Metering device for oil-gas-water mixed transportation

Abstract

The invention discloses an oil-gas-water mixed transportation metering device which comprises a main mounting pipe, one end of the main mounting pipe is provided with a first flow guide cover through a bolt, the input end of the first flow guide cover is communicated with an input pipe, and the other end of the input pipe is provided with a straight pipe type Coriolis mass flow meter through a bolt. The input end of the straight pipe type Coriolis mass flowmeter is communicated with a communicating pipe; liquid flows in the main installation pipe, the fluid model is calculated and measured through a plurality of optical measurement sensors with contrast light and without contrast light sources in the first installation pipe, and light diffraction, reflection and other conditions are collected through a transparent window of an embedded quartz window. The total mass flow rate and the branch mass flow rate are respectively measured by matching with system calculation integration, the overall accuracy is improved, the structural size is small, the application range is wide, use in various scenes is facilitated, and the overall use effect is improved.

Description

Technical Field

[0001] This invention relates to the field of metering technology for oil and gas transportation, specifically a metering device for mixed oil, gas and water transportation. Background Technology

[0002] Oil and gas metering is a core component of oil and gas production, transportation, and trade. Its core function is to measure the flow rate of each phase in a multiphase mixture of oil, gas, water, and solid impurities using a "separation-phase metering" method (the mainstream approach, which uses a separator to separate gas, liquid, and solid phases, then uses flow meters, water content analyzers, and other equipment to measure the flow rate of each phase). This process, combined with temperature and pressure compensation and error calibration, eliminates interference from medium characteristics and operating condition fluctuations, ultimately providing accurate statistics on the output of each phase and reliable data support for production control, trade settlement, and equipment maintenance.

[0003] During the transportation of oil and gas, due to extraction and production reasons, there is often a phenomenon of oil, gas and water being transported together and metered to facilitate meeting subsequent production requirements. However, existing metering methods mostly use various separation equipment to separate the multiple phases before metering. This method involves a variety of equipment, which are large and cumbersome, difficult to arrange, and not flexible enough to be used in some pipeline transportation sections. Installation and use are inconvenient. In some site-restricted scenarios, it is not possible to use large equipment to combine separation and measurement, and it is necessary to use pipeline transportation before separation and measurement, which causes certain inconveniences. Based on this, a metering device for mixed oil, gas and water transportation is proposed. Summary of the Invention

[0004] The purpose of this invention is to provide a metering device for mixed oil, gas and water transportation to solve the problems mentioned in the background art.

[0005] To achieve the above objectives, the present invention provides the following technical solution: a metering device for mixed oil, gas, and water transportation, comprising a main mounting pipe, a flow guide shroud one bolted to one end of the main mounting pipe, an input pipe connected to the input end of the flow guide shroud one, a straight-tube Coriolis mass flow meter bolted to the other end of the input pipe, a connecting pipe connected to the input end of the straight-tube Coriolis mass flow meter, a second flow guide shroud bolted to the end of the main mounting pipe away from the first flow guide shroud, an output pipe connected to the output end of the second flow guide shroud, an inlet connecting pipe connected to the top of the output pipe, a fixing ring fixedly sleeved on the outer sides of both the first and second flow guide shrouds, a temperature and pressure auxiliary sensor mounted on the top of the main mounting pipe, an outlet connecting pipe connected to the top of the main mounting pipe, a flow guide pipe mounted at the top of the outlet connecting pipe, a sampling valve connected to the top of the flow guide pipe, a gas flow meter mounted on the top of the middle section of the flow guide pipe, and a flow guide valve mounted on the top of the end of the flow guide pipe away from the sampling valve. The system is equipped with valve two. Several auxiliary springs are fixedly installed on the inner wall of the first flow guide shroud, and a filter screen is fixedly installed at the other end of each auxiliary spring. A spiral guide plate is fixedly installed inside the input pipe, with a spiral angle ranging from 30° to 60°. A telescopic guide rail is fixedly installed at the top of the inner cavity of the second flow guide shroud, and a floating liquid level sensor is installed at the bottom end of the telescopic guide rail. Several embedded quartz windows are fixedly installed on the inner wall of the main installation pipe. Several installation pipes one are fixedly installed on the outer side of the main installation pipe, and two installation pipes two are fixedly installed on the outer side of the main installation pipe. An optical measurement sensor is installed inside each installation pipe one. A discharge pipe one is connected to the bottom of the first flow guide shroud, and a discharge pipe two is connected to the bottom of the second flow guide shroud. An array-type capacitive sensor is installed on the outer side of the bottom end of the first discharge pipe, and an electromagnetic induction sensor is installed on the outer side of the bottom end of the second discharge pipe. An intelligent controller is fixedly installed on the outer side of the main installation pipe.

[0006] Preferably, a valve is installed inside the connecting pipe, a valve is installed inside the output pipe, and flange rings are provided at opposite ends of the connecting pipe and the output pipe.

