Oil-water-gas multiphase flow array type measuring device

Abstract

The invention relates to the technical field of oil-water-gas three-phase fluid measuring equipment manufacturing, in particular to an oil-water-gas multiphase flow array type measuring device which is reasonable in structure and low in cost, and is characterized in that a three-way connector (45) is arranged on an oil well output liquid input pipeline (4) below an oil well output liquid input port (101); one output end of the three-way connector (45) is connected with an oil well output liquid input port (101) through a liquid inlet pipeline (401), the other output end of the three-way connector (45) is connected with a liquid drainage pipeline (2) through a bypass pipeline (5) or connected with an exhaust and liquid drainage confluence pipeline, and the exhaust and liquid drainage confluence pipeline is a pipeline formed after the liquid drainage pipeline and an exhaust pipeline are confluence; compared with a traditional pump discharging scheme, on the premise that the structural complexity and the device manufacturing cost are obviously reduced, emptying and emptying of the metering tank are achieved through gas separated out by three-phase flow and the control process, and it is guaranteed that the oil-water proportion and the liquid and gas amount are accurately and stably measured through an array type method.

Description

This application is a divisional application of a patent application filed on September 23, 2022, with application number 202211162010.6, and invention name “Oil-water-gas multiphase flow array measurement device and its application”. Technical field:

[0002] The invention relates to the technical field of manufacturing oil-water-gas three-phase fluid measurement equipment, in particular to an oil-water-gas multiphase flow array measurement device with reasonable structure and low cost. Background technology:

[0004] In oil production, accurate and stable monitoring of the three phases of oil, water and gas is the basis for increasing oilfield revenue, reducing costs and digital production. There is no automatic measurement technology at home and abroad that can meet the changing environment of oilfield sites and has acceptable cost-effective products to be promoted. Basically, it relies on time-consuming and labor-intensive metering tanks to measure liquid and gas and manual sampling to measure water content to meet production needs, such as the technical solutions described in patent CN200520123346.7.

[0005] A Chinese patent 201280001771.1 previously proposed by the inventor of this patent proposed an oil well output liquid oil content metering device, including a vertical metering separation tank, wherein the upper part, lower part and top of the metering separation tank are respectively provided with an oil well output liquid input pipeline, a liquid discharge pipeline and an exhaust pipeline, and the oil well output liquid input pipeline, the liquid discharge pipeline and the exhaust pipeline are respectively provided with a liquid inlet valve, a liquid discharge valve and an exhaust valve; at different specified heights in the vertical direction of the metering separation tank, a plurality of oil-water analysis measurement probes which are independent of each other but interconnected are arranged from bottom to top, and the oil-water analysis measurement array composed of these probes can not only measure the oil-water ratio of each oil-water layer in the metering separation tank in real time, and then obtain the total water content of the oil well output liquid required for oil field production, but also measure the liquid production and gas production of the oil well per unit time by monitoring the real-time changes of the liquid level in the metering separation tank, which is referred to as the array type oil well three-phase measurement method. Since the above scheme needs to measure the composition of oil and water in the tank, the entire metering separation tank needs to be emptied when each measurement is completed. It is not possible to leave bottom water or residual liquid in the metering tank like the existing liquid-gas measurement technology. However, the three-phase fluid used for drainage is always accompanied by oil, water and gas. During the drainage process, the residual liquid hanging on the inner wall of the metering tank also flows down continuously, resulting in the inability of the existing metering tank drainage technology to drain the metering tank completely. Therefore, for the drainage of patent 201280001771.1, the existing scheme is to use a drainage pump to drain the liquid so that the liquid in the metering separation tank can be drained after the inlet valve is closed. However, the addition of the drainage pump significantly increases the complexity of the mechanical structure and power distribution, and at the same time, increases the cost, reduces the safety and reliability of the measurement system, limits the development of its automatic measurement function, and cannot meet the requirements of unattended functions. Summary of the invention:

[0007] In view of the shortcomings and deficiencies in the prior art, the present invention proposes an oil-water-gas multiphase flow array measurement device with reasonable structure and low cost and its application.

[0008] The present invention is achieved by the following measures:

[0009] An oil-water-gas multiphase flow array measurement device is provided, comprising a vertical metering and separation tank body (1), an oil well produced liquid input port (101) is provided on the upper side of the metering and separation tank body (1), a liquid output port (102) is provided on the lower part of the metering and separation tank body (1), and a gas output port (103) is provided on the top of the metering and separation tank body (1), the oil well produced liquid input port is connected to an oil well produced liquid input pipeline (4), the liquid output port is connected to a liquid discharge pipeline (2), and the gas output port is connected to an exhaust pipeline (3), a liquid discharge valve (201) is provided on the liquid discharge pipeline, and an exhaust valve (301) is provided on the exhaust pipeline. The metering and separation tank is also provided with an oil-water analysis measurement array (105) composed of a plurality of probes, characterized in that at the oil well produced liquid input port, a liquid discharge valve (201) is provided on the exhaust pipeline, and an exhaust valve (301) is provided on the exhaust pipeline. A three-way joint (45) is provided on the oil well output liquid input pipeline (4) below (101); one output end of the three-way joint (45) is connected to the oil well output liquid input port (101) through the liquid inlet pipeline (401); the other output end is connected to the drainage pipeline (2) or to the exhaust and drainage confluence pipeline through the bypass pipeline (5); the exhaust and drainage confluence pipeline is the pipeline after the drainage pipeline and the exhaust pipeline are confluenced; the bypass pipeline (5) through which the three-way joint (45) is connected to the drainage pipeline is provided with a bypass valve (501); the drainage pipeline (2) and the exhaust pipeline (3) are provided with a drainage valve (201) and an exhaust valve (301) respectively; the connection between the bypass pipeline (5) and the drainage pipeline (2) is located after the drainage valve (201).

