KR20150005036A - System and method for treating boil-off gas for a ship - Google Patents

System and method for treating boil-off gas for a ship Download PDF

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Publication number
KR20150005036A
KR20150005036A KR20130078234A KR20130078234A KR20150005036A KR 20150005036 A KR20150005036 A KR 20150005036A KR 20130078234 A KR20130078234 A KR 20130078234A KR 20130078234 A KR20130078234 A KR 20130078234A KR 20150005036 A KR20150005036 A KR 20150005036A
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KR
South Korea
Prior art keywords
lng
storage tank
gas
heat exchanger
compressed
Prior art date
Application number
KR20130078234A
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Korean (ko)
Inventor
이준채
문영식
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대우조선해양 주식회사
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Priority to KR20130078234A priority Critical patent/KR20150005036A/en
Priority to PCT/KR2014/005976 priority patent/WO2015002491A1/en
Publication of KR20150005036A publication Critical patent/KR20150005036A/en

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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
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B63—SHIPS OR OTHER WATERBORNE VESSELS; RELATED EQUIPMENT
    • B63B—SHIPS OR OTHER WATERBORNE VESSELS; EQUIPMENT FOR SHIPPING 
    • B63B25/00—Load-accommodating arrangements, e.g. stowing, trimming; Vessels characterised thereby
    • B63B25/02—Load-accommodating arrangements, e.g. stowing, trimming; Vessels characterised thereby for bulk goods
    • B63B25/08—Load-accommodating arrangements, e.g. stowing, trimming; Vessels characterised thereby for bulk goods fluid
    • B63B25/12—Load-accommodating arrangements, e.g. stowing, trimming; Vessels characterised thereby for bulk goods fluid closed
    • B63B25/16—Load-accommodating arrangements, e.g. stowing, trimming; Vessels characterised thereby for bulk goods fluid closed heat-insulated
    • 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
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J5/00—Arrangements of cold exchangers or cold accumulators in separation or liquefaction plants
    • 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
    • F17C2223/0146—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
    • F17C2223/00—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel
    • F17C2223/03—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel characterised by the pressure level
    • F17C2223/033—Small pressure, e.g. for liquefied gas
    • 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
    • F17C2223/04—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel characterised by other properties of handled fluid before transfer
    • F17C2223/042—Localisation of the removal point
    • F17C2223/043—Localisation of the removal point in the gas
    • 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
    • F17C2223/04—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel characterised by other properties of handled fluid before transfer
    • F17C2223/042—Localisation of the removal point
    • F17C2223/046—Localisation of the removal point in the liquid
    • F17C2223/047—Localisation of the removal point in the liquid with a dip tube
    • 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
    • F17C2225/0123—Single phase gaseous, e.g. CNG, GNC
    • 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
    • F17C2225/03—Handled fluid after transfer, i.e. state of fluid after transfer from the vessel characterised by the pressure level
    • F17C2225/035—High pressure, i.e. between 10 and 80 bars
    • 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
    • F17C2227/01—Propulsion of the fluid
    • F17C2227/0128—Propulsion of the fluid with pumps or compressors
    • F17C2227/0157—Compressors
    • 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
    • F17C2227/0171—Arrangement
    • F17C2227/0178—Arrangement in the vessel
    • 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
    • F17C2227/0171—Arrangement
    • F17C2227/0185—Arrangement comprising several pumps or compressors
    • 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
    • F17C2227/0306—Heat exchange with the fluid by heating using the same fluid
    • 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
    • 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
    • F17C2265/03—Treating the boil-off
    • F17C2265/032—Treating the boil-off by recovery
    • F17C2265/037—Treating the boil-off by recovery with pressurising
    • 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
    • F17C2265/05—Regasification
    • 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
    • F17C2265/066—Fluid distribution for feeding engines for propulsion
    • 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
    • F17C2270/00—Applications
    • F17C2270/01—Applications for fluid transport or storage
    • F17C2270/0102—Applications for fluid transport or storage on or in the water
    • F17C2270/0105—Ships

