Method and device for detecting energy fluctuation of fluid in pipeline

Abstract

The invention relates to the technical field of energy detection of fluid in a pipeline, and discloses a method and device for detecting energy fluctuation of fluid in the pipeline, and the method comprises the following steps: installing a pressure sensor and a density sensor on the pipeline, pressure and density data in the pipeline are measured through a pressure sensor and a density sensor respectively; calculating the gas phase volume fraction and the latent heat fluctuation intensity according to the measured pressure and density data; when the gas phase proportion is insufficient or the latent heat fluctuation is abnormal, the seawater circulation amount is increased or the standby vaporizer is started; a device for detecting energy fluctuation of fluid in a pipeline comprises an LNG (liquefied natural gas) input pipeline, an NG (natural gas) output pipeline and a warm drainage input pipeline. The pressure and density of fluid in the pipeline can be monitored in real time, subsequent data can be speculated, and the situation that fluctuation of the pipeline becomes large, and a water hammer is formed is avoided.

Description

Technical Field

[0001] The present invention relates to the technical field of fluid energy detection in pipelines, and particularly to a method and device for detecting fluid energy fluctuations in pipelines. Background Art

[0002] In a pressure pipeline, due to some external reason, the water flow velocity suddenly changes, and due to the inertia of the liquid, an alternating change of a sharp increase and decrease in the internal pressure of the liquid occurs. This alternating pressure acts on the pipe wall, valve or other pipeline components like hammering, which is called water hammer or water shock. Too low pressure will cause the pipeline to collapse, and will also damage valves and fixtures, affecting production. The pressure increase caused by water hammer can reach several times or even hundreds of times the normal working pressure of the pipeline. Mildly, it is manifested as noise and pipeline vibration, and severely, it will cause valve damage, pipeline joint disconnection, and even major accidents such as serious pipeline deformation and bursting.

[0003] Taking a liquefied natural gas station (abbreviated as LNG station) as an example, the heat sources of the ORV vaporizer and IFV vaporizer in the LNG station are the nearby seawater and the warm seawater discharged from the power plant. The seawater pumped is passed through two seawater pipelines, with the pipeline length in the order of 10 km. After being adjusted by the valve, it enters the seawater distributor and is distributed into a thin film and flows downward from top to bottom along the outside of the finned heat exchange tube. LNG enters from the bottom of the finned tube and flows upward from bottom to top inside the finned tube. The two media perform countercurrent heat exchange, so that the LNG is vaporized into normal-temperature natural gas and output from the top of the ORV, and the seawater enters the seawater channel and is discharged back to the sea. Regarding the fluid energy fluctuations in the pipeline, they generally occur at the bends of pipelines such as LNG, warm drainage, and seawater. The existing technologies are mainly reflected in the theoretical analysis of internal energy and the protection against severe fluctuations.

[0004] Most of the existing pipeline analyses are for the analysis of water hammer generated by severe energy fluctuations. The water hammer phenomenon caused by closing the valve in the seawater system pipeline is analyzed, and a reasonable valve closing time is given in combination with the on-site working conditions. Aiming at the phenomena of cracks and water leakage in the ORV seawater pipeline, detachment of the seawater distributor, and damage to the distribution butterfly valve that often occur during the operation of the ORV seawater pipeline in the LNG receiving station. By reducing the pressure difference before and after the ORV seawater flow control valve and reducing the local seawater flow velocity, the operation stability of the ORV seawater pipeline is improved. Power failure of the pumping station and valve failure will cause energy fluctuations during the operation process, so it is very important to test the energy fluctuations.