[0010] The probe close to the bottom among the multiple probes of the oil-water analysis measurement array (105) of the present invention serves as a liquid level switch for liquid discharge alarm.

[0011] There is a predetermined height difference between the oil well production liquid input port (101) and the three-way joint (45) described in the present invention. The predetermined height difference described in the present invention is set to be large enough so that when the bypass pipeline is opened, pressure fluctuations in the liquid inlet pipeline will not cause liquid to overflow into the separation tank input port; further, the predetermined height difference may range from 5 cm to 500 cm.

[0012] In order to make the emptying operation more accurate and timely, the present invention can also connect an auxiliary measuring tank (6) in series on the discharge pipeline (2) behind the discharge valve (2) and before the intersection with the bypass pipeline (5). The high point of the liquid outlet of the auxiliary measuring tank (6) is lower than the high point of the liquid inlet by a predetermined height. Furthermore, the predetermined height can be 2.5 to 50 cm. A liquid level sensor (601) is also provided on the auxiliary measuring tank (6) for indicating the change of the liquid level in the tank.

[0013] In order to reduce the instantaneous overflow caused by the change of well pressure during the well change operation, the present invention connects a pressure regulating buffer tank (402) in series to the liquid inlet pipeline (401), and the pressure regulating buffer tank (402) has a predetermined volume. Furthermore, the predetermined volume can be 0.5 to 50 liters, which is used to buffer the instantaneous overflow caused by the pressure difference during the well change operation.

[0014] In order to realize automatic measurement in the present invention, it is necessary to set the above-mentioned valves as electric or pneumatic valves, and to provide an operation and control unit (7), which is electrically connected to each valve and each instrument. Furthermore, in order to realize continuous measurement of gas volume and liquid volume, a gas flow meter or a liquid flow meter is respectively connected in series to the exhaust pipeline (2) or the discharge pipeline (3) to expand the measurement function, and the gas flow meter or the liquid flow meter is electrically connected to the operation and control unit.

[0015] The present invention also proposes an application of the above-mentioned oil-water-gas multiphase flow array measurement device, which is characterized by comprising the following steps:

[0016] Step 1: In the initial state, the bypass valve (501) is in an open state, the exhaust valve (301) is in a closed state, the vertical metering and separation tank (1) is filled with gas, the oil well production fluid is transported out through the bypass pipeline (5), and the pressure inside the vertical metering and separation tank (1) is balanced with the pipeline pressure;

[0017] Step 2: Liquid inlet and measurement: When measuring the water content data of the oil well produced liquid, close the bypass valve (501) and the drain valve (201), open the exhaust valve (301), and the oil well produced liquid enters the vertical metering separation tank (1). After the gas and liquid in the oil well produced liquid are separated, the gas is discharged through the exhaust pipe (3) and the liquid flows into the vertical metering separation tank (1). At this time, the liquid level in the vertical metering separation tank (1) gradually rises. The change of the liquid level and its time are monitored in real time through the oil-water analysis array (105) or the liquid level switch to obtain The change in the liquid level in the tank over a period of time is combined with the corresponding tank capacity table to convert the oil well production volume; before the tank is full, the exhaust valve (301) is closed and the bypass valve (501) is opened, and the measured oil well production volume is discharged through the bypass pipeline (5), and the central control and processing unit (7) controls each oil-water measuring sensor on the oil-water analyzer array (105) to measure the oil-water composition of the liquid thin layer corresponding to the current oil-water measuring sensor, and combines the known tank capacity table to cumulatively calculate the water content of the oil-water mixed liquid;

[0018] When measuring the gas content of the oil well produced liquid, the drain valve (201) is opened, the bypass valve (501) and the exhaust valve (301) are closed, and the oil well produced liquid enters the metering separation tank for gas-liquid separation, and then flows out of the metering separation tank body (1) along the drain pipe (2), and the liquid level in the tank gradually decreases. The change of the liquid level and its time are monitored in real time through the oil-water analysis array or the liquid level switch, and the liquid level change over a period of time is combined with the corresponding tank capacity table to convert the gas production of the oil well;