[0007] Preferably, telescopic outriggers are fixedly installed on both sides of the fixed ring, and support rods are movably sleeved on the opposite sides of the telescopic outriggers. Support pads are fixedly installed at the bottom of the telescopic outriggers, and fixing holes are opened inside the support pads.

[0008] Preferably, the end of the guide tube away from the outlet connecting tube is installed on the inner side of the top of the inlet connecting tube, and a metal defoaming mesh is fixedly installed on the top of the inner cavity of the main installation tube, with the metal defoaming mesh located at the bottom of the outlet connecting tube.

[0009] Preferably, the filter screen is movably sleeved on the inner wall of the flow guide shroud, the position of the filter screen corresponds to the position of the discharge pipe, and the auxiliary springs are evenly distributed circumferentially inside the flow guide shroud.

[0010] Preferably, the optimal flow velocity inside the main mounting pipe is 0.3 to 1.5 m / s, the lead of the spiral guide plate (32) is 0.8 to 1.5, the spiral guide plate is composed of a UHMWPE liner and a stainless steel substrate, and the outer surface is coated with a polytetrafluoroethylene coating.

[0011] Preferably, the floating liquid level sensor is streamlined and coated with a polytetrafluoroethylene coating.

[0012] Preferably, the first mounting tube is evenly distributed circumferentially on the outside of the main mounting tube. The positions of the first and second mounting tubes correspond to the positions of the embedded quartz window. Flange plates are movably installed on the outside of both the first and second mounting tubes. A supplementary light source is provided inside the second mounting tube. The measurement methods of the optical measurement sensor include laser Doppler velocimetry, near-infrared spectral sensing, laser absorption current meter, high-speed imaging velocimetry, and laser diffraction particle analysis.

[0013] Preferably, the array-type capacitive sensors are linearly and uniformly distributed on the outside of the first discharge pipe, and the electromagnetic induction sensors are linearly and uniformly distributed on the outside of the second discharge pipe. Both the first and second discharge pipes are inclined. A valve four is provided inside the bottom end of both the first and second discharge pipes. A spiral sealing cap is threadedly connected to the outer side of the opposite ends of the first and second discharge pipes. The electromagnetic induction sensors and the array-type capacitive sensors are located on the opposite side of the valve four and the spiral sealing cap.

[0014] Preferably, the intelligent controller has a built-in real-time signal filtering algorithm, feature extraction algorithm, AI error calibration model, data fusion module, and remote monitoring and fault diagnosis system.

[0015] Compared with the prior art, the beneficial effects of the present invention are as follows: 1. When the equipment is in use, the mixed liquid is first measured by a straight-pipe Coriolis mass flow meter to determine the total phase mass flow rate. Then, it is guided by a spiral guide plate inside the input pipe to promote rapid pre-separation of gas, liquid, and solid. The solid micro-pebbles contained in the liquid are intercepted by the filter screen. The flow velocity is reduced in the expansion space inside the main installation pipe, and the stratification tends to be stable. Water flows in the lower layer, the middle layer is oil mixture, and the upper layer is gas stratification. The liquid flows through the main installation pipe as the flow progresses. The flow continues inside the inlet and outlet pipe of the second guide shroud. Some gas is introduced into the guide pipe and the flow rate of the outgoing gas in this section is measured by a gas flow meter. Then, multiple optical measurement sensors with and without reference light sources inside the first installation pipe are used to calculate and measure the fluid model separately. Light diffraction and reflection are collected through the transparent window of the embedded quartz window. Combined with the system calculation and integration, the total mass flow rate and the partial mass flow rate are measured separately, which improves the overall accuracy. Moreover, the structure is small in size and has a wide range of applications, making it convenient to use in various scenarios and increasing the overall use effect. 2. The filter screen of this solution intercepts solid microparticles and impacts the filter screen to cause it to vibrate. The design of the movable sleeve and auxiliary spring maintains a relatively stable position, which promotes the interception and deposition of solid microparticles and guides them into the discharge pipe for deposition. It also intercepts gas bubbles separated by the sudden expansion of the mixed liquid under decompression, reduces bubbles, assists in liquid stratification, facilitates the interception of solid particles and the elimination of large bubbles, and increases relative stability. 3. In this solution, when the liquid inside the main installation pipe is intercepted and accumulated by the filter screen, it is guided to the location of the array capacitive sensor through the discharge pipe one. When the accumulated particles are detected and reach the position that needs to be cleaned, the operator closes valve four and unscrews the spiral seal cap to discharge the particles inside discharge pipe one and discharge pipe two. The whole process is convenient for maintenance and indirectly increases the service life of the structure. Attached Figure Description

[0016] Figure 1 This is a front-view stereoscopic structural diagram of the present invention.