[0005] At present, for some detection methods of water hammer effect generated when the fluid energy in the pipeline fluctuates strongly, collecting noise information can achieve real-time water hammer detection and alarm. (Application No. CN202310489831.9, Publication No. CN116481639A, Publication Date: July 25, 2023) Or by comparing the difference between the maximum and minimum pressures to determine that the pressure in the conveying pipeline changes greatly in a short time, so as to realize the monitoring of the water hammer effect in the conveying pipeline. (Application No. CN202311587443.0, Publication No. CN117537279A, Publication Date: February 09, 2024). A pressure-bearing detection mechanism provided with a detection driving component and an external pressure-bearing detection component slides through the external pressure-bearing detection disc of the straight pipe and the heat exchange pipe to detect its simulated bending degree, and detects the deformation degree of the bent part of the heat exchange pipe after being impacted by a water hammer-like effect, so as to conveniently measure the pressure-bearing capacity of the bent part of the heat exchange pipe after bearing the water pressure impact. (Application No. CN202411321760.2, Publication No. CN118837216A, Publication Date: September 23, 2024). A valve for reducing the water hammer effect is disclosed, including a valve positioning component, a switch component is installed on the top of the valve positioning component, positioning pipes are fixedly connected to both sides of the valve positioning component, and a positioning flange is installed on the side of the positioning pipe away from the valve positioning component, which ensures the sealing of the rotation positioning component, the telescopic buffer component and the shunt buffer component after the water valve is closed, and ensures the effective cut-off of the water flow after the valve is closed. (Application No. CN202411285908.1, Publication No. CN118815997A, Publication Date: September 13, 2024). However, for the detection methods and devices of fluid energy fluctuations in pipelines, no systematic solution has been formed.

[0006] In the research on fluid energy fluctuations in pipelines, it mainly stays in theoretical analysis and protection against severe fluctuations. No method for selecting physical quantities for testing and measuring fluid energy fluctuations in pipelines and the optimal layout strategy for measuring points are given. When there are potential safety hazards in the actual pipeline, it is impossible to obtain information on fluid energy fluctuations in the pipeline in advance, resulting in a large amount of later costs and even safety problems. Regarding the testing and measurement of fluid energy fluctuations in pipelines in natural gas gasification systems, no complete methodology and test system solution have been formed.

[0007] Therefore, there is an urgent need for a detection method and device for fluid energy fluctuations in pipelines to solve the above problems. Summary of the Invention

[0008] The purpose of the present invention is to provide a detection method and device for fluid energy fluctuations in pipelines to solve the problems existing in the above-mentioned prior art.

[0009] To achieve the above purpose, the present invention provides the following solution: The present invention provides a detection method for fluid energy fluctuations in pipelines, including the following steps:

[0010] S1. Install a number of pressure sensors and a number of density sensors on the pipeline, and measure the pressure and density data inside the pipeline through the pressure sensors and the density sensors respectively;

[0011] S2. Calculate the gas volume fraction and the latent heat fluctuation intensity from the measured pressure and density data;

[0012] S3. When the gas phase ratio is insufficient or the latent heat fluctuation is abnormal, increase the seawater circulation volume or start the standby vaporizer.

[0013] According to a detection method for fluid energy fluctuation in a pipeline provided by the present invention, after step S1, dynamic correction is performed according to the measured density data, and the density dynamic correction satisfies:

[0014]

[0015] where ρ 校正 is the corrected fluid density; ρ 测量 is the measured fluid density; is the methane mole fraction in the LNG component;

[0016] Calibrate the phase of the pressure signal through the pressure data.

[0017] According to a detection method for fluid energy fluctuation in a pipeline provided by the present invention, in step S2, the gas phase volume fraction is α, which satisfies:

[0018]

[0019] where ρ liq is the measured NG density; ρ gas is the measured LNG density; ρ mix is the measured density of the mixed fluid.

[0020] According to a detection method for fluid energy fluctuation in a pipeline provided by the present invention, in step S2, the latent heat fluctuation intensity I latent satisfies:

[0021]

[0022] where Se(f) is the power spectral density function.

[0023] According to a detection method for fluid energy fluctuation in a pipeline provided by the present invention, in step S3, when α < 0.95, it indicates that the gas phase ratio is insufficient, and it is necessary to increase the seawater circulation volume or start the standby vaporizer.

