CN114893719A - BOG gas recovery system and method for hydrogenation and liquefied natural gas combined station - Google Patents

BOG gas recovery system and method for hydrogenation and liquefied natural gas combined station Download PDF

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Publication number
CN114893719A
CN114893719A CN202210589432.5A CN202210589432A CN114893719A CN 114893719 A CN114893719 A CN 114893719A CN 202210589432 A CN202210589432 A CN 202210589432A CN 114893719 A CN114893719 A CN 114893719A
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China
Prior art keywords
bog
storage tank
pipeline
heat exchanger
lng storage
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CN202210589432.5A
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CN114893719B (en
Inventor
李明昕
周亮
田冠亚
李俊杰
黄景龙
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Zhengxing Hydrogen Electric Technology Zhengzhou Co ltd
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Zhengxing Hydrogen Electric Technology Zhengzhou Co ltd
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    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C9/00—Methods or apparatus for discharging liquefied or solidified gases from vessels not under pressure
    • F17C9/02—Methods or apparatus for discharging liquefied or solidified gases from vessels not under pressure with change of state, e.g. vaporisation
    • F17C9/04—Recovery of thermal energy
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C13/00—Details of vessels or of the filling or discharging of vessels
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C13/00—Details of vessels or of the filling or discharging of vessels
    • F17C13/02—Special adaptations of indicating, measuring, or monitoring equipment
    • F17C13/025—Special adaptations of indicating, measuring, or monitoring equipment having the pressure as the parameter
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C13/00—Details of vessels or of the filling or discharging of vessels
    • F17C13/02—Special adaptations of indicating, measuring, or monitoring equipment
    • F17C13/026—Special adaptations of indicating, measuring, or monitoring equipment having the temperature as the parameter
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C6/00—Methods and apparatus for filling vessels not under pressure with liquefied or solidified gases
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17D—PIPE-LINE SYSTEMS; PIPE-LINES
    • F17D1/00—Pipe-line systems
    • F17D1/005—Pipe-line systems for a two-phase gas-liquid flow
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17D—PIPE-LINE SYSTEMS; PIPE-LINES
    • F17D1/00—Pipe-line systems
    • F17D1/08—Pipe-line systems for liquids or viscous products
    • F17D1/14—Conveying liquids or viscous products by pumping
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17D—PIPE-LINE SYSTEMS; PIPE-LINES
    • F17D3/00—Arrangements for supervising or controlling working operations
    • F17D3/01—Arrangements for supervising or controlling working operations for controlling, signalling, or supervising the conveyance of a product
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2221/00—Handled fluid, in particular type of fluid
    • F17C2221/01—Pure fluids
    • F17C2221/012—Hydrogen
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2221/00—Handled fluid, in particular type of fluid
    • F17C2221/03—Mixtures
    • F17C2221/032—Hydrocarbons
    • F17C2221/033—Methane, e.g. natural gas, CNG, LNG, GNL, GNC, PLNG
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2223/00—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel
    • F17C2223/01—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel characterised by the phase
    • F17C2223/0107—Single phase
    • F17C2223/013—Single phase liquid
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2223/00—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel
    • F17C2223/01—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel characterised by the phase
    • F17C2223/0146—Two-phase
    • F17C2223/0153—Liquefied gas, e.g. LPG, GPL
    • F17C2223/0161—Liquefied gas, e.g. LPG, GPL cryogenic, e.g. LNG, GNL, PLNG
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2225/00—Handled fluid after transfer, i.e. state of fluid after transfer from the vessel
    • F17C2225/01—Handled fluid after transfer, i.e. state of fluid after transfer from the vessel characterised by the phase
    • F17C2225/0107—Single phase
    • F17C2225/013—Single phase liquid
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2225/00—Handled fluid after transfer, i.e. state of fluid after transfer from the vessel
    • F17C2225/01—Handled fluid after transfer, i.e. state of fluid after transfer from the vessel characterised by the phase
    • F17C2225/0146—Two-phase
    • F17C2225/0153—Liquefied gas, e.g. LPG, GPL
    • F17C2225/0161—Liquefied gas, e.g. LPG, GPL cryogenic, e.g. LNG, GNL, PLNG
