An online metering device and method for oil well production fluid based on swirl shaping

Abstract

A differential pressure online metering device for oil well production fluids based on swirl shaping includes an oil, gas, and water production fluid inlet, a production fluid gas phase separation section, a production fluid oil and water swirl shaping uniform mixing section, a differential pressure measurement and metering system, and an oil, gas, and water three-phase remixing outflow section. The present invention significantly shortens the required straight pipe section, greatly reduces the pressure difference, and has excellent adaptability to rotating flow and eddy currents. For multiphase fluids, the swirl device can rectify complex multiphase fluids into a uniformly dispersed flow state within the pipe that is symmetrical about the axis, making measurement more convenient. Since this method only affects the measurement of a simple swirl device, this method and device are easier to standardize than other non-standard differential pressure flowmeters.

Description

Technical Field

[0001] The invention belongs to the technical field of three-phase flow measurement, and in particular relates to a real-time automatic metering system and method for oilfield production fluid of three-phase oil, gas and water in an oilfield well. Background Art

[0002] During the oilfield production process, the produced fluid from the oil well mainly contains oil, associated gas, water, etc. During the flow of the produced fluid in the downhole oil pipe and the surface pipeline, the measurement of its flow rate and phase content are both typical multiphase flow metering problems. The surface multiphase pipe flow starts from the wellhead of the oil well, and goes through the process of collection, transportation, pressurization, gas-liquid separation, oil-water separation and other processes. It is necessary to measure the total flow rate of oil, gas and water in the pipeline at different process stages, the phase flow rate, water content, gas content and other parameters. The "three phases" in the present invention refer to the oilfield associated gas phase, oil phase and water phase. Due to the complexity of multiphase flow, the development of oil, gas and water multiphase flowmeters is quite difficult, and there are currently many technical routes for the development of multiphase flowmeters.

[0003] The traditional method for measuring oilfield well production in China primarily involves transporting the produced fluid from each well to a metering station for centralized metering. To conserve investment, a metering station typically houses only one large tank or bucket metering device, which periodically switches between them to perform spot checks on each well entering the station. This method suffers from poor real-time performance, making it both uneconomical and unsuitable for oilfield development. Measuring the water content of oilwell produced fluids generally involves manual sampling and testing, which is characterized by low representativeness and infrequent sampling. This process is cumbersome, labor-intensive, and costly. Therefore, real-time understanding and mastering of the operating conditions of the oil production system and achieving online metering of individual wells are urgent issues that need to be addressed in order to streamline domestic oil production processes and improve economic efficiency.

[0004] In multiphase flow measurement, separation remains the most reliable and accurate technology. For example, Chinese patents ZL200810112558.3 ​​and ZL200710046862.8 employ a large vessel as a three-phase oil-gas-water separation system, followed by single-phase metering. This method separates the oil, gas, and water phases into gas, oil, and water, then measures each phase's flow rate using a single-phase flowmeter. This method avoids the effects of flow pattern variations and instability on measurement. However, in actual multiphase flow measurement, complete and cost-effective separation of many fluids is sometimes impossible, leading to significant challenges in multiphase measurement. To address these issues, researchers both domestically and internationally have also adopted partial separation techniques. For example, U.S. Patent US6128962 employs a partial separation method that reduces separator size but does not completely separate the three-phase flow into a single phase, compromising metering accuracy. Chinese patent ZL98113068.2 also uses a similar split-phase measurement method. However, when the flow rate of the liquid or gas phase in the two-phase flow is very small (low gas content or high water content), after the split, the gas or oil phase flow rate flowing out of the separator is even smaller and cannot represent the whole, resulting in large measurement errors. U.S. Patents US5390547 and US7311001 respectively disclose a multiphase flow measurement device that only uses the multiphase fluid pipeline itself to form a separation system. This system abandons the traditional separator but adopts an external cyclone separation method, so in essence it is no different from the traditional separation method. In recent years, with the progress of related research work, new technologies for multiphase detection have continued to emerge, which makes it possible to greatly improve the performance of multiphase flowmeters in the future. For example, electrical, magnetic or radioactive methods are used to measure the phase density, phase holdup and phase velocity of the oil, gas and water three-phases online, thereby realizing oil, gas and water three-phase measurement, such as ZL201410468193.3 and 200810150257.X. However, the application of existing technologies is still very difficult in situations where the flow rate and phase holdup fluctuate widely and the flow is complex, such as oil well produced fluid.