[0017] Figure 2 This is a schematic diagram of the three-dimensional appearance structure of the present invention from a rear-view or upward-view perspective.

[0018] Figure 3 This is a schematic diagram of the front appearance structure of the present invention.

[0019] Figure 4 This is a front sectional view of the internal structure of the present invention.

[0020] Figure 5 This is a schematic diagram of the internal structure of the present invention, viewed from the right side.

[0021] Figure 6 For the present invention Figure 4 Enlarged structural diagram at point A in the middle.

[0022] Figure 7 For the present invention Figure 4 Enlarged structural diagram at point B.

[0023] Figure 8 For the present invention Figure 5 Enlarged structural diagram at point C.

[0024] In the diagram: 1. Main mounting pipe; 2. Flow guide shroud one; 3. Input pipe; 4. Straight-tube Coriolis mass flow meter; 5. Connecting pipe; 6. Valve one; 7. Temperature and pressure auxiliary sensor; 8. Outgoing connection pipe; 9. Sampling valve; 10. Flow guide pipe; 11. Gas flow meter; 12. Valve two; 13. Inlet connection pipe; 14. Output pipe; 15. Valve three; 16. Flow guide shroud two; 17. Mounting pipe one; 18. Mounting pipe two; 19. Intelligent controller; 20. Telescopic outrigger. 21. Support; 22. Support rod; 23. Fixing hole; 24. Discharge pipe one; 25. Discharge pipe two; 26. Fixing ring; 27. Valve four; 28. Spiral sealing cap; 29. ​​Electromagnetic induction sensor; 30. Array capacitive sensor; 31. Embedded quartz window; 32. Spiral guide plate; 33. Auxiliary spring; 34. Filter screen; 35. Telescopic guide rail; 36. Floating liquid level sensor; 37. Metal foam breaker; 38. Optical measurement sensor. Detailed Implementation

[0025] The technical solutions of the embodiments of the present invention will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of the present invention, and not all embodiments. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of the present invention.

[0026] Please see Figures 1-8This invention provides a technical solution: a metering device for mixed oil, gas, and water transportation, comprising a main mounting pipe 1, a flow guide shroud 2 bolted to one end of the main mounting pipe 1, an input pipe 3 connected to the input end of the flow guide shroud 2, a straight-tube Coriolis mass flow meter 4 bolted to the other end of the input pipe 3, a connecting pipe 5 connected to the input end of the straight-tube Coriolis mass flow meter 4, and a second flow guide shroud 16 bolted to the end of the main mounting pipe 1 away from the flow guide shroud 2, the output end of the second flow guide shroud 16 connected to a connecting pipe 5. The top of the outlet pipe 14 is connected to the inlet connecting pipe 13. The outer sides of both the first and second flow guide shrouds 16 are fixedly fitted with retaining rings 26. A temperature and pressure auxiliary sensor 7 is installed on the top of the main mounting pipe 1. An outlet connecting pipe 8 is connected to the top of the main mounting pipe 1. A flow guide pipe 10 is installed at the top of the outlet connecting pipe 8. A sampling valve 9 is connected to the top of the flow guide pipe 10. A gas flow meter 11 is installed on the top of the middle section of the flow guide pipe 10. A valve 2 12 is installed on the top of the end of the flow guide pipe 10 furthest from the sampling valve 9. Several auxiliary springs 33 are fixedly installed on the inner wall of the flow guide shroud 1 2. A filter screen 34 is fixedly installed on the other end of the auxiliary springs 33. A spiral guide plate 32 is fixedly installed inside the input pipe 3. The spiral angle of the spiral guide plate 32 is in the range of 30°~60°. A telescopic guide rail 35 is fixedly installed on the top of the inner cavity of the flow guide shroud 2 16. A floating liquid level sensor 36 is installed at the bottom end of the telescopic guide rail 35. Several embedded quartz windows 31 are fixedly installed embedded in the inner wall of the main installation pipe 1. Several mounting tubes 17 are fixedly installed on the outside of the main mounting tube 1. Two mounting tubes 18 are fixedly installed on the outside of the main mounting tube 1. An optical measurement sensor 38 is installed inside the mounting tube 17. The bottom of the flow guide 2 is connected to the discharge tube 24. The bottom of the flow guide 2 is connected to the discharge tube 25. An array-type capacitive sensor 30 is set on the outside of the bottom end of the discharge tube 24. An electromagnetic induction sensor 29 is set on the outside of the bottom end of the discharge tube 25. An intelligent controller 19 is fixedly installed on the outside of the main mounting tube 1.

