Offshore platform production separator gas phase flow measurement system

Abstract

The utility model discloses an offshore platform production separator gas phase flow measurement system, including three -phase separator, orifice plate differential pressure flowmeter, differential pressure transmitter and gas -liquid separation device, three -phase separator is connected with the import end of orifice plate differential pressure flowmeter, gas -liquid separation device includes the container, and the circumferential side wall of container is equipped with the air inlet, and the top of container is equipped with the gas outlet, and the filter plate is equipped in container, and the filter plate interval sets up and is located between air inlet and gas outlet, the high pressure port of orifice plate differential pressure flowmeter is connected through the first pressure -drain pipe with air inlet, and the high pressure measurement chamber of differential pressure transmitter is connected through the second pressure -drain pipe with air inlet, and the low pressure port of orifice plate differential pressure flowmeter is connected through the third pressure -drain pipe with the low pressure measurement chamber of differential pressure transmitter. Through the application gas -liquid separation device, the liquid component in mixed gas is effectively separated, thereby guaranteeing that orifice plate differential pressure flowmeter can accurately, stably measure gas flow under the gas -liquid miscible flow environment, and effectively solve liquid interference problem.

Description

Technical Field

[0001] This utility model relates to the field of offshore platform measurement technology, and in particular to a gas phase flow measurement system for an offshore platform production separator. Background Technology

[0002] like Figure 1 As shown, in the three-phase separator 10 used on offshore oil drilling and production platforms, an orifice plate differential pressure flow meter 20 is installed at the gas phase outlet to measure gas flow. The orifice plate differential pressure flow meter 20 is connected to the differential pressure transmitter 30 via a pressure tap. However, due to the influence of high temperature and saturated steam inside the three-phase separator 10, the medium flowing through the orifice plate differential pressure flow meter 20 is often in a gas-liquid two-phase flow state. With the high-frequency logging at the production site, the gas-liquid ratio of the medium introduced into the three-phase separator 10 fluctuates greatly, resulting in impure gas phase separation and mixed impurities flowing through the orifice plate differential pressure flow meter 20.

[0003] The orifice plate differential pressure flowmeter 20 selected on-site is based on the principle that when gas flows through a throttling orifice plate, the flow velocity increases and the static pressure decreases, creating a pressure difference before and after the orifice plate. The flow rate is calculated using the formula Q = CdA√(2ΔP / ρ). Cd is the flow coefficient, which depends on the type, size, and installation method of the orifice plate and is generally a constant; A is the cross-sectional area of ​​the orifice plate, also a constant; ΔP represents the pressure difference before and after the orifice plate, and ρ is the fluid density. Therefore, any factor affecting the differential pressure and fluid density will cause fluctuations in the flow measurement.

[0004] (a) Factors affecting differential pressure and gas phase fluid density include:

[0005] 1. Liquid content in the gas phase: Because the formula of the orifice plate differential pressure flow meter 20 involves the density parameter of the fluid, if the actual gas density fluctuates due to the liquid content, the orifice plate differential pressure flow meter 20 will drift continuously.

[0006] 2. The differential pressure signal fluctuation problem caused by two-phase flow: The orifice plate differential pressure flowmeter 20 is designed for single-phase flow. When there is gas-liquid two-phase flow, the flow state may become unstable, such as forming slug flow or stratified flow. These flow states will cause differential pressure signal fluctuation, thus making the measured value unstable.

[0007] 3. Liquid accumulation in the pressure-conducting tube: If the liquid in the pressure-conducting tube cannot be drained in time, it may cause the differential pressure measurement value to be too high or too low. Especially when the external temperature drops, the liquid may condense, which will further affect the measurement.

[0008] (II) Traditional solutions include the following:

[0009] 1. Based on the physical properties of the medium at the outlet of the three-phase separator 10, the orifice plate differential pressure flowmeter 20 is calibrated periodically, and the correction coefficient of the differential pressure transmitter 30 is adjusted to perform dynamic compensation to prevent error accumulation and measurement drift.

[0010] 2. Promptly disassemble the pressure tapping pipe, clean internal impurities and liquid accumulation in the discharge pipe to ensure that the gas phase at both high and low pressure ends of the differential pressure transmitter is clean.

[0011] 3. Insulating the pressure tapping pipe reduces the condensation of liquid-containing gas inside the pipe due to temperature drop. However, the effect is not ideal, as water vapor condensation is still unavoidable, and the amount of condensate is large. Utility Model Content

[0012] The technical problem to be solved by this utility model is to provide a gas phase flow measurement system for a production separator on an offshore platform.