[0019] Step 3: The tank is emptied to prepare for the next measurement: At this time, the drain valve (201) is in an open state, the bypass valve (501) and the exhaust valve (301) are in a closed state, the oil-water-gas mixture is fully separated in the metering tank, and the liquid can be pushed to be quickly discharged through the drain pipe (2). When the liquid level in the metering separation tank (1) reaches the liquid level setting value, the bypass valve (501) is opened, and the drain valve (201) and the exhaust valve (301) are kept unchanged. The liquid level setting value is at the lower part of the tank body of the metering separation tank (1), and the liquid level setting value is greater than the lowest value of the liquid level in the metering separation tank (1). At this time, most of the oil well production fluid is transported out through the bypass pipe (5), and part of the gas precipitated from the oil well production fluid input pipe (4) and the bypass pipe (5) is discharged due to the kinetic energy of the three-phase flow itself and the gas-liquid density difference. Under the dual effects of the liquid inlet pipe (401), the liquid continues to flow upwards into the metering separation tank (1), and the gas without liquid is used to push the remaining liquid and the liquid hanging on the wall to slowly discharge from the metering separation tank (1). In this process, at the intersection (25) or (23) of the discharge pipe (2) and the bypass pipe (5), the Bernoulli effect of the fast-flowing liquid and the slow-flowing liquid is used to strengthen the liquid discharge. At this time, the liquid level in the tank continues to drop. When the liquid level switch at the bottom of the metering separation tank (1) or the liquid level gauge on the small buffer measuring tank located on the discharge pipe (2) displays an alarm signal, the residual liquid in the metering separation tank (1) is completely discharged and the discharge valve (201) is closed, thereby ensuring that the metering separation tank is in an empty and clean state, completing a complete measurement process, and preparing for the next measurement.

[0020] Step 2 of the present invention also includes a method for continuously measuring the gas flow rate using a flow meter connected in series to the exhaust pipeline (2), or continuously measuring the liquid flow rate using a liquid flow meter connected in series to the discharge pipeline (2) when performing continuous gas parameter measurement or liquid parameter measurement: by coordinating and controlling the exhaust valve or the discharge valve, the gas and liquid are stably separated in the metering separation tank (1), and the gas flow rate or liquid flow rate is continuously read at the same time. At this time, the metering separation tank (1) plays the role of a gas-liquid separator. At the end of the continuous measurement, the total liquid level in the metering separation tank is controlled to the starting liquid level of the continuous measurement by adjusting the discharge valve (201) or the exhaust valve (301) to eliminate unnecessary errors.

[0021] The method for emptying a tank in an array type oil-water-gas multiphase flow measuring device of the present invention comprises opening a bypass valve (501) when the liquid in a metering separation tank (1) reaches a set value, and keeping the original state of a liquid discharge valve (201) and an air discharge valve (301) unchanged. At this time, most of the oil well produced liquid is transported out through a bypass pipeline (5), and part of the gas precipitated from the oil well produced liquid input pipeline (4) and the bypass pipeline (5) continues to enter the metering system upward along a liquid inlet pipeline (401) under the dual effects of the kinetic energy of the three-phase flow itself and the gas-liquid density difference. The separation tank (1) uses a gas without liquid to push the remaining liquid and the liquid hanging on the wall to slowly discharge from the metering separation tank (1). At this time, the liquid level in the tank continues to drop. When the liquid level switch located at the bottom of the metering separation tank (1) or the liquid level gauge on the small buffer measuring tank located on the discharge pipeline (2) displays an alarm signal, the residual liquid in the metering separation tank (1) is completely discharged and the discharge valve (201) is closed, thereby ensuring that the metering separation tank is in an empty and drained state, completing a complete measurement process, and preparing for the next measurement.

[0022] Compared with the traditional pumping scheme, the present invention realizes the emptying of the metering tank by utilizing the gas released by the three-phase flow and the control process, while significantly reducing the structural complexity and the device cost, thereby ensuring the accuracy and stability of measuring the oil-water ratio and the liquid and gas volumes by the array method; at the same time, because the complex pumping system is omitted, not only the failure points are significantly reduced, but also, except for the short time of specific measurement, at other times it can be ensured that at least one of the drain valve or the exhaust valve is in the open state, so as to form an external transmission passage for the oil well production, which significantly improves the safety of the measurement system and meets the requirements of remote control and unattended on-site operation. Description of the drawings:

[0024] Attached Figure 1 It is a structural schematic diagram of the present invention.

[0025] Attached Figure 2 The present invention is a structural schematic diagram of a small auxiliary measuring tank and a pressure regulating buffer tank.

[0026] Attached Figure 3 It is a schematic diagram of the small and medium-sized auxiliary measuring tank of the present invention.

[0027] Attached Figure 4 It is a structural schematic diagram of a pressure regulating buffer tank and a continuous measuring gas or liquid flow meter of the present invention.