Abstract

The present invention relates to an evaporation gas treatment system for a ship capable of returning evaporation gas to a storage tank by reliquefying the evaporation gas using the cold and heat of the LNG, thereby treating the evaporation gas without using a reliquefying device having a separate refrigerant cycle; and to an evaporation gas treatment method for a ship. The evaporation gas treatment system for a ship is provided to treat evaporation gas generated in the storage tank by being installed in the ship including a regasification facility which regasifies the LNG stored in the storage tank; and comprises: a compressor compressing the evaporation gas discharged from the storage tank; and a heat exchanger cooling the evaporation gas compressed by the compressor. The heat exchanger is installed in the downstream side of a high pressure pump compressing the LNG, which is discharged from the storage tank, to have a pressure required by demand; and cools the evaporation gas compressed by the compressor using the cold and heat of the LNG compressed by the high pressure pump.

Description

TECHNICAL FIELD [0001] The present invention relates to a system and a method for treating a vapor of a ship,

The present invention relates to a system and a method for treating an evaporative gas of a ship, and more particularly, to a system and method for treating an evaporative gas of a ship, To an evaporative gas treatment system and method for a ship capable of treating an evaporative gas without using a re-liquefying apparatus having a separate refrigerant cycle by liquefying and returning to a storage tank.

In recent years, consumption of natural gas has been rapidly increasing worldwide. Natural gas is transported in a gaseous state via land or sea gas piping, or is transported to a distant consumer where it is stored in an LNG carrier (particularly an LNG carrier) in the state of liquefied natural gas. Liquefied natural gas is obtained by cooling natural gas at cryogenic temperatures (approximately -163 ° C), and its volume is reduced to approximately 1/600 of that of natural gas, making it well suited for long-distance transport through the sea.

LNG carriers are used to transport liquefied natural gas to the sea by carrying liquefied natural gas. For this purpose, LNG storage tanks (often referred to as 'cargo holds') capable of withstanding cryogenic temperatures of liquefied natural gas, . Generally, such LNG carrier cargoes liquefied natural gas in the LNG storage tank in the liquefied state on land, and the unloaded LNG is regenerated by the LNG regeneration facility installed on the land, and then transported through the gas pipeline to the consuming place of natural gas do.

These LNG regasification facilities on the land are known to be advantageous economically when the natural gas market is well established and it is installed in a stable natural gas demand place. However, it is economically disadvantageous to install LNG regasification facilities on land because of the high installation and maintenance costs, in the case of natural gas demand where natural gas demand is seasonal, short-term or periodic.

Especially, when the LNG carrier is destroyed by natural disasters, even if the LNG carriers arrive at the destination with LNG, it is impossible to regenerate the LNG. It is holding.

Accordingly, for example, an offshore LNG regasification system, in which an LNG regeneration facility is provided on a marine plant or an LNG carrier, regenerates liquefied natural gas at sea, and supplies the natural gas obtained from the regeneration to the land Developed.

A storage tank capable of storing liquefied gas at a cryogenic temperature and a ship having a regeneration facility for regenerating the liquefied gas include a plant such as an LNG RV (Regasification Vessel) or an LNG FSRU (Floating Storage and Regulation Unit) .

LNG RV is a LNG regeneration facility installed on a liquefied gas carrier capable of self-sailing and floating. LNG FSRU stores liquefied natural gas unloaded from an LNG carrier in off-shore area in the storage tank, It is an offshore structure that supplies natural gas to the demand of the land. In the present specification, the term "ship" is a concept including both LNG RV and LNG FSRU.

Since the liquefaction temperature of natural gas is a cryogenic temperature of about -163 ° C at normal pressure, LNG is evaporated even if its temperature is slightly higher than -163 ° C at normal pressure. Although the storage tanks installed in ships such as LNG RV and LNG FSRU are insulated, external heat is constantly transferred to the LNG, so that the LNG is constantly vaporized in the storage tank and the evaporation gas (BOG ; Boil-Off Gas) occurs.

Conventionally, in ships such as LNG RV and LNG FSRU, BOG was melted in LNG and supplied to the land in the re-condenser in order to treat the BOG generated in the storage tank. However, if the re-condensation capacity is too low to recycle all the BOGs, they must be burned through a gas com- bustion unit (GCU) or vented to the atmosphere as it is.