[0005] Online measurement of oil well production fluids is a crucial task in oilfield production management. Timely and accurate oil well production data is crucial for assessing well production per unit time, tracking the dynamics of underground reservoir blocks, predicting and evaluating the development potential of oil well blocks, comprehensively analyzing and understanding the overall production capacity of the oilfield, and rationally formulating oilfield production plans. Currently, there are many methods for measuring oil well production fluid flow and water content, but they generally suffer from limited measurement ranges, limited applicability, and high costs, making them difficult to meet the actual needs of oilfield production.

[0006] Driven by the urgency of online metering of oil well production fluids, laboratory and field experiments have shown that when oil-water two-phase flow spirals within a pipe, it generates both a cyclonic pressure differential and an axial pressure differential. These two pressure differentials are highly sensitive to flow rate and water content. At a given flow rate, both pressure differentials exhibit a stable relationship with water content. The present invention is based on this research. Compared with existing technologies, this invention not only boasts high resolution but, more importantly, utilizes differential pressure measurement technology. Current differential pressure transmitters are technologically mature, stable, reliable, and economically sound, making them suitable for large-scale applications. Summary of the Invention

[0007] To overcome the shortcomings of the prior art, the present invention proposes a differential pressure flow measurement device and method based on cyclone shaping. This invention provides an automatic three-phase oil, gas, and water metering system for oilfield and well produced fluids. This system utilizes a compact gas-liquid separator within a pipeline to separate the gas phase from the oil-water phase. The separated gas is then discharged through a dedicated pipeline and accurately measured using a differential pressure or thermal mass flowmeter. Then, an in-pipe swirl device is used to rectify the high-water-content oil-water two-phase production fluid into a uniformly dispersed flow pattern. After the oil-water mixed fluid passes through the swirl mixer, water becomes the continuous phase and oil becomes the free phase dispersed therein. The swirl shaping device is used to generate radial differential pressure along the center and wall of the pipeline, and the axial pressure difference formed before and after the swirl shaping device is related to the flow rate and water content. Therefore, the dual differential pressure is used to realize the dual parameter measurement of oil well water content and liquid phase flow. Finally, combined with the gas phase flow measurement, the oil, gas and water three-phase content and total flow measurement are realized. The measured fluid passes through the resistance piece and is mixed with the returning gas flow, and continues to be transported along the pipeline to complete the three-phase automatic metering of the oil well production fluid.

[0008] The present invention offers the following advantages and features: It significantly shortens the required straight pipe section, significantly reduces differential pressure, and exhibits excellent adaptability to rotating and eddy currents. For multiphase fluids, the cyclone device can rectify the complex multiphase flow into a uniform, dispersed flow within the pipe that is symmetrical about the axis, thus facilitating measurement. Because this method only involves a simple cyclone, it is easier to standardize than other non-standard differential pressure flowmeters.

[0009] The purpose of the present invention can also be achieved by the following technical measures:

[0010] A differential pressure-based oil, gas, and water three-phase holdup and flow measurement device based on swirl shaping has a clear and concise structure. The device consists of five main parts: an oil, gas, and water production inlet, a production liquid gas separation section, a production liquid oil and water swirl shaping and uniform mixing section, a differential pressure measurement and metering system, and an oil, gas, and water three-phase remixing and outflow section. The oil well production liquid flows through the first part, the oil, gas, and water production inlet, and then passes through the production liquid inlet section and the production liquid inlet control valve into the second part, the production liquid gas separation section. The gas phase of the three phases is roughly separated through the production liquid lower bend section and the production liquid upper air duct section. The majority of the gas is introduced into the production liquid upper air duct section and enters the gas-liquid separator through the air duct section control valve. Together with the gas separated again from the production liquid lower bend section, it passes through a filtration device, enters the separation air duct section, the separation air duct section control valve, and the separation gas remixing section, where it is remixed with the separated oil-water mixture and flows into the downstream gathering and transportation pipeline. The oil-water mixture that passes through the gas-liquid separator enters the third part, the production liquid oil and water swirl shaping and uniform shaping. Part, at this time the produced liquid is basically all oil-water mixture, and the remaining small amount of gas has no obvious effect on shaping and measurement. At this time, the oil-water mixture is first shaped by the oil-water swirl shaping mixer, and is arranged into a uniform dispersed flow pattern symmetrical about the axis, establishing the flow pattern required for radial and axial pressure difference measurement. In the third part, it is connected to the fourth part of the differential pressure measurement and metering system through high and low pressure pressure pipelines, and the radial pressure difference between the center tube and the wall at the specified section after swirl shaping and the axial pressure difference between the two walls at the specified section before and after swirl shaping, as well as the pressure difference before and after the orifice plate of the gas phase pipeline are measured respectively. Finally, the oil-water mixture enters the fifth part, the oil, gas and water three-phase re-mixing outflow part. At this time, the oil-water mixture is re-mixed with the gas phase in the second part of the liquid-gas separation part and flows to the downstream gathering pipeline.