[0024] A method for detecting fluid energy fluctuations in a pipeline. In step S3, the mechanical energy fluctuation intensity I mech satisfies:

[0025]

[0026] wherein, when I latent > 0.8I mech it indicates that the latent heat fluctuation is abnormal, and it is necessary to increase the seawater circulation volume or start the standby vaporizer.

[0027] A detection device for fluid energy fluctuations in a pipeline, which is arranged on the pipeline;

[0028] The pipeline includes an LNG input pipeline, an NG output pipeline, and a warm drainage input pipeline;

[0029] The LNG input pipeline includes a terminal liquid collection tank, a first vaporizer, a compressor, a high-pressure pump, and an LNG storage tank arranged in sequence from left to right. A first slow-closing check valve and a first electric valve are installed between the terminal liquid collection tank and the first vaporizer, and a second slow-closing check valve and a second electric valve are installed between the first vaporizer and the compressor;

[0030] The detection device includes a pressure sensor and a density sensor, which are respectively used to detect the pressure value and the density value. The pressure sensor is installed at both ends of the first electric valve, both ends of the second slow-closing check valve, and between the high-pressure pump and the LNG storage tank, and the density sensor is installed between the first vaporizer and the second slow-closing check valve;

[0031] A data processing module, which is used to calculate the gas volume fraction and the latent heat fluctuation intensity through the measured pressure and density data;

[0032] A determination module, which is used to determine the gas phase ratio or the latent heat fluctuation situation.

[0033] According to a detection device for fluid energy fluctuations in a pipeline provided by the present invention, the NG output pipeline includes a first sump, a first water pump, a first conveying pipeline, and a second vaporizer arranged in sequence from left to right. The first sump is communicated with the outside seawater through a seawater inlet. A manual valve is installed between the first sump and the first water pump, and a third slow-closing check valve and a third electric valve are installed between the first water pump and the first conveying pipeline. The pressure sensor is installed between the manual valve and the first water pump and at both ends of the first conveying pipeline, and the density sensor is installed between the third slow-closing check valve and the third electric valve.

[0034] A detection device for fluid energy fluctuation in a pipeline according to the present invention, the warm wastewater input pipeline includes a second sump, a second water pump, a second conveying pipeline, a third vaporizer and a third sump arranged in sequence from left to right. The second sump is communicated with the external warm seawater through a warm seawater inlet. A fourth electric valve is installed between the second sump and the second water pump. A fourth slow-closing check valve and a fifth electric valve are installed between the second water pump and the second conveying pipeline. Pressure sensors are installed between the fourth electric valve and the second water pump and between the second conveying pipeline and the third vaporizer. A density sensor is installed between the fourth slow-closing check valve and the fifth electric valve. A temperature sensor is installed on the third sump.

[0035] A detection device for fluid energy fluctuation in a pipeline according to the present invention, the pressure sensor is a piezoresistive sensor, and the density sensor is a mass flowmeter.

[0036] Compared with the prior art, the present invention has the following advantages and technical effects:

[0037] A detection method and device for fluid energy fluctuation in a pipeline provided by the present invention, when in use, pressure sensors are installed at the inlet / outlet of the vaporizer and key pipe sections, and several density sensors are installed at a position less than 0.5D (pipe diameter), and data is measured. Dynamic correction is performed according to the measured density. Aiming at the pressure wave velocity difference of two-phase flow, the upstream and downstream measurement point data are aligned, the phase of the pressure signal is calibrated, the gas volume fraction and the latent heat fluctuation intensity are calculated. When the gas phase ratio is insufficient or the latent heat fluctuation is abnormal, the seawater circulation volume is increased or the standby vaporizer is started to prevent equipment vibration caused by uneven gas-liquid distribution and ensure the stable operation of the equipment. In this application, pressure and density sensors are set at the water pump and different valves. During the equipment process, the pressure and density of the fluid in the pipeline are monitored in real time. The density sensor and pressure sensor between the vaporizer and the water pump will monitor the pipeline in real time to obtain the change values of pressure and density, so as to protect against energy fluctuation. At the same time, the subsequent data can also be inferred to avoid the pipeline fluctuation from becoming larger and forming a water hammer. Brief Description of the Drawings