[0028] Figure numerals: metering separation tank (1), oil well production liquid input port (101), discharge port (102), exhaust port (103), sampling port (104), oil-water analyzer array (105), temperature transmitter (106), pressure transmitter (107), discharge pipeline (2), discharge valve (201), liquid flow meter (202), exhaust pipeline (3), exhaust valve (301), gas flow meter (302), production liquid input pipeline (4), liquid inlet pipe section (401), pressure regulating buffer tank (402), bypass pipeline (5), bypass valve (501), auxiliary measurement tank (6), liquid level sensor (601), central control and processing unit (7), discharge and bypass pipeline junction (25), three-way connector (45), gas-liquid pipeline junction (23). Specific implementation method:

[0030] The present invention will be further described below in conjunction with the accompanying drawings and embodiments.

[0031] Embodiment 1:

[0032] As attached Figure 1 As shown, this example proposes an oil-water-gas multiphase flow array measurement device, which is provided with a vertical metering separation tank (1), an oil well production liquid input port (101) is provided on the side of the upper middle part of the metering separation tank (1), a liquid discharge port (102) is provided at the lower part of the metering separation tank (1), and an exhaust port (103) is provided at the top of the metering separation tank (1), the oil well production liquid input port (101) is connected to the oil well production liquid input pipeline, the liquid discharge port (102) is connected to the liquid discharge pipeline (2), the exhaust port (103) is connected to the exhaust pipeline (3), and the liquid discharge pipeline (2) is provided with A discharge valve (201), an exhaust valve (301) is provided on the exhaust pipeline (3), an oil-water analyzer array (105) composed of a plurality of probes is also provided on the metering separation tank (1), a three-way joint (45) is provided on the production liquid input pipeline (4), one output end of the three-way joint (45) is connected to the oil well production liquid input port (101), and the other output end is connected to the discharge pipeline (2), and then connected to the exhaust and discharge confluence pipeline, the exhaust and discharge confluence pipeline is the pipeline after the discharge pipeline (2) and the exhaust pipeline (3) are merged;

[0033] The pipeline between the three-way joint (45) and the oil well production fluid input port (101) is the liquid inlet pipe section (401), the pipe section connecting the three-way joint (45) and the liquid discharge pipe (2) is the bypass pipe (5), a bypass valve (501) is provided on the bypass pipe (5), and the connection between the three-way joint (45) and the liquid discharge pipe (2) is located before the liquid discharge valve (201); there is a height difference between the oil well production fluid input port (101) and the three-way joint (45), and the height difference ranges from 5 cm to 500 cm.

[0034] In this example, one output end of the three-way joint (45) on the oil well output liquid input pipeline is connected to the oil well output liquid input port, and the other output end is connected to the drainage pipeline (2), and then connected to the exhaust and drainage confluence pipeline. The exhaust and drainage confluence pipeline is the pipeline after the drainage pipeline and the exhaust pipeline are merged. When working, this example uses the signal given by the oil-water analysis unit located at the bottom of the metering separation tank to determine the timing of closing the drainage valve (201);

[0035] After the measurement is completed, the oil-water-gas mixture is fully separated from the gas and liquid in the metering tank and the liquid is pushed to be discharged through the liquid discharge pipeline (2). When the liquid in the metering separation tank (1) reaches the set value, the bypass valve is opened, and the liquid discharge valve and the exhaust valve are kept in their original states. Most of the oil well production liquid is transported out through the bypass pipeline (5). Under the dual effects of the kinetic energy of the three-phase flow itself and the gas-liquid density difference, part of the gas precipitated from the production liquid input pipeline (4) and the bypass pipeline (5) continues to enter the metering separation tank (1) along the liquid inlet pipeline (401). The gas without liquid is used to push the remaining liquid and the wall liquid to slowly discharge from the metering separation tank (1). The liquid level continues to drop. When the liquid level sensor located at the bottom of the metering separation tank (1) displays an alarm signal, the residual liquid in the metering separation tank (1) is completely discharged, and the liquid discharge valve (201) is closed in time, thereby ensuring that the metering separation tank (1) is in an empty and clean state, completing a complete measurement process, and preparing for the next measurement.

[0036] Embodiment 2:

[0037] This example has the same vertical metering separation tank structure as Example 1, as shown in the attached Figure 2 As shown, in this example, in order to make the emptying operation more accurate and timely, an auxiliary measuring tank (6) is connected in series to the discharge pipeline (2) behind the discharge valve (201) and before the junction with the bypass pipeline (5). Figure 3 As shown, the high point of the liquid outlet of the auxiliary measuring tank (6) is between 2.5 and 50 cm lower than the high point of the liquid inlet, and a liquid level sensor is also provided on the auxiliary measuring tank (6) to indicate the change of the liquid level in the tank;

[0038] During operation, the timing of closing the drain valve (201) is determined by using the signal given by the liquid level sensor located on the small auxiliary measuring tank (6), so that the draining and control are more reliable and stable.

[0039] Embodiment 3:

[0040] This example has the same vertical metering separation tank structure as Example 1. In order to reduce the instantaneous overflow caused by the change of well pressure during the well change operation, a pressure regulating buffer tank (402) (as shown in the attached figure) is connected in series to the liquid inlet section (401). Figure 4 The volume is 0.5 to 50 liters, which is used to buffer the instantaneous overflow caused by the pressure difference of the well.