[0011] The coarse separation and degassing device of the present invention utilizes the principle of gas-liquid density difference to automatically separate gas and oil-water mixtures in downwardly inclined and upwardly inclined pipes. The angle between the downwardly inclined pipe and the horizontal pipe axis is controlled at 30-45°, while the angle between the upwardly inclined pipe and the horizontal pipe axis is controlled at 45-60°. The upwardly inclined pipe is installed 1 / 5-1 / 3 upstream of the downwardly inclined pipe.

[0012] The present invention utilizes a swirl device and adopts a swirl forced mixed flow method to expand the application range of oilfield produced fluid. It is not only suitable for stratified flow and wavy stratified flow at low flow rate, but also for annular flow and elastic flow at high flow rate.

[0013] The swirl device is used to organize the oil and water production fluid with complex flow patterns into the desired axisymmetric uniform flow pattern, and establish the flow pattern required for radial and axial pressure difference measurement.

[0014] When the axial pressure taking points are arranged, the first pressure taking position is located between 2D-5D upstream of the cyclone device, and the second pressure taking position is located between 5D-10D upstream of the cyclone device.

[0015] The radial pressure taking surface is arranged between 1D-5D downstream of the swirl device, and the second axial pressure taking position can coincide with the radial pressure taking wall pressure.

[0016] The swirl blades in the swirl device selected in the present invention can be either elliptical blade type or spiral type, or both can be used at the same time. The elliptical blade angle θ is 45-60°, and the spiral rotation angle θ is 30-60°.

[0017] The oil well production liquid online metering system also includes a temperature sensor and a pressure sensor, which are connected to the oil-water mixture pipeline and the gas phase pipeline to obtain temperature and pressure values ​​and verify the density and volume parameters of the oil, gas and water three-phase fluid.

[0018] The physical and chemical properties of oil, gas and water in the oil well oil, gas and water three-phase automatic metering system are input into the system's computer, and then new characteristic curves and parameters are formed based on the collected water content, flow value, temperature value and pressure value. The collected data are then processed and calculated to obtain the volume flow rate and mass flow rate of each phase of oil, gas and water.

[0019] The present invention discloses a three-phase online metering method for oil well production fluid based on the principle of swirl shaping. According to fluid mechanics, the axial pressure difference is caused by the friction along the fluid flow process, while the radial pressure difference is caused by the centrifugal acceleration when the fluid rotates. Here, the radial pressure difference is expressed as ΔP r , the axial pressure difference is expressed as ΔP r , define the ratio of the two as λ, the formula is as follows:

[0020]

[0021] After a lot of indoor and field research, it was found that when the oil-water two-phase mixture flows through the cyclone device, the radial pressure difference ΔP a and axial pressure difference ΔP r The ratio λ and the volume water content β of the oil-water two-phase mixture have the following relationship:

[0022] β=A*λ 2 +B*λ+C (2)

[0023] Among them, A, B, and C are all constants and can be obtained through indoor experiments or field experiments.

[0024] At the same time, the total flow rate of oil-water mixture Q m The radial pressure difference of the swirl flow, the pipe radius R, the volume water content β, and the water phase density ρ w , oil phase density ρ o .

[0025]

[0026] In addition, the radial flow coefficient α r and D are constants related to the device structure and fluid medium. Therefore, once the designed metering device structure is finalized, the corresponding radial α can be determined through indoor experiments. r and D value.

[0027] Differential pressure flowmeters with orifice plates and other throttling devices are commonly used in industry to measure gas flow. They are widely used due to their simple, reliable, and low maintenance methods. P0 and T0 are the pressure and temperature of the gas under standard conditions, respectively; P1 and T1 are the pressure and temperature of the gas under actual measurement conditions, respectively. g , is the flow coefficient, laboratory calibration, R g is the radius of the gas pipeline, ΔP g is the measured pressure difference on both sides of the orifice plate, Q g is the measured volume flow rate.