In order to reduce the natural gas to be discarded, a method of re-liquefying the BOG by re-liquefying a refrigerant cycle and returning it to the storage tank has been proposed. However, when the re-liquefying apparatus is used, the manufacturing cost of the ship is increased, a space for installing the re-liquefying apparatus in a ship having a limited space is secured, and a problem that the operating cost is increased due to a considerable amount of energy consumed in re-liquefaction have.

Disclosure of Invention Technical Problem [8] Accordingly, the present invention has been made to solve the above-mentioned problems occurring in the prior art, and it is an object of the present invention to provide an LNG storage tank, It is an object of the present invention to provide an evaporative gas treatment system and method for a ship capable of treating an evaporative gas without using a re-liquefying apparatus having a separate refrigerant cycle by returning to a tank.

According to an aspect of the present invention, there is provided an apparatus for recovering LNG stored in a storage tank, the apparatus including a regeneration unit for regenerating LNG stored in a storage tank, the evaporation gas 1. A treatment system comprising: a compressor for compressing an evaporated gas discharged from the storage tank; A heat exchanger for cooling the evaporated gas compressed in the compressor; Wherein the heat exchanger is installed downstream of a high-pressure pump for compressing the LNG discharged from the storage tank to a pressure required by a customer, and compresses the compressed LNG in the compressor using the LNG compressed by the high- And the evaporation gas is cooled.

The evaporated gas cooled and re-liquefied in the heat exchanger is preferably supplied to the storage tank and stored.

And an expansion valve for reducing the evaporated gas cooled in the heat exchanger and re-liquefied.

Preferably, the evaporative gas processing system further includes a DFDE system for receiving and consuming the compressed evaporated gas in the compressor.

Preferably, the evaporative gas processing system further includes a GCU for receiving and consuming compressed evaporative gas from the compressor.

The LNG heated through the heat exchange with the evaporation gas in the heat exchanger is preferably vaporized by the vaporizer and then supplied to the customer.

According to another aspect of the present invention, there is provided an LNG storage tank comprising: a storage tank for storing LNG; A regasification facility for regenerating the LNG stored in the storage tank; The evaporative gas processing system installed to process the evaporative gas generated in the storage tank; Lt; RTI ID = 0.0 > RV < / RTI >

According to another aspect of the present invention, there is provided an LNG storage tank comprising: a storage tank for storing LNG; A regasification facility for regenerating the LNG stored in the storage tank; The evaporative gas processing system installed to process the evaporative gas generated in the storage tank; Lt; RTI ID = 0.0 > FSRU. ≪ / RTI >

According to another aspect of the present invention, there is provided a method of controlling an LNG stored in a storage tank, the method comprising the steps of: evaporating a vapor of a vessel installed in a vessel including a regeneration facility for regenerating LNG stored in the storage tank, CLAIMS What is claimed is: 1. A method of treating a gas, comprising: compressing an evaporated gas discharged from the storage tank; A cooling step of cooling the evaporated gas compressed in the compressing step; Wherein the cooling step includes a cooling step of cooling the LNG discharged from the storage tank to a pressure required by a customer, And the evaporation gas compressed in the compressing step is cooled.

The evaporated gas cooled and re-liquefied in the heat exchanger is preferably supplied to the storage tank after being depressurized and stored.

The LNG heated through the heat exchange with the evaporation gas in the heat exchanger is preferably vaporized and then supplied to the customer.

According to the present invention, when the LNG stored in the storage tank is regenerated and supplied to the shore, the evaporative gas in the storage tank can be re-liquefied by using the cold heat of the LNG and returned to the storage tank. System and method can be provided.

Therefore, according to the evaporation gas processing system and method of the present invention, the evaporation gas can be processed without using a re-liquefier having a separate refrigerant cycle.

Further, according to the evaporative gas treatment system and method of the present invention, since the heat exchanger installed for the heat exchange between the evaporated gas and the LNG is located on the downstream side of the pump, the LNG, It is not necessary to worry about adverse effects on the pump, and thus the liquefaction capacity of the evaporated gas can be increased.

BRIEF DESCRIPTION OF THE DRAWINGS FIG. 1 is a schematic diagram showing a system for processing an evaporative gas of a ship according to the present invention; FIG.