[0027] The working principle of the above technical solution is as follows: In use, the connecting pipe 5 and the output pipe 14 are connected to the upstream and downstream of the conveying pipeline through flanges. When the unstratified mixed liquid is conveyed through the straight-pipe Coriolis mass flow meter 4, the total phase mass flow range is first measured. Then, the spiral flow is guided by the spiral guide plate 32 inside the input pipe 3. The spiral plate is forced to rotate, generating centrifugal force and guiding the fluid to form a spiral flow. The flow velocity is fastest at the center of the pipe and slowest at the wall surface, avoiding the accumulation of solid particles due to excessively low flow velocity. This promotes rapid pre-stratification of gas, liquid, and solid. The filter screen 34 intercepts and reduces the solid micro-pebbles contained in the liquid, which are then accumulated at the bottom of the guide hood 2 and stored inside the discharge pipe 24. The mesh of the filter screen 34 promotes the gradual stabilization of the liquid, and the expansion space inside the main installation pipe 1 reduces the flow velocity and tends to achieve stratification and stability. At this time, the liquid is formed... The liquid flows in a lower layer as smaller particles and water, a middle layer is a mixture of oil and gas, and an upper layer is a stratified gas. The length of the main installation pipe 1 is extended according to the flow velocity. After initial separation, the liquid flows through the main installation pipe 1 and is guided into the output pipe 14 through the flow guide shroud 16 to continue flowing, creating a pressure difference. Some gas is introduced into the flow guide pipe 10, and the flow rate of the gas exiting this section is measured by the gas flow meter 11. The gas then merges through the output pipe 14. Then, multiple optical measurement sensors 38 with and without reference light sources inside the installation pipe 17 calculate and measure the fluid model separately. The light diffraction and reflection are collected through the transparent window of the embedded quartz window 31. The total mass flow rate and the partial mass flow rate are measured separately by the algorithm, which improves the overall accuracy. The structure is small in size and has a wide range of applications, making it convenient to use in various scenarios and increasing the overall performance.

[0028] In another implementation scheme, such as Figures 1-5 As shown, valve 6 is installed inside the connecting pipe 5, and valve 15 is installed inside the output pipe 14. Flange rings are provided at the opposite ends of the connecting pipe 5 and the output pipe 14.

[0029] The installation of valves 1-6 and 3-15 facilitates closure during maintenance, cutting off the flow in the diversion pipe, allowing the main installation pipe 1 to be disassembled from the opposite side of guide shield 1-2 and guide shield 2-16 for maintenance and cleaning. It also indirectly assists in adjusting the flow rate, facilitating measurement operations. It can be used to adjust the diversion speed in multi-pipe diversion, increasing the structural effectiveness. The connecting pipe 5 and the output pipe 14 are connected to the conveying pipe through flanges for easy connection.

[0030] In another implementation scheme, such as Figures 1-5 As shown, telescopic outriggers 20 are fixedly installed on both sides of the fixed ring 26. Support rods 22 are movably sleeved on the opposite side of the telescopic outriggers 20. Support pads 21 are fixedly installed at the bottom of the telescopic outriggers 20. Fixing holes 23 are opened inside the support pads 21.

[0031] After the telescopic outrigger 20 is adjusted, the equipment is supported at the installation position of the conveying pipeline. By adjusting the length, the support pad 21 is placed on the bottom of the ground and a rubber pad is added. It is fixed by inserting bolts or ground anchors into the fixing holes 23. The support rod 22 is used to increase the structural force and provide a relatively stable support force for the main installation pipe 1, which facilitates support and ensures stability.

[0032] In another implementation scheme, such as Figures 1-8 As shown, the end of the guide tube 10 away from the outlet connecting tube 8 is installed on the inner side of the top of the inlet connecting tube 13, and a metal defoaming mesh 37 is fixedly installed on the top of the inner cavity of the main installation tube 1. The metal defoaming mesh 37 is located at the bottom of the outlet connecting tube 8.

[0033] The metal defoaming mesh 37 captures mist-like droplets entrained in the gas, reducing the liquid content in the gas flowing out through the guide pipe 10. Through the expansion space design of the main installation pipe 1 and the gas distribution pipe design of the guide pipe 10, the gas is concentrated at the top of the expansion section and flows into the output end through the gas distribution pipe. Solids and water settle at the bottom of the expansion section and move forward with the liquid flow. The oil is located in the middle of the expansion section, and the overall distribution is a layered distribution of "gas at the top, oil in the middle, and solid and liquid at the bottom". When the mixed fluid enters the expansion section of the main installation pipe 1, the flow velocity drops from the normal pipe velocity to 1 / 3 to 1 / 5, and the separation effect is quickly activated. The gas rises instantly, the solids and liquids sink rapidly, and the crude oil is buffered in the middle. The gas distribution pipe of the top guide pipe 10 continuously discharges the gas, avoiding the accumulation of gas layer and the entrainment of crude oil and solids and liquids by the airflow. The bottom solid and liquid layer is assumed to be horizontal or slightly inclined due to the pipeline direction, and moves forward slowly with the liquid flow. Solid particles are not easy to accumulate. If the expansion section has an inclination angle, solids are more likely to accumulate at the lower end. Near the ends of the expansion section where it connects to the main installation pipe 1, the flow velocity gradually returns to normal, and the stratification boundaries may become slightly blurred. A small amount of slight entrainment of "gas in oil" or "oil in water" may occur, but the overall distribution trend remains unchanged. Key variable parameters: Volume of the expansion section of main installation pipe 1: a larger volume and longer length result in lower flow velocity, more thorough separation, and clearer stratification. Inclination angle of main installation pipe 1: a slight downward inclination of ≤5° in the expansion section facilitates the flow of solids and water to the output end, preventing accumulation; an upward inclination may lead to solid-liquid stagnation. Extending the length of main installation pipe 1 and controlling the input fluid velocity reduces the risk of insufficient separation time after entering the expansion section due to excessively high flow velocity in the normal pipe section, which could lead to gas entrainment of droplets and solids suspended in the oil phase, resulting in blurred stratification.