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2227/00—Transfer of fluids, i.e. method or means for transferring the fluid; Heat exchange with the fluid
    • F17C2227/01—Propulsion of the fluid
    • F17C2227/0128—Propulsion of the fluid with pumps or compressors
    • F17C2227/0135—Pumps
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2227/00—Transfer of fluids, i.e. method or means for transferring the fluid; Heat exchange with the fluid
    • F17C2227/03—Heat exchange with the fluid
    • F17C2227/0302—Heat exchange with the fluid by heating
    • F17C2227/0309—Heat exchange with the fluid by heating using another fluid
    • F17C2227/0323—Heat exchange with the fluid by heating using another fluid in a closed loop
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2227/00—Transfer of fluids, i.e. method or means for transferring the fluid; Heat exchange with the fluid
    • F17C2227/03—Heat exchange with the fluid
    • F17C2227/0337—Heat exchange with the fluid by cooling
    • F17C2227/0341—Heat exchange with the fluid by cooling using another fluid
    • F17C2227/0355—Heat exchange with the fluid by cooling using another fluid in a closed loop
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2227/00—Transfer of fluids, i.e. method or means for transferring the fluid; Heat exchange with the fluid
    • F17C2227/03—Heat exchange with the fluid
    • F17C2227/0367—Localisation of heat exchange
    • F17C2227/0388—Localisation of heat exchange separate
    • F17C2227/039—Localisation of heat exchange separate on the pipes
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2227/00—Transfer of fluids, i.e. method or means for transferring the fluid; Heat exchange with the fluid
    • F17C2227/03—Heat exchange with the fluid
    • F17C2227/0367—Localisation of heat exchange
    • F17C2227/0388—Localisation of heat exchange separate
    • F17C2227/0393—Localisation of heat exchange separate using a vaporiser
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2250/00—Accessories; Control means; Indicating, measuring or monitoring of parameters
    • F17C2250/06—Controlling or regulating of parameters as output values
    • F17C2250/0605—Parameters
    • F17C2250/0626—Pressure
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2250/00—Accessories; Control means; Indicating, measuring or monitoring of parameters
    • F17C2250/06—Controlling or regulating of parameters as output values
    • F17C2250/0605—Parameters
    • F17C2250/0631—Temperature
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2260/00—Purposes of gas storage and gas handling
    • F17C2260/04—Reducing risks and environmental impact
    • F17C2260/046—Enhancing energy recovery
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2265/00—Effects achieved by gas storage or gas handling
    • F17C2265/03—Treating the boil-off
    • F17C2265/032—Treating the boil-off by recovery
    • F17C2265/033—Treating the boil-off by recovery with cooling
    • F17C2265/034—Treating the boil-off by recovery with cooling with condensing the gas phase
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2265/00—Effects achieved by gas storage or gas handling
    • F17C2265/06—Fluid distribution
    • F17C2265/063—Fluid distribution for supply of refueling stations
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
    • Y02P90/00—Enabling technologies with a potential contribution to greenhouse gas [GHG] emissions mitigation
    • Y02P90/45—Hydrogen technologies in production processes

Abstract

The invention discloses a BOG gas recovery system and a BOG gas recovery method for a hydrogenated and liquefied natural gas combined building station, which aim to solve the technical problems of high equipment cost and large occupied area caused by the fact that a large amount of equipment for providing cooling energy for a heat exchanger is required in the BOG recovery process in the conventional LNG; the system comprises an LNG storage tank, an output pipeline, a recovery pipeline, a heat exchanger, a liquid hydrogen system and a control unit; the liquid hydrogen system is communicated with the heat exchanger, the output pipeline and the recovery pipeline are respectively and correspondingly communicated between the LNG storage tank and the heat exchanger, and the control unit comprises a plurality of temperature transmitters, pressure transmitters and a PLC (programmable logic controller); the PLC is used for controlling the circulation quantity of BOG in the LNG storage tank entering the heat exchanger based on the information collected by the temperature transmitter and the pressure transmitter; according to the invention, the cold energy of the liquid hydrogen is used for providing corresponding cold energy for the BOG recovery process, so that the construction and use cost of a special cold energy device for the heat exchanger is reduced, and meanwhile, the occupied area is reduced.