Hereinafter, an evaporative gas processing system according to a preferred embodiment of the present invention will be described in detail with reference to the drawings. FIG. 1 is a view schematically showing a configuration of a vapor gas treatment system for a ship according to the present invention.

The evaporative gas treatment system according to the preferred embodiment of the present invention shown in FIG. 1 is capable of storing LNG in the storage tank 11 and is applied to a ship capable of regenerating the stored LNG to supply it to a demand place on the land.

A storage tank capable of storing liquefied gas at a cryogenic temperature and a ship having a regeneration facility for regenerating the liquefied gas include a plant such as an LNG RV (Regasification Vessel) or an LNG FSRU (Floating Storage and Regulation Unit) . LNG RV is a LNG regeneration facility installed on a liquefied gas carrier capable of self-sailing and floating, and LNG FSRU stores liquefied natural gas unloaded from an LNG carrier in the sea off the sea, stored in a storage tank, It is an offshore structure that supplies natural gas to the demand of the land. In the present specification, the term "ship" is a concept including both LNG RV and LNG FSRU.

The vessel according to the present invention is provided with an LNG (Liquefied Natural Gas) configured to be able to vaporize the liquefied natural gas (LNG) discharged from the storage tank 11 along the transfer line while vaporizing the liquefied natural gas A re-ignition system is provided.

The LNG regasification system includes a discharge pump 21 for discharging the stored LNG stored in the storage tank 11 to the outside of the storage tank and an LNG discharged by the discharge pump 21 at a higher pressure And a high-pressure pump 23 for supplying the vaporized gas to the vaporizer 25.

The LNG compressed by the high-pressure pump 23 to a pressure (for example, 100 bar) demanded by the customer onshore is vaporized in the vaporizer 25 and then supplied to the customer. Means that the LNG is compressed at a pressure higher than the pressure compressed by the discharge pump 21 that discharges the LNG from the storage tank 11 and the range of the high pressure is specified It is not.

On the other hand, the storage tank has a sealing and thermal barrier to store liquefied gas such as LNG in a cryogenic condition, but it can not completely block the heat transmitted from the outside. Accordingly, evaporation of the liquefied gas is continuously performed in the storage tank 11, and it is necessary to appropriately treat the evaporative gas generated in the storage tank 11 in order to maintain the internal pressure of the storage tank at an appropriate level.

According to the present invention, the evaporated gas generated in the storage tank 11 is discharged from the storage tank, compressed in the compressor 13, and re-liquefied and returned to the storage tank 11. A heat exchanger 15 is provided between the high pressure pump 23 and the vaporizer 25 in the line through which the LNG is transferred and the evaporated gas compressed by the compressor 13 is supplied to the heat exchanger 15, Heat exchanged.

The LNG compressed by the high-pressure pump 23 is heated by the evaporating gas in the heat exchanger 15 before being vaporized in the vaporizer 25 and the evaporated gas compressed by the compressor 13 is heated in the heat exchanger 15 by the LNG It can be re-liquefied by being cooled. The liquefied evaporated gas is decompressed while passing through the expansion valve (17), and returned to the storage tank (11) and stored.

At least a part of the evaporated gas compressed in the compressor 13 is supplied to a dual fuel diesel electric electric system (DFDE) system or a gas combustion unit (GCU) when the evaporated gas above the processing capacity that can be re-liquefied by the heat exchanger 15 is generated. To be consumed. In addition, if necessary, the evaporation gas may be vented to the atmosphere as it is.

The method of treating the evaporation gas by re-liquefaction using the cold heat of the LNG as in the present invention can treat a larger amount of BOG than the method of dissolving the evaporation gas in the LNG and feeding it to the vaporizer through the recondenser, Accordingly, it is possible to reduce the amount of the evaporative gas that is burned in the GCU or released as it is in the air.

Further, according to the present invention, there is no need to provide a separate re-liquefying device (i.e., a refrigerant cycle) for re-liquefying the evaporation gas using the refrigerant, thereby reducing the cost and effort required for installing and operating the re-liquefying device .