[0028]

[0029] The present invention discloses a three-phase online metering method for oil well production fluid based on the swirl shaping principle. The implementation steps are as follows:

[0030] Step 1: From formula (2), it can be seen that after the device is processed, as long as the radial pressure difference ΔP at a certain cross section after the swirl is measured, r and the axial pressure difference ΔPr, and substituting the ratio λ between the two into the value, the volume water content β of the oil-water two-phase mixture can be obtained.

[0031] Step 2: Collect the real-time data of temperature and pressure installed on the gas phase pipeline and the oil-water mixture pipeline, and substitute the measured water content β into formula (3). Combined with the experimental related constants and oil-water density, the total flow rate Q of the oil-water mixture can be obtained. m , to achieve the measurement of the total flow rate and phase content of oil-water mixture after degassing.

[0032] Step 3: Combine the gas phase with the orifice plate to measure the gas flow rate Q using formula (4) g , the oil, gas and water three-phase flow and phase content can be achieved, and the purpose of online measurement of oil well production fluid can be achieved. BRIEF DESCRIPTION OF THE DRAWINGS

[0033] In order to more clearly illustrate the technical solutions in the embodiments of the present invention, the following briefly introduces the drawings required for describing the embodiments. The drawings described below are only some embodiments of the present invention.

[0034] Figure 1A schematic diagram of an online metering device and method for oil well production fluid based on swirl shaping and its connection method;

[0035] Figure 2 Schematic diagram of gas-liquid separation tube structure requirements;

[0036] Figure 3 Schematic diagram of the structure of the oil-water swirl mixer;

[0037] Figure 4 a Schematic diagram of the elliptical swirl shaping blade structure;

[0038] Figure 4 b Schematic diagram of the spiral swirl shaping blade structure;

[0039] Figure 5 This is a schematic diagram of the flow pattern of the oilfield produced fluid in a circular pipe being converted into an axially uniformly dispersed flow after passing through an oil-water swirl mixer;

[0040] Figure 6 Field measured curve of axial radial pressure difference ratio λ and β water content;

[0041] Figure 7 Field measured curve of radial pressure difference and flow rate.

[0042] The reference numerals are as follows:

[0043] 1 Liquid production inlet section 2-1 Liquid production inlet control valve 2-3 Liquid production lower bend section 2-4 Liquid production upper air inlet pipe section 2-5 Liquid production upper air inlet pipe section regulating valve 2-6 Gas-liquid separator 2-7 Separation air pipe section 2-8 Separation air pipe section regulating valve 2-9 Separation air re-blending pipe section 3-1 Oil-water mixture inlet control valve 3-2 Oil-water swirl shaping mixer 3-3 Oil-water mixture outlet control valve 4-1 High-pressure end of oil-water mixture axial pressure inlet pipe 4-2 Low-pressure end of oil-water mixture axial pressure inlet pipe 4-3 Oil-water mixture axial differential pressure transmitter 4-4 High-pressure end of oil-water mixture radial pressure inlet pipe 4-5 Low-pressure end of oil-water mixture radial pressure inlet pipe 4-6 Oil-water mixture radial differential pressure transmitter 4-7 Gas phase flow differential pressure testing system 4-8 Gas phase temperature and pressure measurement system 4-9 Oil-water mixture temperature and pressure measurement system 4-10 Oil-gas-water three-phase flow and phase holdup metering system 5 Oil-gas-water three-phase mixture outlet;

[0044] 3-2-1 swirl shaping blade 3-2-2 swirl shaping blade outer tube. DETAILED DESCRIPTION

[0045] The following will clearly and completely describe the technical solutions in the embodiments of the present invention in conjunction with the accompanying drawings. Obviously, the described embodiments are only part of the embodiments of the present invention, not all of the embodiments. Based on the embodiments of the present invention, all other embodiments obtained by ordinary technicians in this field without making any creative efforts shall fall within the scope of protection of the present invention.

