor, represents the gas flow rate at the time represents the gauge pressure of the gas flow meter at the time represents the local atmospheric pressure, represents the standard atmospheric pressure, represents the absolute temperature at the time in the standard state, represents the absolute temperature of the gas at the time represents the gas flow measurement value, represents the measurement frequency;​​ The gas-liquid two-phase integration model includes the following formula: ； in, Indicates the first Gas flow rate at any given time Indicates the swirl coefficient for full gas flow. Indicates the first The swirl coefficient at time 1. Indicates the first The gauge pressure of the gas flow meter at any given time. Indicates the first Absolute temperature under standard conditions at a given time. Indicates the first The absolute temperature of the gas at any given time.

2. The asymmetric dumbbell-shaped two-phase metering system of claim 1, wherein, The data acquisition and detection module includes: A gas flow meter is installed on the upper transverse straight pipe section to measure the gas data; A liquid flow meter is installed on the lower transverse primary diameter reducing pipe section to measure the liquid data.

3. The asymmetric dumbbell-shaped two-phase metering system of claim 2, wherein, The data acquisition and detection module includes: A swirl measurement module, located upstream of the gas flow meter, is used to measure the swirl signal; A moisture content detection module is located upstream of the liquid flow meter and is used to measure the moisture content data.

4. The asymmetric dumbbell-shaped two-phase metering system of claim 3, wherein, The data acquisition and detection module includes: The first differential pressure transmitter is located upstream of the swirl measurement module and is used to detect the first pressure value at the upstream position. The second differential pressure transmitter is located upstream of the moisture content detection module and is used to detect the second pressure value at the upstream location. The differential pressure generation unit communicates with the first differential pressure transmitter and the second differential pressure transmitter to calculate the differential pressure data based on the first pressure value and the second pressure value.

5. The asymmetric dumbbell-shaped two-phase metering system of claim 1, wherein, The metering module includes: The flow regime analysis module is used to determine the flow regime based on the swirling signal, the water content data, and the pressure difference data, wherein: When the swirling signal is greater than the preset swirling value and the differential pressure data is greater than the preset differential pressure value, it is determined to be a gas-liquid two-phase system; otherwise, it is determined to be a single gas phase system. When the moisture content data is greater than the preset moisture content value, it is judged to be a single liquid phase.

6. The asymmetric U-shaped two-phase metering system as described in claim 2, characterized in that, The liquid flow rate at each moment is calculated using the following formula: ； in, Indicates the first Liquid flow rate at any given time Indicates the inner diameter of the liquid flow meter. This represents the induced electromotive force of the liquid flow meter. Indicates the measured frequency. Indicates the calculated coefficient. This indicates the magnetic induction intensity of the liquid flow meter.

7. An asymmetric, zigzag-shaped two-phase metering method, characterized in that, The method for online real-time metering of gas-liquid two-phase gases using the asymmetric zigzag two-phase metering system as described in any one of claims 1-6 comprises: Gas-liquid separation is achieved through an asymmetrical U-shaped device with the inlet end positioned higher than the outlet end; The data acquisition and detection module installed on the asymmetric U-shaped device collects swirling signals, water content data, pressure difference data, gas data, and liquid data. The metering module, which communicates with the asymmetric U-shaped device and the data acquisition and detection module, realizes online real-time metering of gas and liquid phases based on the flow state and in combination with the gas volume calculation model and / or the gas-liquid two-phase accumulation model.

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