Description

BOG gas recovery system and method for hydrogenation and liquefied natural gas combined station
Technical Field
The invention relates to the technical field of liquid hydrogen and LNG combined stations, in particular to a BOG gas recovery system and method for a hydrogenation and liquefied natural gas combined station.
Background
The problems of energy shortage and environmental pollution caused by automobiles in China are gradually highlighted, and the popularization of the existing hydrogen station is an important measure and development trend for relieving the contradiction between fuel supply and demand, reducing tail gas emission, improving atmospheric environment and promoting the technical progress of the automobile industry. The construction of the hydrogen station is a crucial ring for guaranteeing the supply of hydrogen energy, and the main reason for the scarcity of the domestic hydrogen station is that key parts required for constructing the hydrogen station are mature products without mass production, most of the key parts depend on import, and the construction cost is high due to the reasons of construction land, administrative examination and approval and the like. The hydrogen station is built by depending on the existing gas station, which is considered as a better construction mode at present, because many existing gas stations have the basic conditions for jointly building the hydrogen station: sufficient land and distance from peripheral facilities meet the requirements of the technical specifications of the hydrogen station.
Liquefied natural gas (abbreviated as LNG in english) in a liquefied natural gas filling station is a liquid obtained by compressing and cooling natural gas to a condensation temperature of-161.5 ℃, and is usually stored in a low-temperature storage tank at-162 ℃ and about 0.1 to 1.0 MPa. However, even if the liquefied natural gas is stored in the storage tank in a low temperature state, the LNG is gasified to generate flash vapor (BOG for short) due to the heat invasion of the external environment in the storage tank and during the transportation process through the pipeline, and part of mechanical energy is converted into heat energy during the operation of the pump in the LNG storage tank, the LNG in the tank is gasified to generate flash vapor, the flash vapor forms natural gas at normal temperature, and if the natural gas is discharged into the air, the natural gas is dangerous, pollutes the atmospheric environment, and has considerable economic loss; the existing BOG recovery liquefaction needs a plurality of heat exchangers and needs to provide enough cold energy for the heat exchangers, so that the occupied area is large, and the construction and use costs are high.
The information disclosed in this background section is only for enhancement of understanding of the background of the disclosure and should not be taken as an acknowledgement or any form of suggestion that this information forms the prior art that is known to a person skilled in the art.
Disclosure of Invention
In view of at least one of the above technical problems, the present disclosure provides a BOG gas recovery system and method for a hydrogenated and liquefied natural gas synthesis station, which condense and recover BOG by using high-grade cold energy possessed by liquid hydrogen itself.
According to one aspect of the disclosure, a BOG gas recovery system of a hydrogenation liquefied natural gas combined building station is provided, which is characterized by comprising an LNG storage tank, an output pipeline, a recovery pipeline, a heat exchanger, a liquid hydrogen system and a control unit; the liquid hydrogen system comprises a liquid hydrogen storage tank, a plunger pump and a downstream assembly which are sequentially communicated through a hydrogen transmission pipeline; the heat exchanger is arranged on a hydrogen conveying pipeline between the plunger pump and the downstream assembly, the output pipeline and the recovery pipeline are respectively and correspondingly communicated between the LNG storage tank and the heat exchanger, and the control unit comprises a plurality of temperature transmitters, pressure transmitters and a PLC (programmable logic controller); and the PLC is used for controlling the circulation amount of BOG in the LNG storage tank entering the heat exchanger based on the information collected by the temperature transmitter and the pressure transmitter.