[0038] In order to more clearly illustrate the technical solutions in the embodiments of the present invention or the prior art, the following will briefly introduce the drawings required for use in the embodiments. Obviously, the following described drawings are only some embodiments of the present invention. For those of ordinary skill in the art, without creative efforts, other drawings can be obtained according to these drawings:

[0039] Figure 1 It is a schematic structural diagram of the LNG input pipeline of the present invention;

[0040] Figure 2Schematic diagram of the NG output pipeline structure of the present invention;

[0041] Figure 3 Schematic diagram of the warm wastewater input pipeline structure of the present invention;

[0042] Among them, 1. Wharf collecting tank; 2. First vaporizer; 3. Compressor; 4. High-pressure pump; 5. LNG storage tank; 6. First slow-closing check valve; 7. First electric valve; 8. Second slow-closing check valve; 9. Second electric valve; 10. Pressure sensor; 11. Density sensor; 12. First sump; 13. First water pump; 14. First conveying pipeline; 15. Second vaporizer; 16. Seawater inlet; 17. Manual valve; 18. Third slow-closing check valve; 19. Third electric valve; 20. Second sump; 21. Second water pump; 22. Second conveying pipeline; 23. Third vaporizer; 24. Third sump; 25. Warm seawater inlet; 26. Fourth electric valve; 27. Fourth slow-closing check valve; 28. Fifth electric valve; 29. Temperature sensor. Detailed implementation manners

[0043] Next, the technical solutions in the embodiments of the present invention will be clearly and completely described in conjunction with the accompanying drawings in the embodiments of the present invention. Obviously, the described embodiments are only a part of the embodiments of the present invention, rather than all the embodiments. All other embodiments obtained by those of ordinary skill in the art based on the embodiments of the present invention without creative efforts shall fall within the protection scope of the present invention.

[0044] To make the above objects, features, and advantages of the present invention more obvious and understandable, the present invention will be further described in detail below in conjunction with the accompanying drawings and specific implementation manners.

[0045] Refer to Figures 1 - 3 , the present invention provides a method for detecting the fluid energy fluctuation in a pipeline, including the following steps:

[0046] S1. Install a plurality of pressure sensors and a plurality of density sensors on the pipeline, and respectively measure the pressure and density data in the pipeline through the pressure sensors and density sensors;

[0047] S2. Calculate the gas volume fraction and latent heat fluctuation intensity through the measured pressure and density data;

[0048] S3. When the gas phase ratio is insufficient or the latent heat fluctuation is abnormal, increase the seawater circulation volume or start the standby vaporizer.

[0049] In one embodiment of the present invention, during use, pressure sensors 10 are installed at the inlet / outlet of the vaporizer and key pipe sections, and several density sensors 11 are installed at a position less than 0.5D (pipe diameter), and data is measured. Dynamic correction is performed based on the measured density. In view of the difference in the pressure wave velocity of the two-phase flow, the upstream and downstream measurement point data is aligned, the phase of the pressure signal is calibrated, the gas volume fraction and the latent heat fluctuation intensity are calculated. When the gas phase ratio is insufficient or the latent heat fluctuation is abnormal, the seawater circulation volume is increased or a standby vaporizer is started to prevent equipment vibration caused by uneven gas-liquid distribution and ensure the stable operation of the equipment.

[0050] As an alternative implementation manner, after step S1, dynamic correction is performed according to the measured density data, and the density dynamic correction satisfies:

[0051]

[0052] where ρ 校正 is the corrected fluid density; ρ 测量 is the measured fluid density; is the methane mole fraction in the LNG component;

[0053] The phase of the pressure signal is calibrated through the pressure data.