[0046] As attached Figure 1 As shown, the device described in the present invention includes the following five parts: an oil, gas and water production liquid inlet part, a production liquid and gas phase separation part, a production liquid oil and water swirl shaping and uniform mixing part, a differential pressure measurement and metering system, and an oil, gas and water three-phase re-mixing outflow part. The various parts are specifically composed of the following: liquid production inlet section, liquid production inlet control valve, liquid production lower bend section, liquid production upper air duct section, liquid production upper air duct section regulating valve, gas-liquid separator, separation air pipe section, separation air pipe section regulating valve, separation gas re-mixing pipe section, oil-water mixture inlet control valve, oil-water swirl shaping mixer, oil-water mixture outlet control valve, oil-water mixture axial pressure pipe high pressure end, oil-water mixture axial pressure pipe low pressure end, oil-water mixture axial differential pressure transmitter, oil-water mixture radial pressure pipe high pressure end, oil-water mixture radial pressure pipe low pressure end, oil-water mixture radial differential pressure transmitter, gas phase flow differential pressure test system, gas phase temperature and pressure sensor, oil-water mixture temperature and pressure sensor, oil-gas-water three-phase flow and phase content metering system, oil-gas-water three-phase mixture outlet.

[0047] The specific connection method of each section is as follows: the oil well production liquid flows through the first section, oil, gas and water production liquid inlet section 1, into the production liquid inlet control valve 2-1, and then into the second section, the production liquid gas phase separation section. The gas phase of the three phases of oil, gas and water is roughly separated by gravity using the gas-liquid density difference through the production liquid lower bend section 2-3 and the production liquid upper air inlet section 2-4. The majority of the gas is introduced into the production liquid upper air inlet section 2-4 and enters the gas-liquid separator 2-6 through the air inlet section control valve 2-5. Then, through the expansion buffer, the gas-liquid density difference is again utilized, and the gas phase separation is further carried out by gravity and a filter screen. Together with the gas separated again from the production liquid lower bend section, it passes through the filtration device into the separation air pipe section 2-7, the separation air pipe section control valve 2-8, and the separation gas re-mixing pipe section 2-9, where it is mixed with the separated oil-water mixture and flows to the downstream gathering and transportation pipeline. The oil-water mixture passing through the gas-liquid separator 2-6 enters the third section, the production liquid, and is swirl-shaped to form a uniform oil-water mixture. Part, at this time the produced liquid is basically all oil-water mixture, and the remaining small amount of gas has no obvious effect on shaping and measurement. At this time, the oil-water mixture first passes through the oil-water mixture inlet control valve 3-1 and enters the oil-water swirl shaping mixer 3-2 for shaping, and is arranged into a uniform dispersed flow pattern symmetrical about the axis, establishing the flow pattern required for radial and axial pressure difference measurement. Then the rectified oil-water mixture passes through the oil-water mixture outlet control valve 3-3 and enters the downstream gathering pipeline where it is re-mixed with the gas phase in the second part of the liquid-gas separation part and flows to the oil-gas-water three-phase mixture outlet 5. In the third part, the axial pressure difference on the specified two sections is measured by connecting the high-pressure end 4-1 of the oil-water mixture axial pressure guide pipe and the low-pressure end 4-2 of the oil-water mixture axial pressure guide pipe to the oil-water mixture axial differential pressure transmitter 4-3. Additionally, the radial pressure differential at a specified cross-section is measured via the high-pressure end 4-4 and low-pressure end 4-5 of a radial oil-water mixture pressure inlet pipe connected to an oil-water mixture radial differential pressure transmitter 4-6. Simultaneously, data from a gas phase flow differential pressure test system 4-7, a gas phase temperature and pressure sensor 4-8, and an oil-water mixture temperature and pressure sensor 4-9, which collect data from the pressure differential across the orifice plate of the gas phase pipeline, are transmitted to an oil-gas-water three-phase flow and phase holdup metering system 4-10. The system then centrally displays the total oil-water flow rate, gas phase flow rate, and water cut.

[0048] Among them, the gas-liquid separation tube structure is as shown in the attached Figure 2 As shown in the figure, the positions and angles of the gas sampling tube and the oil-water separation tube during crude gas separation are clearly defined. The included angle θ1 between the downward-inclined pipe and the horizontal pipe axis is controlled between 30-45°, and the included angle θ2 between the upward-inclined pipe and the horizontal pipe axis is controlled between 45-60°. Position L1 of the upward-inclined pipe is installed 1 / 5-1 / 3 L upstream of the downward-inclined pipe.

[0049] The structure of the oil-water swirl mixer is shown in the attached Figure 3It consists of a swirl shaping blade 3-2-1 and a swirl shaping blade outer tube 3-2-2, which is mainly arranged into a uniform dispersed flow pattern about the axis, and establishes the flow pattern required for radial and axial pressure difference measurement, as shown in the attached figure. Figure 5 shown.