In some embodiments of the present disclosure, a circulation pump is disposed in the output pipeline, and the PLC controller is electrically connected to the circulation pump to control the circulation amount of the BOG entering the heat exchanger.
In some embodiments of the present disclosure, a gas-liquid separation tank is disposed in the recovery pipeline, and the gas-liquid separation tank includes a liquid inlet pipeline and a gas inlet pipeline which are correspondingly communicated with the LNG storage tank, so that the BOG and the liquefied natural gas condensed by the heat exchanger are recovered into the LNG storage tank through the branch pipelines.
In some embodiments of the present disclosure, a temperature transmitter and a pressure transmitter are respectively provided in the output line and the recovery line.
In some embodiments of the present disclosure, a corresponding pressure transmitter is disposed in the LNG storage tank for detecting a pressure value in the LNG storage tank in real time.
In some embodiments of the present disclosure, the liquid hydrogen system comprises a liquid hydrogen tank and a plunger pump; the recycling pipeline is communicated with a bleeding branch, and a safety valve is arranged in the bleeding branch.
In some embodiments of the present disclosure, a solenoid valve is disposed in the hydrogen pipeline between the plunger pump and the heat exchanger to control the on/off of the liquid hydrogen.
According to another aspect of the present disclosure, a BOG gas recovery control method is provided, in which the BOG gas recovery system based on the above-mentioned hydrogenation and liquefied natural gas co-construction station includes the following steps:
s1, starting the plunger pump and the PLC to control the on/off of the circulating pump based on the information of the pressure transmitter in the LNG storage tank;
s2, after the circulating pump is started, the PLC controls the working circulation frequency of the circulating pump through the information of the temperature transmitter arranged in the recovery pipeline;
and S3, feeding the BOG and the liquefied natural gas condensed by the heat exchanger into an LNG storage tank through a gas-liquid separation tank.
In some embodiments of the present disclosure, in step S1, when the pressure transmitter in the LNG storage tank is greater than or equal to 0.4MPa, the PLC controller controls the circulation pump to start; otherwise, the circulating pump is controlled to stop.
In some embodiments of the present disclosure, in step S2, the PLC controller decreases the operating frequency of the circulation pump when the temperature transmitter in the recovery line is > -162 ℃; otherwise, the working frequency of the circulating pump is increased.
One or more technical solutions provided in the embodiments of the present application have at least any one of the following technical effects or advantages:
1. because the cold energy of the liquid hydrogen is adopted to provide enough cold energy for BOG liquefaction, the technical problems that a plurality of heat exchangers and refrigerating devices need to be additionally arranged in the prior art, and further the occupied area is reduced and the construction and use costs are reduced are effectively solved.
2. Because the PLC control system is adopted to control the implementation circulating power of the circulating pump based on the information acquired by the temperature transmitter in real time, the technical problem of low conversion efficiency in the BOG condensation process is effectively solved.
Drawings
Fig. 1 is a schematic structural diagram of a BOG gas recovery system of a hydrogenated and liquefied natural gas synthesis station according to an embodiment of the present application.
Fig. 2 is a schematic diagram of PLC control in an embodiment of the present application.
Fig. 3 is a flow chart of a BOG liquefaction logic control of an LNG storage tank according to another embodiment of the present disclosure.
In the above figures, 1, a liquid hydrogen storage tank; 2. a liquid hydrogen plunger pump; 3. a high-pressure solenoid valve; 4. a heat exchanger; 5. an LNG storage tank; 6. an output line; 7. a recovery line; 8. a circulation pump; 9. a gas-liquid separation tank; 10. a temperature transmitter; 11. a pressure transmitter; 12. a downstream component; 13. a PLC controller; 14. a safety valve.