[0054] As an alternative implementation manner, in step S2, the gas phase volume fraction is α, and it satisfies:

[0055]

[0056] where ρ liq is the measured NG density; ρ gas is the measured LNG density; ρ mix is the measured density of the mixed fluid.

[0057] As an alternative implementation manner, in step S2, in step S2, the latent heat fluctuation intensity I latent satisfies:

[0058]

[0059] where Se(f) is the power spectral density function.

[0060] As an alternative implementation manner, in step S3, when α < 0.95, it indicates that the gas phase ratio is insufficient, and the seawater circulation volume needs to be increased or a standby vaporizer needs to be started.

[0061] In one embodiment of the present invention, when the gas phase volume fraction is less than 0.95, it is determined that the gas phase ratio is insufficient, and the safe and stable operation of the pipeline is ensured by increasing the seawater circulation volume or starting a standby vaporizer.

[0062] As an alternative embodiment, in step S3, the mechanical energy fluctuation intensity I mech satisfies:

[0063]

[0064] wherein, when I latent > 0.8I mech it indicates that the latent heat fluctuation is abnormal, and it is necessary to increase the seawater circulation volume or start the standby vaporizer.

[0065] In an embodiment of the present invention, when the latent heat fluctuation intensity is greater than 0.8 times the mechanical energy fluctuation intensity, it is determined that the latent heat fluctuation is abnormal, and the safe and stable operation of the pipeline is ensured by increasing the seawater circulation volume or starting the standby vaporizer.

[0066] A detection device for fluid energy fluctuation in a pipeline is provided on the pipeline;

[0067] The LNG input pipeline includes a terminal liquid collection tank 1, a first vaporizer 2, a compressor 3, a high-pressure pump 4, and an LNG storage tank 5 arranged in sequence from left to right. A first slow-closing check valve 6 and a first electric valve 7 are installed between the terminal liquid collection tank 1 and the first vaporizer 2, and a second slow-closing check valve 8 and a second electric valve 9 are installed between the first vaporizer 2 and the compressor 3;

[0068] The detection device includes a pressure sensor 10 and a density sensor 11, which are respectively used to detect the pressure value and the density value. The pressure sensor 10 is installed at both ends of the first electric valve 7, both ends of the second slow-closing check valve 8, and between the high-pressure pump 4 and the LNG storage tank 5, and the density sensor 11 is installed between the first vaporizer 2 and the second slow-closing check valve 8;

[0069] The data processing module is used to calculate the gas volume fraction and the latent heat fluctuation intensity through the measured pressure and density data;

[0070] The determination module is used to determine the gas phase ratio or the latent heat fluctuation condition. The pipeline includes an LNG input pipeline, an NG output pipeline, and a warm drainage input pipeline;

[0071] In an embodiment of the present invention, the pipeline includes an LNG input pipeline, an NG output pipeline, and a warm drainage input pipeline. Detection is carried out for different pipelines, and the pressure and density in the LNG input pipeline are measured by the provided pressure sensor 10 and density sensor 11.

[0072] As an alternative embodiment, the NG output pipeline includes a first sump 12, a first water pump 13, a first conveying pipeline 14, and a second vaporizer 15 arranged in sequence from left to right. The first sump 12 is communicated with the external seawater through a seawater inlet 16. A manual valve 17 is installed between the first sump 12 and the first water pump 13. A third slow-closing check valve 18 and a third electric valve 19 are installed between the first water pump 13 and the first conveying pipeline 14. Pressure sensors 10 are installed between the manual valve 17 and the first water pump 13 and at both ends of the first conveying pipeline 14. A density sensor 11 is installed between the third slow-closing check valve 18 and the third electric valve 19.

[0073] In an embodiment of the present invention, the pressure and density in the NG output pipeline are measured by the provided pressure sensor 10 and density sensor 11.