[0050] The structure of the swirl shaping blade is as shown in the attached Figure 4 4a and 4b. In this embodiment, the blade structures used in both indoor and field experiments were: elliptical blades with an elliptical blade angle θ of 45-60°; and spiral blades with a spiral rotation angle θ of 30-60°. Alternating these two blade types and coordinating them together yields more accurate separation results. It is understood that other suitable blade types may also be selected based on field conditions.

[0051] The produced fluids with different flow patterns, such as stratified flow, slug flow and annular flow, are transformed into a uniform and evenly dispersed flow after passing through the oil-water swirl mixer. Figure 5 As shown in the figure, by shaping and mixing, more uniform measurement results can be obtained for oil-water mixtures under different environments.

[0052] Through measurement, various measured curves can be obtained on site. Figure 6 The figure shows the field measured curve of the axial radial pressure difference ratio λ and the water content of B, which corresponds to the radial pressure difference ΔP when the oil-water two-phase mixture flows through the cyclone device. r and axial pressure difference ΔP r The formula of the ratio λ and the volume water content β of the oil-water two-phase mixture is: β=A*λ 2 +B*λ+C. As attached Figure 7 The figure shows the field measured curve of radial pressure difference and flow rate, which corresponds to the total flow rate Q of oil-water mixture. m The radial pressure difference of the swirl flow, the pipe radius R, the volume water content β, and the water phase density ρ w , oil phase density ρ o The relationship is as follows:

[0053]

[0054] While embodiments of the present invention have been shown and described, it will be appreciated by those skilled in the art that various changes, modifications, substitutions, and variations may be made to the embodiments without departing from the principles and spirit of the invention, and that the scope of the invention is defined by the claims and their equivalents.

Claims

1. An operating method of a differential pressure oil well production liquid online metering device based on swirl shaping, characterized in that: The metering device includes an oil, gas and water production liquid inlet part, a production liquid and gas phase separation part, a production liquid oil and water swirl shaping and uniform mixing part, a differential pressure measurement and metering system, and an oil, gas and water three-phase re-mixing outflow part; The operation method is: Step 1: Measure the radial pressure difference ΔP at a certain section after the swirl z and axial pressure difference ΔP r The ratio λ of the two is substituted into the volumetric water content β of the oil-water two-phase mixture, as shown in formula (2); β = A * λ 2 + B * λ + C Equation (2); Among them, A, B, and C are constants; Step 2: Collect the real-time data of temperature and pressure installed on the gas phase pipeline and the oil-water mixture pipeline, combine the measured water content β, and the experimentally obtained related constants and oil-water density, and use formula (3) to obtain the total flow rate Q of the oil-water mixture: m ; Among them, α r is the flow coefficient, D is the fluid medium constant, R is the pipe radius, β is the volume water content, ρ w is the density of the water phase, ρ o is the density of the oil phase; Step 3: Combine the gas phase with the orifice plate to measure the gas flow rate Q using formula (4) g , and obtain the oil, gas and water three-phase flow and phase holdup; P0, T0, respectively, are the pressure and temperature of the gas being measured under standard conditions; P1, T1 are respectively the pressure and temperature of the gas under actual measurement conditions, α g , is the flow coefficient, R g is the radius of the gas pipeline, ΔP g is the measured pressure difference on both sides of the orifice plate, Q g is the measured volume flow rate.

2. The method for operating the differential pressure type oil well production fluid online metering device based on swirl shaping according to claim 1, characterized in that: In the metering device, the liquid-gas phase separation part realizes the separation of gas and oil-water mixture in the inclined pipeline.

3. The differential pressure type oil well production liquid online metering device based on swirl shaping according to claim 2, characterized in that: The inclined pipeline includes an upper inclined pipeline and a lower inclined pipeline.

4. The method for operating the differential pressure type oil well production fluid online metering device based on swirl shaping according to claim 3 is characterized in that: In the metering device, the angle between the downward inclined pipe and the horizontal pipe axis is controlled to be 30-45°.

5. The method for operating the differential pressure type online metering device for oil well production fluid based on swirl shaping according to claim 3 or 4, characterized in that: In the metering device, the angle between the upward inclined pipe and the horizontal pipe axis is controlled to be 45-60°.

6. The method for operating the differential pressure type online metering device for oil well production fluid based on swirl shaping according to claim 5, characterized in that: In the metering device, the upper inclined pipeline is installed upstream of the lower inclined pipeline.

7. The method for operating the differential pressure type online metering device for oil well production fluid based on swirl shaping according to claim 1, characterized in that: In the metering device, the swirl shaping and uniform mixing part includes swirl blades.

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