Detailed Description
In the description of the present application, it is to be understood that the terms "upper", "lower", "front", "rear", "left", "right", "top", "bottom", "inner", "outer", "vertical", "horizontal", "clockwise", "counterclockwise", and the like, indicate orientations or positional relationships based on those shown in the drawings, and are used only for convenience in describing the present application and for simplicity in description, and do not indicate or imply that the devices or elements referred to must have a particular orientation, be constructed in a particular orientation, and be operated, and thus, are not to be construed as limiting the present application. The term "connected" and "coupled" when used in this application includes both direct and indirect connections (couplings), unless otherwise specified.
The programs referred to or relied on in the following embodiments are all conventional programs or simple programs in the art, and those skilled in the art can make routine selection or adaptation according to specific application scenarios.
The unit modules (components, structures, and mechanisms) and the devices such as sensors in the following examples are all conventional commercial products unless otherwise specified.
For better understanding of the technical solutions of the present application, the technical solutions will be described in detail below with reference to the drawings and specific embodiments.
Example one
The embodiment discloses a BOG gas recovery system of a hydrogenated and liquefied natural gas synthesis station, which is shown in figure 1 and comprises an LNG storage tank 5, an output pipeline 6, a recovery pipeline 7, a heat exchanger 4, a liquid hydrogen system and a control unit.
The LNG storage tank 5 is used for storing liquefied natural gas in the combined station, and the LNG is gasified to generate a flash evaporator due to the interference of external environment heat and the heat energy generated when a pump in the LNG storage tank 5 operates; a pressure transmitter 11 is arranged in the LNG storage tank 5 and used for monitoring the gas pressure in the storage tank in real time; one end of the output pipeline 6 is communicated with the gas outlet port of the LNG storage tank 5, the other end of the output pipeline is communicated with the heat exchanger, and a BOG circulating pump 8 is installed in the output pipeline 6 and used for enabling BOG gas in the LNG storage tank 5 to circularly enter the heat exchanger 4; one end of the recovery pipeline 7 is communicated with the heat exchanger 4, the other end of the recovery pipeline is communicated with the LNG storage tank 5, the liquefied natural gas and the incompletely converted BOG which pass through the heat exchanger 4 after absorbing cold energy are recovered into the LNG storage tank 5, a gas-liquid separation tank 9 is arranged in the recovery pipeline 7, two pipelines, namely a liquid inlet pipeline and an air inlet pipeline, are arranged between the gas-liquid separation tank 9 and the LNG storage tank 5 and are used for respectively recovering the liquefied natural gas and the incompletely converted BOG which are converted after absorbing cold energy by the heat exchanger 4 into the LNG storage tank 5.
The liquid hydrogen system comprises a liquid hydrogen storage tank 1, a liquid hydrogen plunger pump 2 and a downstream component 12, wherein the liquid hydrogen storage tank 1 is used for storing liquid hydrogen in a combined building station, the liquid hydrogen plunger pump 2 is communicated with the liquid hydrogen storage tank 1 through a hydrogen conveying pipeline and is used for conveying the liquid hydrogen in the liquid hydrogen storage tank 1 to the downstream component 12, the other end of the liquid hydrogen plunger pump 2 is communicated with a heat exchanger 4 through a pipeline, and the liquid hydrogen in the liquid hydrogen storage tank 1 is conveyed through the heat exchanger 4, so that a cold energy medium is provided for the heat exchanger due to high-grade cold energy of the liquid hydrogen, and the BOG passing through the heat exchanger is liquefied to form liquefied natural gas for recycling; a temperature transmitter 10 and a pressure transmitter 11 are arranged in a pipeline between the liquid hydrogen plunger pump 2 and the heat exchanger 4 for displaying the temperature of the liquid hydrogen in the pipeline and the pressure in the pipeline in real time, and a high-pressure electromagnetic valve 3 is also arranged for controlling the on-off of the pipeline for the liquid hydrogen entering the heat exchanger 4; the line carrying liquid hydrogen passes through heat exchanger 4 and is then routed via a hydrogen transfer line to downstream module 12 for hydroprocessing functions.