[0041] In order to realize automatic measurement, each valve in this example is set as an electric or pneumatic valve, and is provided with an operation and control unit, which is electrically connected to each valve and each instrument. In order to realize continuous measurement of gas volume and liquid volume, a gas flow meter or liquid flow meter (such as the attached one) is connected in series to the exhaust pipeline or the discharge pipeline respectively. Figure 4 As shown), used to expand the measurement function, the gas flow meter or liquid flow meter is electrically connected to the operation and control unit.

[0042] The method of using the oil-water-gas multiphase flow array measurement device in this example is as follows:

[0043] In the initial state: the bypass valve (501) is in an open state, the exhaust valve (301) is in a closed state, the vertical metering and separation tank (1) is filled with gas, the oil well production fluid is transported out through the bypass pipeline (5), and the pressure inside the vertical metering and separation tank (1) is balanced with the pipeline pressure;

[0044] When measuring the water content data of the oil well produced liquid, the bypass valve (501) is closed and the exhaust valve (301) is opened, and the oil well produced liquid enters the vertical metering separation tank (1). After the gas and liquid in the oil well produced liquid are separated, the gas is discharged through the exhaust pipe (3) and the liquid flows into the vertical metering separation tank (1). At this time, the liquid level in the vertical metering separation tank (1) gradually rises. The change of the liquid level and its time are monitored in real time through the oil-water analysis array (105) or the liquid level switch. The change of the liquid level in the tank over a period of time is combined with the corresponding tank capacity table to convert the oil well produced liquid volume. Before the tank is full, the exhaust valve (301) is closed and the bypass valve (501) is opened. The measured oil well produced liquid is discharged through the bypass pipe (5). The central control and processing unit (7) controls each oil-water measuring sensor on the oil-water analyzer array (105) to measure the oil-water composition of the liquid thin layer corresponding to the current oil-water measuring sensor. Combined with the known tank capacity table, the water content of the oil-water mixed liquid is cumulatively calculated.

[0045] When measuring the gas content of the oil well produced liquid, the drain valve (201) is opened, the bypass valve (501) and the exhaust valve (301) are closed, and the oil well produced liquid enters the metering separation tank for gas-liquid separation, and then flows out of the metering separation tank body (1) along the drain pipe (2), and the liquid level in the tank gradually decreases. The change of the liquid level and its time are monitored in real time through the oil-water analysis array or the liquid level switch, and the liquid level change over a period of time is combined with the corresponding tank capacity table to convert the gas production of the oil well;

[0046] When continuously measuring gas parameters or liquid parameters, a flow meter connected in series to an exhaust pipe (2) is used to continuously measure the gas flow rate, or a liquid flow meter connected in series to a liquid discharge pipe (2) is used to continuously measure the liquid flow rate: by coordinating and controlling the exhaust valve or the liquid discharge valve, the gas and liquid are stably separated in the metering separation tank (1), and the gas flow rate or liquid flow rate is continuously read at the same time. At this time, the metering separation tank (1) plays the role of a gas-liquid separator. At the end of the continuous measurement, the total liquid level in the metering separation tank is controlled to the starting liquid level of the continuous measurement by adjusting the liquid discharge valve (201) or the exhaust valve (301) to eliminate unnecessary errors.

[0047] After the measurement is completed, the tank is emptied to prepare for the next measurement: the oil-water-gas mixture is fully separated into gas and liquid in the metering tank, and the liquid can be pushed to be discharged through the discharge pipeline (2). Specifically, when the liquid in the metering separation tank (1) reaches the set value, the bypass valve (501) is opened, and the discharge valve (201) and the exhaust valve (301) are kept unchanged. At this time, most of the oil well production liquid is transported out through the bypass pipeline (5), and part of the gas precipitated from the oil well production liquid input pipeline (4) and the bypass pipeline (5) is discharged upward along the inlet under the dual effects of the kinetic energy of the three-phase flow itself and the gas-liquid density difference. The liquid pipeline (401) continues to enter the metering separation tank (1), and the gas without liquid is used to push the remaining liquid and the liquid hanging on the wall to slowly discharge from the metering separation tank (1). At this time, the liquid level in the tank continues to drop. When the liquid level switch located at the bottom of the metering separation tank (1) or the liquid level gauge on the small buffer measuring tank located on the discharge pipeline (2) displays an alarm signal, the residual liquid in the metering separation tank (1) is completely discharged, and the discharge valve (201) is closed, thereby ensuring that the metering separation tank is in an empty and drained state, completing a complete measurement process, and preparing for the next measurement.