[0013] The technical solution adopted by this utility model to solve its technical problem is: to construct a gas phase flow measurement system for a production separator on an offshore platform, including a three-phase separator, an orifice plate differential pressure flow meter, a differential pressure transmitter, and a gas-liquid separation device; the three-phase separator is connected to the inlet end of the orifice plate differential pressure flow meter;

[0014] The gas-liquid separation device includes a container, an air inlet on the circumferential side wall of the container, an air outlet on the top of the container, and a plurality of filter plates inside the container, the plurality of filter plates being spaced apart and disposed between the air inlet and the air outlet.

[0015] The air inlet is connected to the high-pressure port of the orifice plate differential pressure flow meter via a first pressure-sensing pipe, the air inlet is connected to the high-pressure measuring chamber of the differential pressure transmitter via a second pressure-sensing pipe, and the low-pressure port of the orifice plate differential pressure flow meter is connected to the low-pressure measuring chamber of the differential pressure transmitter via a third pressure-sensing pipe.

[0016] In some embodiments, the three-phase separator is connected to the inlet end of the orifice plate differential pressure flow meter via a connecting pipe, and a first valve is provided on the connecting pipe.

[0017] In some embodiments, a second valve and a third valve are provided at intervals on the first pressure tapping tube, the second valve being located near the high-pressure port of the orifice plate differential pressure flow meter, and the third valve being located near the air inlet.

[0018] In some embodiments, a fourth valve and a fifth valve are provided at intervals on the second pressure tap, the fourth valve being located near the air outlet and the fifth valve being located near the high-pressure measurement chamber of the differential pressure transmitter.

[0019] In some embodiments, a sixth valve and a seventh valve are provided at intervals on the third pressure tap, the sixth valve being located near the low-pressure port of the orifice plate differential pressure flowmeter, and the seventh valve being located near the low-pressure measurement chamber of the differential pressure transmitter.

[0020] In some embodiments, the filter plate is detachably connected to the inner wall of the container.

[0021] In some embodiments, the inner wall of the container is provided with slots on opposite sidewalls, and the two sides of the filter plate are respectively inserted into the slots.

[0022] In some embodiments, the angle formed between the plane of the filter plate and the bottom wall of the container is an acute angle.

[0023] In some embodiments, the filter plate is provided with a plurality of circular holes, the inner diameter of which is 3mm-5mm.

[0024] In some embodiments, the circumferential sidewall of the container is provided with at least one drain hole near the bottom wall of the container, and the offshore platform production separator gas phase flow measurement system further includes a drain pipe connected to the drain hole, and the drain pipe is provided with at least one eighth valve.

[0025] The implementation of this utility model has the following beneficial effects: The gas phase flow measurement system of the offshore platform production separator effectively separates the liquid components in the mixed gas by applying a gas-liquid separation device, thereby ensuring that the orifice plate differential pressure flow meter can accurately and stably measure the gas flow in a gas-liquid mixed flow environment, and effectively solves the problem of liquid interference. Attached Figure Description

[0026] To more clearly illustrate the technical solution of this utility model, the present utility model will be further described below in conjunction with the accompanying drawings and embodiments. It should be understood that the following drawings only show some embodiments of this utility model and should not be considered as a limitation of the scope. For those skilled in the art, other related drawings can be obtained from these drawings without creative effort. In the drawings:

[0027] Figure 1 This is a schematic diagram of the structure of a separator gas phase flow measurement system in related technologies;

[0028] Figure 2 This is a schematic diagram of the structure of the gas phase flow measurement system for the offshore platform production separator in some embodiments of this utility model;

[0029] Figure 3 This is a schematic diagram of the installation of the filter plate in some embodiments of this utility model;

[0030] Figure 4This is a schematic diagram of the filter plate in some embodiments of this utility model;

[0031] Figure 5 This is a schematic diagram of the filter plate in some other embodiments of the present invention. Detailed Implementation

[0032] To provide a clearer understanding of the technical features, objectives, and effects of this utility model, the specific embodiments of this utility model are now described in detail with reference to the accompanying drawings. In the following description, it should be understood that the orientations or positional relationships indicated by terms such as "front," "rear," "upper," "lower," "left," "right," "longitudinal," "horizontal," "vertical," "horizontal," "top," "bottom," "inner," "outer," "head," and "tail" are based on the orientations or positional relationships shown in the accompanying drawings, and are constructed and operated in a specific orientation. They are only for the convenience of describing this technical solution and do not indicate that the device or component referred to must have a specific orientation; therefore, they should not be construed as limitations on this utility model.