[0034] In another implementation scheme, such as Figures 1-8 As shown, the filter screen 34 is movably sleeved on the inner wall of the flow guide shroud 2, and the position of the filter screen 34 corresponds to the position of the discharge pipe 24. The auxiliary springs 33 are evenly distributed in a circular pattern inside the flow guide shroud 2.

[0035] The function of the filter screen 34 is to receive the mixed liquid flow sprayed from the spiral guide plate 32 inside the inlet pipe 3, which has a certain impact force and is guided to the inner side of the filter screen 34 under the action of the spiral. At this time, the solid micro particles are intercepted and impact the filter screen 34, causing the filter screen 34 to vibrate. The design of the movable sleeve and the auxiliary spring 33 maintains a relatively stable position, which promotes the interception and deposition of solid micro particles and guides them into the discharge pipe 24 for deposition. It also intercepts the gas bubbles separated by the sudden expansion of the mixed liquid under decompression, reduces bubbles, assists in liquid stratification, facilitates the interception of solid particles and the elimination of large bubbles, and increases relative stability.

[0036] In another implementation scheme, such as Figures 1-8 As shown, the optimal flow velocity range inside the main installation pipe 1 is 0.3 to 1.5 m / s, the lead of the spiral guide plate 32 is 0.8 to 1.5, and the spiral guide plate 32 is composed of a UHMWPE liner and a stainless steel substrate, with a polytetrafluoroethylene coating on its outer surface.

[0037] Ensure the liquid flow velocity within the expansion section of the main mounting pipe 1 is controlled between 0.3 and 1.5 m / s. This ensures stable stratification while preventing solid accumulation due to excessively low velocity or stratification disruption due to excessively high velocity. The embedded quartz window 31 is located in the middle of the main mounting pipe 1. At this point, the liquid stratification is stable, facilitating optical measurements. Lead calculation: P = k × Dk = 0.8 ~ 1.5. Spiral plate height calculation: h = 0.1 ~ 0.2 × D. Lead / pipe diameter ratio: 0.8 ~ 1.5, preferably 1:1. For high gas content conditions: increase the lead to 1.2 ~ 1.5. For high sand content conditions: decrease the lead to 0.8 ~ 1.0. The lead determines the spiral flow intensity; a 1:1 ratio provides the optimal balance between centrifugal force and pressure drop. Increasing the lead angle reduces gas retention and pressure drop when gas content is high; decreasing the lead angle enhances centrifugal force and promotes solid adhesion to the wall when sand content is high. For spiral guide vanes 32, 3-6 blades are preferred, with 4-5 blades being ideal. The number of blades affects flow field uniformity; 4-5 blades achieve a balance between separation efficiency and pressure drop. Reducing the number of blades when sand content is high lowers the risk of solid entrapment; increasing the number of blades for high-viscosity fluids enhances turbulent mixing. The helix angle determines the direction of centrifugal force; 45° results in the highest gas-liquid-solid separation efficiency. Increasing the helix angle in horizontal pipes enhances vertical stratification, while decreasing the helix angle in inclined pipes prevents fluid deflection. UHMWPE liners have 7-10 times the wear resistance of carbon steel, making them suitable for sandy conditions. The PTFE coating reduces the coefficient of friction to 0.07, minimizing solid adhesion. Blade spacing must be larger than the solid particle size to prevent entrapment. For high sand content conditions, a sand discharge port should be added, and deposited solids should be cleaned regularly. In addition, it should be noted that if the spiral plate lead is too small or the blades are too dense, solid particles may accumulate and clog the blade gaps. Under high gas content conditions, the central gas phase zone may expand, compressing the liquid flow channel and affecting flow stability. Pressure drop estimation requires additional reference to estimation formulas.

[0038] In another implementation scheme, such as Figures 1-8 As shown, the floating liquid level sensor 36 is streamlined and coated with a polytetrafluoroethylene coating.