[0048] Compared with the traditional pumping scheme, the present invention does not need a permanent valve at the input port of the metering separation tank. Its function is to make full use of the associated gas spontaneously precipitated in the pipeline to realize the emptying and draining of the metering tank. On the other hand, except for the short time of specific measurement, at least one of the discharge valve or the exhaust valve can be guaranteed to be in an open state at other times. For the oil well production, an external transmission channel is formed, which significantly improves the safety of the measurement system and meets the requirements of remote control and unmanned on-site operation. Specifically, compared with the original pumping technology, it has the following advantages: (1) The optimized and simple equipment structure significantly reduces the equipment cost, while reducing the failure points and maintenance workload, improving the safety and reliability of measurement and control, and meeting the requirements of remote control and unmanned operation. (2) The technical solution adopts an imported normally open structure, which reduces the impact of the water hammer effect of measuring the well inversion on the equipment and pipeline, and further improves the safety of the equipment and pipeline. (3) The characteristics of the three-phase fluid itself are fully utilized for drainage, and the control, emptying and draining effects are stable and reliable. (4) The continuous measurement function of gas volume and liquid volume is added to meet the further needs of the oil field. Notes: 1. An array type measuring device for oil-water-gas multiphase flow, comprising a vertical metering and separation tank body (1), wherein an oil well produced liquid input port (101) is provided on the upper side of the metering and separation tank body (1), a liquid output port (102) is provided on the lower part of the metering and separation tank body (1), and a gas output port (103) is provided on the top of the metering and separation tank body (1), wherein the oil well produced liquid input port is connected to an oil well produced liquid input pipeline (4), the liquid output port is connected to a liquid discharge pipeline (2), and the gas output port is connected to an exhaust pipeline (3), a liquid discharge valve (201) is provided on the liquid discharge pipeline, and an exhaust valve (301) is provided on the exhaust pipeline, and an oil-water analysis measurement array (105) composed of a plurality of probes is further provided on the metering and separation tank, wherein the oil well produced liquid input port (101) is connected to an oil well produced liquid input pipeline (4), the liquid output port is connected to a liquid discharge pipeline (2), and the gas output port is connected to an exhaust pipeline (3), a liquid discharge valve (201) is provided on the liquid discharge pipeline, and an exhaust valve (301) is provided on the exhaust pipeline, and the oil-water analysis measurement array (105) composed of a plurality of probes is further provided on the metering and separation tank, wherein the oil well produced liquid input port (101) is connected to an oil well produced liquid input pipeline (4), the liquid discharge port is connected to a liquid discharge pipeline (2), and the gas discharge port is connected to an exhaust pipeline (3), A three-way joint (45) is provided on the oil well output liquid input pipeline (4) below the outlet (101); one output end of the three-way joint (45) is connected to the oil well output liquid input port (101) through a liquid inlet pipeline (401); the other output end is connected to the drainage pipeline (2) or to an exhaust and drainage confluence pipeline through a bypass pipeline (5); the exhaust and drainage confluence pipeline is a pipeline after the drainage pipeline and the exhaust pipeline are confluenced; a bypass valve (501) is provided on the bypass pipeline (5) through which the three-way joint (45) is connected to the drainage pipeline; a drainage valve (201) and an exhaust valve (301) are provided on the drainage pipeline (2) and the exhaust pipeline (3), respectively; and the connection between the bypass pipeline (5) and the drainage pipeline (2) is located after the drainage valve (201). 2. The oil-water-gas multiphase flow array measurement device according to clause 1 is characterized in that the probe close to the bottom of the multiple probes of the oil-water analysis measurement array (105) serves as a liquid level switch for drainage alarm. 3. The oil-water-gas multiphase flow array measurement device according to clause 1 is characterized in that there is a predetermined height difference between the oil well production fluid inlet (101) and the three-way joint (45). 4. An oil-water-gas multiphase flow array measuring device according to clause 1 is characterized in that an auxiliary measuring tank (6) is connected in series to the discharge pipeline (2) behind the discharge valve (2) and before the intersection with the bypass pipeline (5), the highest point of the liquid outlet of the auxiliary measuring tank (6) is lower than the highest point of the liquid inlet by a predetermined height, and a liquid level sensor (601) is also provided on the auxiliary measuring tank (6) to indicate changes in the liquid level in the tank. 5. The oil-water-gas multiphase flow array measurement device according to clause 1 is characterized in that a pressure regulating buffer tank (402) is connected in series to the liquid inlet pipeline (401), and the pressure regulating buffer tank (402) has a predetermined volume so that it can buffer the instantaneous overflow effect caused by the pressure difference of the well rotation. 6. The oil-water-gas multiphase flow array measuring device according to clause 1 is characterized in that a gas flow meter or a liquid flow meter is connected in series to the exhaust pipeline (2) or the drain pipeline (3) respectively to expand the measurement function, and the gas flow meter or the liquid flow meter is electrically connected to the operation and control unit. 7. The oil-water-gas multiphase flow array measurement device according to clause 3 is characterized in that the height difference is set large enough so that when the bypass pipeline is opened, pressure fluctuations in the liquid inlet pipeline will not cause liquid to overflow into the separation tank input port (101). 8. The oil-water-gas multiphase flow array measurement device according to clause 7 is characterized in that the height difference range is 5cm-500cm. 9. The oil-water-gas multiphase flow array measurement device according to clause 4, characterized in that the predetermined height is 2.5 to 50 cm. 10. The oil-water-gas multiphase flow array measurement device according to clause 5, characterized in that the predetermined volume is 0.5 to 50 liters. 