[0074] As an alternative embodiment, the warm wastewater input pipeline includes a second sump 20, a second water pump 21, a second conveying pipeline 22, a third vaporizer 23, and a third sump 24 arranged in sequence from left to right. The second sump 20 is communicated with the external warm seawater through a warm seawater inlet 25. A fourth electric valve 26 is installed between the second sump 20 and the second water pump 21. A fourth slow-closing check valve 27 and a fifth electric valve 28 are installed between the second water pump 21 and the second conveying pipeline 22. Pressure sensors 10 are installed between the fourth electric valve 26 and the second water pump 21 and between the second conveying pipeline 22 and the third vaporizer 23. A density sensor 11 is installed between the fourth slow-closing check valve 27 and the fifth electric valve 28. A temperature sensor 29 is installed on the third sump 24.

[0075] In an embodiment of the present invention, the pressure and density in the warm wastewater input pipeline are measured by the provided pressure sensor 10 and density sensor 11.

[0076] As an alternative embodiment, the pressure sensor 10 is a piezoresistive sensor, and the density sensor 11 is a mass flowmeter.

[0077] In an embodiment of the present invention, the pressure sensor 10 is preferably a low-temperature piezoresistive sensor, and the density sensor 11 is preferably an ultra-low-temperature mass flowmeter.

[0078] In one embodiment of the present invention, according to the physical properties of different fluids in the pipeline, two or three physical quantities are selected for monitoring and measurement to judge and reflect the energy fluctuations of the fluids. For pipeline fluctuations, due to the fluid pressure caused by the change in flow velocity and the water hammer caused by pipeline vibration, we select the density and pressure of the fluid, which can most simply obtain the oscillation situation of the fluid. The unique advantage of this method is that the dedicated sensor and thermal insulation design ensure long-term stable operation in an environment of -160°C, and the mean time between failures > 50000 hours. Based on the density-pressure covariance analysis, flow patterns such as slug flow and annular flow can be distinguished in real time to prevent equipment vibration caused by uneven gas-liquid distribution. The LNG receiving station can achieve automatic peak shaving through the interface.

[0079] In the description of the present invention, it should be understood that the orientation or positional relationship indicated by the terms "longitudinal", "transverse", "upper", "lower", "front", "rear", "left", "right", "vertical", "horizontal", "top", "bottom", "inner", "outer", etc. is based on the orientation or positional relationship shown in the drawings, and is only for the convenience of describing the present invention, rather than indicating or implying that the device or element referred to must have a specific orientation, be constructed and operated in a specific orientation, and thus cannot be understood as a limitation to the present invention.

[0080] The above-described embodiments are only for describing the preferred mode of the present invention, and do not limit the scope of the present invention. Without departing from the design spirit of the present invention, various deformations and improvements made by those of ordinary skill in the art to the technical solution of the present invention shall fall within the protection scope determined by the claims of the present invention.

Claims

1. A method for detecting the energy fluctuation of fluid in a pipeline, characterized in that It includes the following steps: S1. Install a number of pressure sensors and a number of density sensors on the pipeline, and measure the pressure and density data inside the pipeline through the pressure sensors and the density sensors respectively; S2. Calculate the gas volume fraction and the latent heat fluctuation intensity through the measured pressure and density data; S3. When the gas phase ratio is insufficient or the latent heat fluctuation is abnormal, increase the seawater circulation volume or start the standby vaporizer.

2. The detection method for fluid energy fluctuation in a pipeline according to claim 1, wherein: After step S1, perform dynamic correction according to the measured density data, and the density dynamic correction satisfies: where ρ 矫正 is the corrected fluid density; ρ 测量 is the measured fluid density; is the methane mole fraction in the LNG composition; Calibrate the phase of the pressure signal through the pressure data.

3. The detection method for fluid energy fluctuation in a pipeline according to claim 1, wherein: In step S2, the gas phase volume fraction is α, and it satisfies: Among them, ρ liq is the measured density of NG; ρ gas is the measured density of LNG; ρ mix is the density of the measured mixed fluid.