[0039] A streamlined float is used to reduce water flow resistance. The material is selected to be wear-resistant and corrosion-resistant to avoid wear from solid particles. The guide rail structure is equipped with a vertical guide rail to restrict the float to only move up and down. The guide rail gap is ≤0.5mm to prevent solid particles from entering, and a sand discharge trough is set at the bottom of the guide rail to periodically discharge deposited particles. The float density must be between the two phases of the measured medium. For example, it is used to measure the stratification of gas and liquid layers to measure the liquid level, which facilitates the derivation of the overall liquid flow by the algorithm and system auxiliary data. The sensor output cable is led out through an explosion-proof sealed connector to meet the explosion-proof requirements of oil and gas scenarios.

[0040] In another implementation scheme, such as Figures 1-8 As shown, mounting tube 17 is evenly distributed around the outside of the main mounting tube 1. The positions of mounting tube 17 and mounting tube 2 18 correspond to the positions of the embedded quartz window 31. Flange plates are movably installed on the outside of mounting tube 17 and mounting tube 2 18. A supplementary light source is provided inside mounting tube 2 18. The measurement methods of the optical measurement sensor 38 include laser Doppler velocimetry, near-infrared spectral sensing, laser absorption current meter, high-speed imaging velocimetry, and laser diffraction particle analysis.

[0041] Laser Doppler velocimetry measures flow velocity by irradiating trace particles in a gas with a laser and measuring the frequency shift of the scattered light. This flow velocity is then calculated by combining the cross-sectional area of ​​the branch pipe. The signal difference originates from the particle motion itself and requires no reference light calibration. Tunable diode laser absorption spectroscopy measures flow velocity and component concentration simultaneously by measuring the absorption intensity of a specific wavelength of laser light by the gas, indirectly deducing flow rate. Near-infrared light penetrating an oil layer shows different absorption intensities by oil and water of different wavelengths, allowing for the simultaneous inference of water cut and flow velocity. This, combined with the cross-sectional area of ​​the oil layer, allows for the calculation of oil flow rate. Laser diffraction measures solid particle concentration, and a high-speed camera captures the liquid flow trajectory to calculate flow velocity. Combining the cross-sectional area of ​​the solid and liquid layers with water cut, water flow rate and solid flux are derived respectively. Laser absorption velocimeters are based on the Doppler absorption of gas molecules after absorbing laser light. A reference light is used to stabilize the laser power, offsetting the effects of temperature and pressure changes on light intensity and improving the accuracy of flow velocity measurement. Overall advantages include no need to insert into the pipe, avoiding the impact of solid particle abrasion and media corrosion on the sensor, extending its service life, no pressure loss, no change to the flow channel structure, no increase in system pressure loss, and suitability for low-velocity separation conditions in large expansion space sections. The aforementioned optical measurements are selected and adapted according to actual needs. If a reference light measurement method is required, auxiliary measurements are needed through the built-in reference light sources in mounting tube 17 and mounting tube 2 18 at the optical measurement receiver. When a reference light-free method is selected, mounting tube 2 18 serves as an observation window and supplements ambient light. The measurement scheme is selected based on different representations, such as gas phase measurement, oil phase / water content measurement, gas phase / liquid flow velocity measurement, solid-liquid phase measurement, oil phase measurement, etc. After the measurements are collected, the system performs supplementary calculations and displays the values. Key precautions: The core function of the reference light is only to "cancele system interference" such as light intensity attenuation, ambient light, and window contamination; it does not participate in the signal calculation of the measurement itself. For techniques requiring a reference light, it is necessary to ensure that the wavelength of the reference light and the measurement light are consistent, the optical paths are parallel, and the distance between them is ≤5mm to avoid calibration failure due to deviation of the two optical paths. In scenarios with high sand content and easily contaminated viewing windows, such as bottom solid-liquid phase measurements, even for techniques that do not require a reference light, it is recommended to install a "light intensity monitoring module" to indirectly replace the calibration function of the reference light.

[0042] In another implementation scheme, such as Figures 1-8 As shown, array-type capacitive sensors 30 are linearly and uniformly distributed on the outside of discharge pipe 1 24, and electromagnetic induction sensors 29 are linearly and uniformly distributed on the outside of discharge pipe 25. Both discharge pipe 1 24 and discharge pipe 25 are inclined. Both discharge pipe 1 24 and discharge pipe 25 are equipped with valve 4 27 at the bottom. Both discharge pipe 1 24 and discharge pipe 25 are connected to spiral sealing caps 28 by threads on the opposite sides of the discharge pipe 1 24 and discharge pipe 25. Electromagnetic induction sensors 29 and array-type capacitive sensors 30 are located on the opposite sides of valve 4 27 and spiral sealing caps 28.