[0033] It should also be noted that, unless otherwise explicitly specified and limited, terms such as "installation," "connection," "joining," "fixing," and "setting" should be interpreted broadly. For example, they can refer to a fixed connection, a detachable connection, or an integral part; they can refer to a mechanical connection or an electrical connection; they can refer to a direct connection or an indirect connection through an intermediate medium; they can refer to the internal communication of two components or the interaction between two components. When an component is referred to as being "on" or "below" another component, the component can be located "directly" or "indirectly" on the other component, or there may be one or more intermediary components. The terms "first," "second," "third," etc., are only for the convenience of describing this technical solution and should not be construed as indicating or implying relative importance or implicitly specifying the number of indicated technical features. Therefore, features defined with "first," "second," "third," etc., may explicitly or implicitly include one or more of that feature. For those skilled in the art, the specific meaning of the above terms in this utility model can be understood according to the specific circumstances.

[0034] In the following description, specific details such as particular system structures and techniques are set forth for illustrative purposes and not for limitation, in order to provide a thorough understanding of the embodiments of the present invention. However, those skilled in the art will understand that the present invention can be implemented in other embodiments without these specific details. In other instances, detailed descriptions of well-known systems, apparatuses, circuits, and methods are omitted so as not to obscure the description of the present invention with unnecessary detail.

[0035] Whether the differential pressure signal fluctuation is caused by two-phase flow or the measurement accuracy is affected by condensate in the pressure tapping tube, the root cause is the liquid content in the gas phase leading to measurement drift in the differential pressure transmitter 30. To solve this problem, the liquid in the pressure tapping tube must be addressed at its source, ensuring that the pressure introduced into the measuring chamber (or pressure measuring chamber) of the differential pressure transmitter 30 is a single medium pressure. Observation of liquid collection in the high- and low-pressure pressure tapping tubes revealed that, with the same gas phase outlet medium properties at the front-end three-phase separator 10, the condensation conditions at the high-pressure port 21 and low-pressure port 22 of the orifice plate differential pressure flowmeter 20 were significantly different. The gas in the high-pressure tapping tube contained up to 25% liquid, while there was almost no condensate at the low-pressure end. Therefore, addressing the condensate issue in the high-pressure tapping tube will ensure a purer gas in the measuring chamber of the differential pressure transmitter 30. Based on this, the present invention discloses a gas phase flow measurement system for a production separator on an offshore platform, which is mainly used for accurate measurement of gas phase flow in the primary and secondary separators of offshore drilling and production platforms. By applying a gas-liquid separation device 40, the liquid component in the mixed gas is effectively separated, thereby ensuring that the orifice plate differential pressure flow meter 20 can accurately and stably measure the gas flow in a gas-liquid mixed flow environment, effectively solving the problem of liquid interference.

[0036] like Figures 2 to 5 As shown, the gas phase flow measurement system of the offshore platform production separator may include a three-phase separator 10, an orifice plate differential pressure flow meter 20, a differential pressure transmitter 30, and a gas-liquid separation device 40; the three-phase separator 10 is connected to the inlet end of the orifice plate differential pressure flow meter 20.

[0037] The gas-liquid separation device 40 includes a container 41, an air inlet 42 on the circumferential side wall of the container 41, an air outlet 43 on the top of the container 41, and a plurality of filter plates 44 inside the container 41, the plurality of filter plates 44 being spaced apart and disposed between the air inlet 42 and the air outlet 43.

[0038] The air inlet 42 is connected to the high-pressure port 21 of the orifice plate differential pressure flow meter 20 through the first pressure tap 60. The air inlet 42 is connected to the high-pressure measuring chamber of the differential pressure transmitter 30 through the second pressure tap 70. The low-pressure port 22 of the orifice plate differential pressure flow meter 20 is connected to the low-pressure measuring chamber of the differential pressure transmitter 30 through the third pressure tap 80.

[0039] In this embodiment, the high-pressure side gas passes through container 41 and then enters the differential pressure transmitter 30. Since the two are from the same source and have equal pressure, there will be no pressure drop, and it will not affect the measurement of the differential pressure transmitter 30.