4. A method for detecting fluid energy fluctuations in a pipeline according to claim 1, characterized in that: In step S2, the latent heat fluctuation intensity I latent satisfies: where Se(f) is the power spectral density function.

5. The detection method for fluid energy fluctuation in a pipeline according to claim 3, characterized in that: In step S3, when α < 0.95, it indicates that the gas phase ratio is insufficient, and it is necessary to increase the seawater circulation volume or start the standby vaporizer.

6. The detection method of fluid energy fluctuation in a pipeline according to claim 4, characterized in that: In step S3, the mechanical energy fluctuation intensity I mech satisfies: Among them, when I latent > 0.8I mech it indicates that the latent heat fluctuation is abnormal, and it is necessary to increase the seawater circulation volume or start the standby vaporizer.

7. A detection device for fluid energy fluctuation in a pipeline, applicable to a detection method for fluid energy fluctuation in a pipeline according to claim 1, characterized in that: The detection device is arranged on the pipeline; The pipeline includes an LNG input pipeline, an NG output pipeline, and a warm drainage input pipeline; The LNG input pipeline includes a terminal collecting tank (1), a first vaporizer (2), a compressor (3), a high-pressure pump (4), and an LNG storage tank (5) arranged in sequence from left to right. A first slow-closing check valve (6) and a first electric valve (7) are installed between the terminal collecting tank (1) and the first vaporizer (2), and a second slow-closing check valve (8) and a second electric valve (9) are installed between the first vaporizer (2) and the compressor (3); The detection device includes a pressure sensor (10) and a density sensor (11), which are respectively used to detect the pressure value and the density value. The pressure sensor (10) is installed at both ends of the first electric valve (7), both ends of the second slow-closing check valve (8), and between the high-pressure pump (4) and the LNG storage tank (5), and the density sensor (11) is installed between the first vaporizer (2) and the second slow-closing check valve (8); A data processing module, which is used to calculate the gas volume fraction and the latent heat fluctuation intensity through the measured pressure and density data; A determination module, which is used to determine the gas phase ratio or the latent heat fluctuation condition.

8. The detection device for fluid energy fluctuation in a pipeline according to claim 7, characterized in that: The NG output pipeline includes a first collecting tank (12), a first water pump (13), a first conveying pipeline (14), and a second vaporizer (15) arranged in sequence from left to right. The first collecting tank (12) is communicated with the outside seawater through a seawater inlet (16). A manual valve (17) is installed between the first collecting tank (12) and the first water pump (13), and a third slow-closing check valve (18) and a third electric valve (19) are installed between the first water pump (13) and the first conveying pipeline (14). The pressure sensor (10) is installed between the manual valve (17) and the first water pump (13) and at both ends of the first conveying pipeline (14), and the density sensor (11) is installed between the third slow-closing check valve (18) and the third electric valve (19).

9. The detection device for fluid energy fluctuation in a pipeline according to claim 7, characterized in that: The warm drainage input pipeline includes a second sump (20), a second water pump (21), a second conveying pipeline (22), a third vaporizer (23) and a third sump (24) arranged in sequence from left to right. The second sump (20) is communicated with the external warm seawater through a warm seawater inlet (25). A fourth electric valve (26) is installed between the second sump (20) and the second water pump (21). A fourth slow-closing check valve (27) and a fifth electric valve (28) are installed between the second water pump (21) and the second conveying pipeline (22). The pressure sensors (10) are installed between the fourth electric valve (26) and the second water pump (21) and between the second conveying pipeline (22) and the third vaporizer (23). A density sensor (11) is installed between the fourth slow-closing check valve (27) and the fifth electric valve (28). A temperature sensor (29) is installed on the third sump (24).

10. A method and device for detecting fluid energy fluctuations in a pipeline according to claim 7, characterized in that: The pressure sensor (10) is a piezoresistive sensor, and the density sensor (11) is a mass flowmeter.

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