The device also comprises a control unit, which comprises a plurality of temperature transmitters 10, pressure transmitters 11 and a PLC (programmable logic controller) 13, as shown in figure 2; the LNG storage tank 5 is internally provided with a pressure transmitter 11 for detecting the pressure of the BOG gas in the LNG storage tank 5 in real time; the output pipeline 6 and the recovery pipeline 7 are respectively and correspondingly provided with a temperature transmitter 10 and a pressure transmitter 11 which are used for respectively monitoring the temperature and the pressure of BOG gas in the corresponding pipelines; the PLC 13 is electrically connected with the circulating pump 8, in the BOG recycling operation process, the PLC 13 controls the starting and stopping of the circulating pump 8 based on the value of the pressure transmitter 11 in the LNG storage tank 5, and the PLC 13 controls the circulating power of the circulating pump 8 based on the value of the temperature transmitter 10 in the recycling pipeline 7.
The recovery pipeline is also provided with a relief branch, a safety valve (the relief value of the safety valve is set to be 49.5 MPa) is arranged in the relief branch, and the relief branch is communicated with a relief main pipe in the closed building station to carry out centralized relief recovery.
Example two
The embodiment discloses a BOG gas recovery control method, which is implemented based on the BOG gas recovery system of the hydrogenation and liquefied natural gas filling station and comprises the following steps of:
and S1, starting the liquid hydrogen plunger pump 2, and conveying the liquid hydrogen in the liquid hydrogen storage tank 1 through a pipeline by the liquid hydrogen plunger pump 2 to pass through a heat exchanger.
S2, the PLC 13 compares the value of the pressure transmitter 11 in the LNG storage tank 5 with a preset standard value (0.4 MPa), and if the value is larger than or equal to 0.4MPa, the PLC controls the circulating pump 8 to start, so that BOG gas in the LNG storage tank 5 is circulated into the heat exchanger; if the pressure is less than 0.4MPa, the circulating pump 8 is controlled to stop working.
S3, the PLC 13 compares the value in the temperature transmitter 10 in the output pipeline 6 with the preset standard value (-162 ℃), if the value is equal to-162 ℃, the circulating pump 8 is controlled to keep the corresponding circulating power; if the temperature is higher than 162 ℃, controlling the circulating pump 8 to reduce the circulating power, and at the moment, the cold energy in the heat exchanger 4 is insufficient, so that the BOG is not completely liquefied and the efficiency is low; if the temperature is lower than-162 ℃, the circulating pump 8 is controlled to increase the circulating power, the cold energy in the heat exchanger 4 is sufficient, the amount of the BOG gas is increased, and the conversion of the BOG gas into the liquefied natural gas is further improved.
S4, stopping the pressure value of the pressure transmitter 11 in the liquid hydrogen plunger pump 2 or the circulating pump 8 or the LNG storage tank 5 is less than 0.4MPa, or the pressure value obtained by subtracting the pressure transmitter 11 in the LNG storage tank 5 from the pressure transmitter 11 in the output pipeline 6 is more than 0.2MPa (the BOG is judged to be changed into a solid to block the pipeline), or the value of the temperature transmitter 10 in the recovery pipeline 7 is less than-175 ℃ (the BOG temperature is too low, solidification is possible), and ending BOG liquefaction.
While certain preferred embodiments of the present invention have been described, additional variations and modifications in those embodiments may occur to those skilled in the art once they learn of the basic inventive concepts. Therefore, it is intended that the appended claims be interpreted as including preferred embodiments and all such alterations and modifications as fall within the scope of the invention.