[0040] like Figure 2As shown, in some embodiments, the three-phase separator 10 is connected to the inlet end of the orifice plate differential pressure flowmeter 20 via a connecting pipe 50. A first valve 51 is provided on the connecting pipe 50, which can be used to isolate the three-phase separator 10 from the orifice plate differential pressure flowmeter 20. Preferably, the first valve 51 can be a ball valve made of stainless steel.

[0041] like Figure 2 As shown, in some embodiments, a second valve 61 and a third valve 62 are spaced apart on the first pressure tap 60. The second valve 61 is located near the high-pressure port 21 of the orifice plate differential pressure flow meter 20, and the third valve 62 is located near the air inlet 42. The second valve 61 and the third valve 62 can be used to isolate the orifice plate differential pressure flow meter 20 from the gas-liquid separator 40, and can also be used for disassembly and maintenance of the first pressure tap 60. The second valve 61 and the third valve 62 can be stainless steel ball valves.

[0042] like Figure 2 As shown, in some embodiments, a fourth valve 71 and a fifth valve 72 are spaced apart on the second pressure tap 70. The fourth valve 71 is located near the outlet 43, and the fifth valve 72 is located near the high-pressure measuring chamber of the differential pressure transmitter 30. The fourth valve 71 and the fifth valve 72 can be used to isolate the orifice plate differential pressure flowmeter 20 from the differential pressure transmitter 30, and can also be used for disassembly and maintenance of the second pressure tap 70. Both the first pressure tap 60 and the second pressure tap 70 can be made of stainless steel. The fourth valve 71 and the fifth valve 72 can be stainless steel ball valves.

[0043] like Figure 2 As shown, in some embodiments, a sixth valve 81 and a seventh valve 82 are spaced apart on the third pressure tap 80. The sixth valve 81 is located near the low-pressure port 22 of the orifice plate differential pressure flowmeter 20, and the seventh valve 82 is located near the low-pressure measuring chamber of the differential pressure transmitter 30. The sixth valve 81 and the seventh valve 82 can be used to isolate the orifice plate differential pressure flowmeter 20 from the differential pressure transmitter 30, and can also be used for disassembly and maintenance of the third pressure tap 80. The third pressure tap 80 can be made of stainless steel. The sixth valve 81 and the seventh valve 82 can be made of stainless steel ball valves.

[0044] In some embodiments, the container 41 may be disposed on an easily operable platform, and the container 41 is located below the orifice differential pressure flow meter 20 in the height direction.

[0045] In some embodiments, the container 41 has a capacity of approximately 5L-10L and is used for separating gas-liquid two-phase flows. The capacity of the container 41 can be 5L, 6L, 7L, 8L, 9L, or 10L.

[0046] In some embodiments, the container 41 may be a circular cylindrical container or a square cylindrical container, with the square cylindrical container including both square and rectangular cylindrical containers. The container 41 may be made of stainless steel to suit marine environments. In some embodiments, the container 41 may include a cylindrical tank body and a cover plate. The cover plate is sealed to the opening of the tank body, which may be fixed via a flange connection. A sealing ring may be provided on the contact surface between the cover plate and the opening of the tank body to improve sealing. A detachable structure facilitates cleaning and maintenance of the interior of the container 41, and also facilitates the installation and maintenance of the filter plate 44 within the container 41. Of course, the container 41 may also be a one-piece structure; no specific limitation is made here.

[0047] In some embodiments, the plane on which the filter plate 44 is located can completely cover the longitudinal section of the container 41, that is, the side of the filter plate 44 is connected and fixed to the inner side wall and bottom wall of the container 41.

[0048] In some embodiments, the filter plate 44 is welded and fixed to the inner wall of the container 41.

[0049] In some embodiments, the filter plate 44 is detachably connected to the inner wall of the container 41. For example... Figure 3 As shown, the inner wall of the container 41 has slots 411 on opposite side walls, and the two sides of the filter plate 44 are respectively inserted into the slots 411.

[0050] In some embodiments, the number of filter plates 44 can be at least two, such as two, three, or any other number greater than two. At least two filter plates 44 can divide the inner cavity of the container 41 into multiple spaces. When the gas-liquid two-phase flow enters the container 41 and hits the filter plates 44, gas-liquid separation is achieved by increasing the condensation area and allowing the liquid to settle due to gravity. Simultaneously, the filter plates 44 can filter out some impurities. The liquid and impurities deposit in the container 41 and can be periodically discharged. The separated pure gas flows from the top to the high-pressure measuring chamber of the differential pressure transmitter 30, ensuring pressure balance throughout the system and effectively guaranteeing measurement stability.