11. An application of the oil-water-gas multiphase flow array measurement device according to any one of clauses 1 to 6, characterized in that it comprises the following steps: Step 1: In the initial state, the bypass valve (501) is in an open state, the exhaust valve (301) is in a closed state, the vertical metering and separation tank (1) is filled with gas, the oil well production fluid is transported out through the bypass pipeline (5), and the pressure inside the vertical metering and separation tank (1) is balanced with the pipeline pressure; Step 2: Liquid inlet and measurement: When measuring the water content data of the oil well produced liquid, close the bypass valve (501) and the drain valve (201), open the exhaust valve (301), and the oil well produced liquid enters the vertical metering separation tank (1). After the gas and liquid in the oil well produced liquid are separated, the gas is discharged through the exhaust pipe (3) and the liquid flows into the vertical metering separation tank (1). At this time, the liquid level in the vertical metering separation tank (1) gradually rises. The change of the liquid level and its time are monitored in real time through the oil-water analysis array (105) or the liquid level switch to obtain The change in the liquid level in the tank over a period of time is combined with the corresponding tank capacity table to convert the oil well production volume; before the tank is full, the exhaust valve (301) is closed and the bypass valve (501) is opened, and the measured oil well production volume is discharged through the bypass pipeline (5), and the central control and processing unit (7) controls each oil-water measuring sensor on the oil-water analyzer array (105) to measure the oil-water composition of the liquid thin layer corresponding to the current oil-water measuring sensor, and combines the known tank capacity table to cumulatively calculate the water content of the oil-water mixed liquid; When measuring the gas content of the oil well produced liquid, the drain valve (201) is opened, the bypass valve (501) and the exhaust valve (301) are closed, and the oil well produced liquid enters the metering separation tank for gas-liquid separation, and then flows out of the metering separation tank body (1) along the drain pipe (2), and the liquid level in the tank gradually decreases. The change of the liquid level and its time are monitored in real time through the oil-water analysis array or the liquid level switch, and the liquid level change over a period of time is combined with the corresponding tank capacity table to convert the gas production of the oil well. Step 3: The tank is emptied to prepare for the next measurement: At this time, the drain valve (201) is in an open state, the bypass valve (501) and the exhaust valve (301) are in a closed state, the oil-water-gas mixture is fully separated in the metering tank, and the liquid can be pushed to be quickly discharged through the drain pipe (2). When the liquid level in the metering separation tank (1) reaches the liquid level setting value, the bypass valve (501) is opened, and the drain valve (201) and the exhaust valve (301) are kept unchanged. The liquid level setting value is at the lower part of the tank body of the metering separation tank (1), and the liquid level setting value is greater than the lowest value of the liquid level in the metering separation tank (1). At this time, most of the oil well production fluid is transported out through the bypass pipe (5), and the oil well production fluid input pipe (4) and the bypass pipe (5) are separated. Under the dual effects of the kinetic energy of the three-phase flow and the gas-liquid density difference, part of the gas continues to enter the metering separation tank (1) upward along the liquid inlet pipeline (401), and uses the gas without liquid to push the remaining liquid and the wall liquid to slowly discharge from the metering separation tank (1). At the same time, with the help of the Bernoulli effect of the fast-flowing liquid and the slow-flowing liquid, the liquid discharge is strengthened. At this time, the liquid level in the tank continues to drop. When the liquid level switch located at the bottom of the metering separation tank (1) or the liquid level gauge on the small buffer measuring tank located on the discharge pipeline (2) displays an alarm signal, the residual liquid in the metering separation tank (1) is completely discharged and the discharge valve (201) is closed, thereby ensuring that the metering separation tank is in an empty and clean state, completing a complete measurement process, and preparing for the next measurement. 12. An application of an oil-water-gas multiphase flow array measurement device according to clause 11, characterized in that step 2 also includes a method of continuously measuring the gas flow rate using a flow meter connected in series to the exhaust pipeline (2), or continuously measuring the liquid flow rate using a liquid flow meter connected in series to the drain pipeline (2) when performing continuous gas parameter measurement or liquid parameter measurement: by coordinating and controlling the exhaust valve or the drain valve, the gas and liquid are stably separated in the metering separation tank (1), and the gas flow rate or liquid flow rate is continuously read at the same time. At this time, the metering separation tank (1) plays the role of a gas-liquid separator. At the end of the continuous measurement, the total liquid level in the metering separation tank is controlled to the starting liquid level of the continuous measurement by adjusting the drain valve (201) or the exhaust valve (301) to eliminate unnecessary errors. 13. A method for emptying a tank in an array type oil-water-gas multiphase flow measuring device as described in any one of clauses 1 to 6, comprising: when the liquid level in the metering separation tank (1) reaches a certain position in the lower part of the tank, opening the bypass valve (501) and keeping the drain valve (201) and the exhaust valve (301) unchanged in their original states, at which time most of the oil well produced liquid is transported out through the bypass pipeline (5), and part of the gas precipitated from the oil well produced liquid input pipeline (4) and the bypass pipeline (5) continues to enter the metering separation tank (1) upward along the liquid inlet pipeline (401) under the dual effects of the kinetic energy of the three-phase flow itself and the gas-liquid density difference, The remaining liquid and the liquid hanging on the wall are pushed slowly out of the metering separation tank (1) by gas without liquid. At the same time, the Bernoulli effect of the fast-flowing liquid and the slow-flowing liquid is used to strengthen the liquid discharge. At this time, the liquid level in the tank continues to drop. When the liquid level switch at the bottom of the metering separation tank (1) or the liquid level gauge on the small buffer measuring tank located on the discharge pipeline (2) displays an alarm signal, the residual liquid in the metering separation tank (1) is completely discharged and the discharge valve (201) is closed, thereby ensuring that the metering separation tank is in an empty and clean state, completing a complete measurement process, and preparing for the next measurement.