[0043] When the liquid inside the main mounting pipe 1 passes through the filter screen 34 and traps solids, it is guided through the discharge pipe 24 to the location of the array-type capacitive sensor 30. Adjacent electrode plates of the array-type capacitive sensor 30 form a capacitor unit. As solid particles accumulate, the capacitance value increases with the dielectric constant of the medium, increasing as follows: solid > water > oil. When the capacitance value at a certain height suddenly jumps from "low capacitance in the liquid layer" to "high capacitance in the solid layer," this height is the accumulation line. Meanwhile, at the other end, fine metal sand and extremely small particles accumulate inside the discharge pipe 25 and reach the location of the electromagnetic induction sensor 29. The transmitting coil of the electromagnetic induction sensor 29 transmits alternating current to generate an alternating magnetic field. When metallic solid particles accumulate, eddy currents are generated, causing the induced voltage of the receiving coil to attenuate. Non-magnetic solids such as quartz sand alter the magnetic field distribution, making the induced voltage decrease. When impedance changes and the signal of a certain coil changes abruptly, the corresponding height is the accumulation line. By detecting the accumulated particles, the system can reach the location that needs to be cleaned. At this time, the operator closes valve 27 and unscrews the spiral sealing cap 28 to discharge the particles inside discharge pipe 24 and discharge pipe 25. The system is easy to maintain and indirectly increases the service life of the structure. The structure design of the array-type capacitive sensor 30 is to arrange 2 to 4 rows of sensor arrays along the axial direction of the lower half of the pipe. Each row contains 8 to 16 electrode plates with a spacing of 5 to 10 mm, covering the lower half of the pipe height. The electrode plates are insulated from the inner wall of the pipe and the lining is made of PTFE. The structure design of the electromagnetic induction sensor 29 is to install a dual coil module of "transmitting coil and receiving coil" at the bottom of the pipe. 3 to 5 groups of coils are arranged in layers along the radial direction of the pipe with a spacing of 8 to 15 mm between each group. The coil axis is perpendicular to the pipe axis.

[0044] In another implementation scheme, such as Figures 1-8 As shown, the intelligent controller 19 has a built-in real-time signal filtering algorithm, feature extraction algorithm, AI error calibration model, data fusion module, and remote monitoring and fault diagnosis system.

[0045] The intelligent controller 19 is an existing intelligent control hardware with a detection and control system. Its core hardware includes a high-stability laser emission module, a high-sensitivity photodetector, an embedded processor, an integrated temperature and pressure auxiliary sensor, and an industrial communication module. At the system level, it features real-time signal filtering algorithms (such as Kalman filtering), feature extraction algorithms (such as scattered light frequency / diffraction pattern analysis), AI error calibration models (such as machine learning to correct flow field interference), a data fusion module (linking temperature and pressure / phase measurement data), and a remote monitoring and fault diagnosis system. It is used for auxiliary optical detection through optical emission and detection, and for measurement through auxiliary derivation using temperature, pressure, and mass flow rate. Through precise signal acquisition by hardware and intelligent processing and calibration by software, it achieves stable and accurate measurement using optical measurement methods. The input terminals of the intelligent controller 19 are electrically connected via wires to the signal output terminals of the straight-tube Coriolis mass flow meter 4, the temperature and pressure auxiliary sensor 7, the gas flow meter 11, the electromagnetic induction sensor 29, the array capacitive sensor 30, the floating liquid level sensor 36, and the optical measurement sensor 38 for optical measurement and error compensation.

[0046] Although embodiments of the invention have been shown and described, it will be understood by those skilled in the art that various changes, modifications, substitutions and alterations can be made to these embodiments without departing from the principles and spirit of the invention, the scope of which is defined by the appended claims and their equivalents.

Claims

1. A metering device for mixed oil, gas and water transportation, comprising a main installation pipe (1), characterized in that: One end of the main mounting pipe (1) is bolted to a flow guide shroud one (2), the input end of the flow guide shroud one (2) is connected to an input pipe (3), the other end of the input pipe (3) is bolted to a straight-tube Coriolis mass flow meter (4), the input end of the straight-tube Coriolis mass flow meter (4) is connected to a connecting pipe (5), the end of the main mounting pipe (1) away from the flow guide shroud one (2) is bolted to a flow guide shroud two (16), the output end of the flow guide shroud two (16) is connected to an output pipe (14), the top of the output pipe (14) is connected to an inlet connecting pipe (13), the... A fixing ring (26) is fixedly sleeved on the outer side of both the first (2) and the second (16) of the flow guide. A temperature and pressure auxiliary sensor (7) is installed on the top of the main mounting pipe (1). An outlet connecting pipe (8) is connected to the top of the main mounting pipe (1). A flow guide (10) is installed at the top of the outlet connecting pipe (8). A sampling valve (9) is connected to the top of the flow guide (10). A gas flow meter (11) is installed on the top of the middle part of the flow guide (10). A valve (12) is installed on the top of the end of the flow guide (10) away from the sampling valve (9). A fixed ring (26) is installed on the inner wall of the first (2) of the flow guide. The system is equipped with several auxiliary springs (33), and a filter screen (34) is fixedly installed at the other end of each auxiliary spring (33). A spiral guide plate (32) is fixedly installed inside the input pipe (3), and the spiral angle of the spiral guide plate (32) is in the range of 30°~60°. A telescopic guide rail (35) is fixedly installed at the top of the inner cavity of the guide cover (16), and a floating liquid level sensor (36) is installed at the bottom end of the telescopic guide rail (35). Several embedded quartz windows (31) are fixedly installed on the inner wall of the main mounting pipe (1), and a filter screen (34) is fixedly installed on the outer side of the main mounting pipe (1). There are several mounting tubes (17), and two mounting tubes (18) are fixedly installed on the outside of the main mounting tube (1). An optical measurement sensor (38) is installed inside the mounting tube (17). The bottom of the flow guide (2) is connected to the discharge tube (24), and the bottom of the flow guide (26) is connected to the discharge tube (25). An array-type capacitive sensor (30) is provided on the outside of the bottom end of the discharge tube (24), and an electromagnetic induction sensor (29) is provided on the outside of the bottom end of the discharge tube (25). An intelligent controller (19) is fixedly installed on the outside of the main mounting tube (1).