[0051] like Figure 2 As shown, the angle formed between the plane of the filter plate 44 and the bottom wall of the container 41 is an acute angle. For example, the angle can be 10°, 20°, 30°, 40° or other degrees. It can be selected and set according to actual needs, and no specific limitation is made here.

[0052] Of course, the filter plate 44 can also be set perpendicular to the bottom wall of the container 41.

[0053] In some embodiments, the filter plate 44 is provided with a plurality of circular holes 441, which may be arranged in the same row or column, such as... Figure 4As shown. Alternatively, the circular holes 441 can also be arranged alternately along the height and horizontal directions of the filter plate 44, as shown. Figure 5 As shown. The arrangement of the circular hole 441 can be selected according to actual needs, and no specific limitation is made here. Preferably, the inner diameter of the circular hole 441 is 3mm-5mm.

[0054] Preferably, the filter plate 44 can be made of stainless steel.

[0055] Of course, in other embodiments, the filter plate 44 may also be provided with square holes or diamond holes, etc., which is not specifically limited here.

[0056] In some embodiments, such as Figure 2 As shown, the container 41 has at least one drain hole on its circumferential sidewall near its bottom wall. The offshore platform production separator gas phase flow measurement system also includes a drain pipe 90 connected to the drain hole. The drain pipe 90 is equipped with at least one eighth valve 91. The eighth valve 91 is used to isolate the container 41 or to discharge liquid, so as to empty the separated liquid into the waste liquid tank and prevent the container 41 from affecting the measurement when it is full. The eighth valve 91 can be a ball valve made of stainless steel or a pneumatic valve.

[0057] Based on extensive practical experience, it has been concluded that when container 41 has a capacity of 10L, it is advisable to discharge the sediment once when it reaches about 4L-5L. Considering the actual working conditions of this drilling and production platform, the discharge cycle is approximately once a week, that is, the operators open valve 91 once a week to discharge the sediment.

[0058] In some embodiments, a liquid level switch may be provided inside the container 41. Preferably, a liquid level switch may be provided at a liquid level of 4L-5L inside the container 41. The eighth valve 91 may be a pneumatic valve, which is linked to the liquid level switch. When the liquid in the container 41 reaches a set value, the liquid level switch activates, and the signal controls the eighth valve 91 (pneumatic valve) to automatically open and discharge liquid for 30 seconds before closing, thus achieving automatic discharge of liquid and effectively freeing up manual operation. Of course, the liquid level switch may not be provided, and manual operation is sufficient.

[0059] Compared to traditional solutions for drift in gas phase orifice plate differential pressure flow meters, this offshore platform production separator gas phase flow measurement system has significant advantages in terms of gas-liquid separation performance, operation, and safety.

[0060] 1. Stability: By designing a gas-liquid separation device 40 on the pressure tapping line with a high liquid content at the high-pressure end of the differential pressure transmitter 30, the liquid in the two-phase flow can be effectively separated, and it also has the function of removing impurities. This ensures that the differential pressure transmitter 30 can be stably supplied with isobaric pure gas, completely solving the drift of the orifice plate differential pressure flowmeter 20 caused by the uncontrollable change in medium density due to the liquid content in the gas phase, and ensuring the measurement accuracy of the orifice plate differential pressure flowmeter 20.

[0061] 2. Continuity of Flow Measurement: Traditional methods of disassembling the pressure tap for drainage and impurity removal require isolating the differential pressure transmitter 30, causing an interruption in flow measurement. This system can drain the water online without isolating or shutting down the differential pressure transmitter 30, effectively ensuring the continuity of measurement.

[0062] 3. Protection of precision instruments: After the gas-liquid two-phase flow enters the measuring chamber of the differential pressure transmitter 30, liquid and impurities may damage the pressure elements of the differential pressure transmitter 30. However, the gas-liquid separation device 40 of this system continuously provides pure gas to the differential pressure transmitter 30, effectively protecting the precision components of the differential pressure transmitter 30.

[0063] 4. Ease of Operation: The orifice plate differential pressure flow meter 20 is generally installed on the top of the three-phase separator 10 tank. Traditionally, drainage and calibration require personnel to climb to the top of the three-phase separator 10 tank. This system allows the gas-liquid separation device 40 to be placed on an easily accessible platform, and the drain hole of the gas-liquid separation device 40 is directly connected to the floor drain. Personnel only need to periodically go to the operating platform and open the eighth valve 91 to drain the liquid, making operation simple and safe.