The evaporation gas processing system of the present invention comprises a heat exchanger (not shown) installed downstream of the high-pressure pump 23 for heat exchange between the LNG supplied to the vaporizer 25 and the evaporated gas discharged from the storage tank 11 15). As described above, since the heat exchanger 15 for re-liquefying the evaporation gas by using the cold heat of the LNG is provided on the downstream side of the high-pressure pump 23, it is possible to fully utilize the cooling and heating of the LNG without fear of damaging the high-pressure pump.

In the case of a pump, it is possible to compress only the liquid material, and if gaseous material is introduced, it may be damaged. Particularly, since LNG is a liquid at a cryogenic temperature, a high-pressure pump for compressing LNG may be further damaged when gaseous substances are introduced. Accordingly, when the heat exchanger is disposed on the upstream side of the high-pressure pump, the amount of evaporative gas that can be re-liquefied is limited in order to prevent vaporization of even a small amount of LNG.

However, according to the present invention, by providing the heat exchanger 15 for heat exchange between the LNG and the evaporation gas on the downstream side of the high-pressure pump 23, even if the LNG heated in the heat exchanger is partially vaporized, do. Accordingly, approximately 7% of the evaporation gas can be further liquefied in comparison with the case where the heat exchanger is disposed on the upstream side of the high-pressure pump under the same conditions.

It will be apparent to those skilled in the art that various modifications and variations can be made in the present invention without departing from the spirit and scope of the invention will be.

11: Storage tank 13: Compressor
15: heat exchanger 17: expansion valve
21: exhaust pump 23: high-pressure pump
25: vaporizer

Claims (11)

An evaporative gas treatment system for a ship, which is installed in a vessel including a regeneration facility for regenerating LNG stored in a storage tank and processes the evaporation gas generated in the storage tank,
A compressor for compressing the evaporated gas discharged from the storage tank;
A heat exchanger for cooling the evaporated gas compressed in the compressor;
/ RTI >
The heat exchanger is installed downstream of a high pressure pump that compresses the LNG discharged from the storage tank to a pressure demanded by a customer, and uses the cold heat of the LNG compressed in the high pressure pump to cool the evaporated gas compressed in the compressor And the evaporation gas processing system of the ship. The method according to claim 1,
And the evaporated gas cooled and re-liquefied in the heat exchanger is supplied to and stored in the storage tank. The method of claim 2,
Further comprising an expansion valve for reducing the evaporated gas cooled by the heat exchanger and re-liquefied. The method according to claim 1,
Further comprising a DFDE system for receiving and consuming compressed evaporated gas from the compressor. The method according to claim 1,
Further comprising a GCU for receiving and consuming the compressed evaporated gas in the compressor. The method according to claim 1,
Wherein the LNG heated through the heat exchange with the evaporation gas in the heat exchanger is vaporized by the vaporizer and then supplied to the customer. A storage tank for storing LNG;
A regasification facility for regenerating the LNG stored in the storage tank;
The evaporative gas processing system according to any one of claims 1 to 6, which is installed for processing evaporative gas generated in the storage tank.
The LNG RV. A storage tank for storing LNG;
A regasification facility for regenerating the LNG stored in the storage tank;
The evaporative gas processing system according to any one of claims 1 to 6, which is installed for processing evaporative gas generated in the storage tank.
The LNG FSRU. 1. A method for processing an evaporative gas by a vapor-processing system of a ship installed in a vessel including a re-vaporization facility for re-vaporizing LNG stored in a storage tank, for processing an evaporative gas generated in the storage tank,
A compression step of compressing the evaporated gas discharged from the storage tank;
A cooling step of cooling the evaporated gas compressed in the compressing step;
/ RTI >
Wherein the cooling step includes a cooling step of cooling the LNG discharged from the storage tank to a pressure required by a customer, And cooling the compressed evaporated gas. The method of claim 9,
Wherein the evaporated gas cooled and re-liquefied in the heat exchanger is decompressed and then supplied to and stored in the storage tank. The method of claim 9,
Wherein the LNG heated through the heat exchange with the evaporating gas in the heat exchanger is vaporized and then supplied to the customer.
KR20130078234A 2013-07-04 2013-07-04 System and method for treating boil-off gas for a ship KR20150005036A (en)

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PCT/KR2014/005976 WO2015002491A1 (en) 2013-07-04 2014-07-03 System and method for treating evaporated gas from ship

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