It will be apparent to those skilled in the art that various changes and modifications may be made in the present invention without departing from the spirit and scope of the invention. Thus, the present invention is intended to include such modifications and variations, provided they come within the scope of the appended claims and their equivalents.

Claims (10)

1. A BOG gas recovery system of a hydrogenation and liquefied natural gas filling station is characterized by comprising an LNG storage tank, an output pipeline, a recovery pipeline, a heat exchanger, a liquid hydrogen system and a control unit; the liquid hydrogen system comprises a liquid hydrogen storage tank, a plunger pump and a downstream assembly which are sequentially communicated through a hydrogen transmission pipeline; the heat exchanger is arranged on a hydrogen conveying pipeline between the plunger pump and the downstream assembly, the output pipeline and the recovery pipeline are respectively and correspondingly communicated between the LNG storage tank and the heat exchanger, and the control unit comprises a plurality of temperature transmitters, pressure transmitters and a PLC (programmable logic controller); and the PLC is used for controlling the circulation amount of BOG in the LNG storage tank entering the heat exchanger based on the information collected by the temperature transmitter and the pressure transmitter.
2. The BOG gas recovery system of the hydrogenated and liquefied natural gas synthesis station according to claim 1, wherein a circulating pump is arranged in the output pipeline, and the PLC is electrically connected with the circulating pump to control the circulation amount of BOG entering the heat exchanger.
3. The BOG gas recovery system of the hydrogenated and liquefied natural gas synthesis station according to claim 1, wherein a gas-liquid separation tank is disposed in the recovery pipeline, and the gas-liquid separation tank comprises a liquid inlet pipeline and a gas inlet pipeline which are correspondingly communicated with the LNG storage tank, so that the BOG and the liquefied natural gas condensed by the heat exchanger are recovered into the LNG storage tank through the gas branch pipeline.
4. The BOG gas recovery system of the hydrogenated and liquefied natural gas synthesis station according to claim 1, wherein a temperature transmitter and a pressure transmitter are respectively and correspondingly arranged in the output pipeline and the recovery pipeline.
5. The BOG gas recovery system of the hydrogenated and liquefied natural gas co-construction station according to claim 1, wherein a corresponding pressure transmitter is provided in the LNG storage tank for detecting the pressure value in the LNG storage tank in real time.
6. The BOG gas recovery system of the hydrogenated and liquefied natural gas co-construction station according to claim 1, wherein a relief branch is communicated with the recovery pipeline, and a safety valve is arranged in the relief branch.
7. The BOG gas recovery system of the hydrogenated and liquefied natural gas synthesis station according to claim 1, wherein a solenoid valve is arranged in a hydrogen transmission line between the plunger pump and the heat exchanger to control the on/off of liquid hydrogen.
8. A BOG gas recovery control method, which is implemented based on the BOG gas recovery system of the hydrogenated and liquefied natural gas synthesis station of claim 1, and comprises the following steps:
s1, starting the plunger pump and the PLC to control the on/off of the circulating pump based on the information of the pressure transmitter in the LNG storage tank;
s2, after the circulating pump is started, the PLC controls the working circulation frequency of the circulating pump through the information of the temperature transmitter arranged in the recovery pipeline;
and S3, feeding the BOG and the liquefied natural gas condensed by the heat exchanger into an LNG storage tank through a gas-liquid separation tank.
9. The BOG gas recovery control method of claim 1, wherein in step S1, when the pressure transmitter in the LNG storage tank is greater than or equal to 0.4MPa, the PLC controller controls the circulation pump to start; otherwise, the circulating pump is controlled to stop.
10. The BOG gas recovery control method according to claim 1, wherein the PLC controller decreases the operating frequency of the circulation pump when the temperature transmitter in the recovery line is > -162 ℃ in step S2; otherwise, the working frequency of the circulating pump is increased.
CN202210589432.5A 2022-05-27 2022-05-27 BOG gas recovery system and method for hydrogenation and liquefied natural gas combined building station Active CN114893719B (en)

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