[0064] 5. Reduced maintenance costs: This system effectively improves the stability and accuracy of the orifice plate differential pressure flow meter 20, reduces the frequency of frequent calibration or repair and replacement of the orifice plate differential pressure flow meter 20, and lowers maintenance costs.

[0065] It is understood that the above embodiments only illustrate preferred embodiments of the present utility model, and their descriptions are relatively specific and detailed, but they should not be construed as limiting the scope of the present utility model patent. It should be noted that for those skilled in the art, the above technical features can be freely combined, and several modifications and improvements can be made without departing from the concept of the present utility model, all of which fall within the protection scope of the present utility model. Therefore, all equivalent transformations and modifications made within the scope of the claims of the present utility model should fall within the coverage of the claims of the present utility model.

Claims

1. A gas phase flow measurement system for a production separator on an offshore platform, characterized in that, It includes a three-phase separator (10), an orifice plate differential pressure flow meter (20), a differential pressure transmitter (30), and a gas-liquid separation device (40); the three-phase separator (10) is connected to the inlet end of the orifice plate differential pressure flow meter (20); The gas-liquid separation device (40) includes a container (41), an air inlet (42) is provided on the circumferential side wall of the container (41), an air outlet (43) is provided on the top of the container (41), and a plurality of filter plates (44) are provided inside the container (41), with the plurality of filter plates (44) spaced apart and located between the air inlet (42) and the air outlet (43); The air inlet (42) is connected to the high-pressure port (21) of the orifice plate differential pressure flow meter (20) through a first pressure tap (60), the air inlet (42) is connected to the high-pressure measuring chamber of the differential pressure transmitter (30) through a second pressure tap (70), and the low-pressure port (22) of the orifice plate differential pressure flow meter (20) is connected to the low-pressure measuring chamber of the differential pressure transmitter (30) through a third pressure tap (80).

2. The offshore platform production separator gas phase flow measurement system according to claim 1, characterized in that, The three-phase separator (10) is connected to the inlet end of the orifice plate differential pressure flow meter (20) via a connecting pipe (50), and a first valve (51) is provided on the connecting pipe (50).

3. The offshore platform production separator gas phase flow measurement system according to claim 1, characterized in that, The first pressure tap (60) is provided with a second valve (61) and a third valve (62) spaced apart. The second valve (61) is located near the high pressure port (21) of the orifice plate differential pressure flow meter (20), and the third valve (62) is located near the air inlet (42).

4. The offshore platform production separator gas phase flow measurement system according to claim 1, characterized in that, The second pressure tap (70) is provided with a fourth valve (71) and a fifth valve (72) spaced apart. The fourth valve (71) is located near the air outlet (43), and the fifth valve (72) is located near the high pressure measuring chamber of the differential pressure transmitter (30).

5. The offshore platform production separator gas phase flow measurement system according to claim 1, characterized in that, The third pressure tap (80) is provided with a sixth valve (81) and a seventh valve (82) spaced apart. The sixth valve (81) is located near the low-pressure port (22) of the orifice plate differential pressure flow meter (20), and the seventh valve (82) is located near the low-pressure measurement chamber of the differential pressure transmitter (30).

6. The offshore platform production separator gas phase flow measurement system according to claim 1, characterized in that, The filter plate (44) is detachably connected to the inner wall of the container (41).

7. The offshore platform production separator gas phase flow measurement system according to claim 1, characterized in that, The inner wall of the container (41) has slots (411) on opposite side walls, and the two sides of the filter plate (44) are respectively inserted into the slots (411).

8. The offshore platform production separator gas phase flow measurement system according to claim 1, characterized in that, The angle formed between the plane of the filter plate (44) and the bottom wall of the container (41) is an acute angle.

9. The offshore platform production separator gas phase flow measurement system according to claim 1, characterized in that, The filter plate (44) is provided with a plurality of round holes (441), the inner diameter of which is 3mm-5mm.

10. The offshore platform production separator gas phase flow measurement system according to claim 1, characterized in that, The container (41) has at least one drain hole on its circumferential sidewall near the bottom wall of the container (41). The offshore platform production separator gas phase flow measurement system also includes a drain pipe (90) connected to the drain hole, and the drain pipe (90) is provided with at least one eighth valve (91).

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