Claims

1. An oil-water-gas multiphase flow array measuring device, comprising a vertical metering and separation tank body (1), an oil well produced liquid input port (101) being provided on the upper side of the metering and separation tank body (1), a liquid output port (102) being provided on the lower part of the metering and separation tank body (1), and a gas output port (103) being provided on the top of the metering and separation tank body (1), the oil well produced liquid input port being connected to an oil well produced liquid input pipeline (4), the liquid output port being connected to a liquid discharge pipeline (2), the gas output port being connected to an exhaust pipeline (3), a liquid discharge valve (201) being provided on the liquid discharge pipeline, and an exhaust valve (301) being provided on the exhaust pipeline, and an oil-water analysis measurement array (105) consisting of a plurality of probes being further provided on the metering and separation tank, characterized in that: A three-way joint (45) is provided on the oil well produced liquid input pipeline (4) located below the oil well produced liquid input port (101), and one output end of the three-way joint (45) is connected to the oil well produced liquid input port (101) via a liquid inlet pipeline (401), wherein no drain valve is provided between the one output end of the three-way joint (45) and the oil well produced liquid input port (101), and a direct connection is maintained, and the other output end is connected to the drain pipe via a bypass pipe (5). The three-way joint (45) is connected to the liquid discharge pipeline (2), or is connected to an exhaust and liquid discharge confluence pipeline, wherein the exhaust and liquid discharge confluence pipeline is a pipeline after the liquid discharge pipeline and the exhaust pipeline are confluenced; a bypass valve (501) is provided on the bypass pipeline (5) through which the three-way joint (45) is connected to the liquid discharge pipeline, and a liquid discharge valve (201) and an exhaust valve (301) are provided on the liquid discharge pipeline (2) and the exhaust pipeline (3), respectively, and the connection between the bypass pipeline (5) and the liquid discharge pipeline (2) is located after the liquid discharge valve (201).

2. The oil-water-gas multiphase flow array measurement device according to claim 1, characterized in that: The probe close to the bottom of the plurality of probes of the oil-water analysis measurement array (105) serves as a liquid level switch for liquid discharge alarm.

3. The oil-water-gas multiphase flow array measurement device according to claim 1, characterized in that: There is a predetermined height difference between the oil well produced fluid input port (101) and the three-way joint (45).

4. The oil-water-gas multiphase flow array measurement device according to claim 1, characterized in that: An auxiliary measuring tank (6) is connected in series to the discharge pipeline (2) behind the discharge valve (2) and before the junction with the bypass pipeline (5). The height of the liquid outlet of the auxiliary measuring tank (6) is lower than the height of the liquid inlet by a predetermined height. A liquid level sensor (601) is also provided on the auxiliary measuring tank (6) for indicating the change of the liquid level in the tank.

5. The oil-water-gas multiphase flow array measurement device according to claim 1, characterized in that: A pressure regulating buffer tank (402) is connected in series to the liquid inlet pipeline (401), and the pressure regulating buffer tank (402) has a predetermined volume so as to buffer the instantaneous overflow effect caused by the pressure difference during well rotation.

6. The oil-water-gas multiphase flow array measurement device according to claim 1, characterized in that: A gas flow meter or a liquid flow meter is respectively connected in series to the exhaust pipeline (2) or the liquid discharge pipeline (3) to expand the measurement function. The gas flow meter or the liquid flow meter is electrically connected to the calculation and control unit.

7. The oil-water-gas multiphase flow array measurement device according to claim 3, characterized in that The height difference is set large enough so that when the bypass pipeline is opened, pressure fluctuations in the liquid inlet pipeline will not cause liquid to overflow into the separation tank input port (101).

8. The oil-water-gas multiphase flow array measurement device according to claim 7, characterized in that The height difference range is 5cm-500cm.

9. The oil-water-gas multiphase flow array measurement device according to claim 4, characterized in that The predetermined height is 2.5 to 50 cm.

10. The oil-water-gas multiphase flow array measurement device according to claim 5, characterized in that The predetermined volume is 0.5 to 50 liters.

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