2. The metering device for mixed oil, gas and water transportation according to claim 1, characterized in that: The connecting pipe (5) is equipped with valve one (6), and the output pipe (14) is equipped with valve three (15). Flange rings are provided at the opposite ends of the connecting pipe (5) and the output pipe (14).

3. The metering device for mixed oil, gas and water transportation according to claim 1, characterized in that: Telescopic outriggers (20) are fixedly installed on both sides of the fixed ring (26). A support rod (22) is movably sleeved on the opposite side of the telescopic outrigger (20). A support pad (21) is fixedly installed at the bottom of the telescopic outrigger (20). A fixing hole (23) is opened inside the support pad (21).

4. The metering device for mixed oil, gas and water transportation according to claim 1, characterized in that: The end of the guide tube (10) away from the outlet connecting tube (8) is installed on the inner side of the top of the inlet connecting tube (13). A metal defoaming mesh (37) is fixedly installed on the top of the inner cavity of the main installation tube (1). The metal defoaming mesh (37) is located at the bottom of the outlet connecting tube (8).

5. A metering device for mixed oil, gas and water transportation according to claim 1, characterized in that: The filter screen (34) is movably sleeved on the inner wall of the flow guide shroud (2), the position of the filter screen (34) corresponds to the position of the discharge pipe (24), and the auxiliary spring (33) is evenly distributed in a circle inside the flow guide shroud (2).

6. A metering device for mixed oil, gas and water transportation according to claim 1, characterized in that: The optimal flow velocity range inside the main installation pipe (1) is 0.3 to 1.5 m / s, the lead of the spiral guide plate (32) is 0.8 to 1.5, the spiral guide plate (32) is composed of a UHMWPE liner and a stainless steel substrate, and the outer surface is coated with polytetrafluoroethylene.

7. A metering device for mixed oil, gas and water transportation according to claim 1, characterized in that: The floating liquid level sensor (36) is streamlined and coated with polytetrafluoroethylene.

8. A metering device for mixed oil, gas and water transportation according to claim 1, characterized in that: The first mounting tube (17) is evenly distributed around the outside of the main mounting tube (1). The positions of the first mounting tube (17) and the second mounting tube (18) correspond to the position of the embedded quartz window (31). Flange plates are movably installed on the outside of the first mounting tube (17) and the second mounting tube (18). A supplementary light source is provided inside the second mounting tube (18). The measurement methods of the optical measurement sensor (38) include laser Doppler velocimetry, near-infrared spectral sensing, laser absorption current meter, high-speed imaging velocimetry, and laser diffraction particle analysis.

9. A metering device for mixed oil, gas and water transportation according to claim 1, characterized in that: The array-type capacitive sensor (30) is linearly and uniformly distributed on the outside of the first discharge pipe (24), and the electromagnetic induction sensor (29) is linearly and uniformly distributed on the outside of the second discharge pipe (25). The first discharge pipe (24) and the second discharge pipe (25) are both inclined. The bottom of the first discharge pipe (24) and the second discharge pipe (25) are both equipped with a valve four (27). The opposite ends of the first discharge pipe (24) and the second discharge pipe (25) are both connected by a spiral sealing cap (28) through a thread. The electromagnetic induction sensor (29) and the array-type capacitive sensor (30) are both located on the opposite side of the valve four (27) and the spiral sealing cap (28).

10. A metering device for mixed oil, gas and water transportation according to claim 1, characterized in that: The intelligent controller (19) has a built-in real-time signal filtering algorithm, feature extraction algorithm, AI error calibration model, data fusion module and remote monitoring and fault diagnosis system.

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