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KR101864150B1 - LNG transfer system - Google Patents

LNG transfer system Download PDF

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Publication number
KR101864150B1
KR101864150B1 KR1020170086289A KR20170086289A KR101864150B1 KR 101864150 B1 KR101864150 B1 KR 101864150B1 KR 1020170086289 A KR1020170086289 A KR 1020170086289A KR 20170086289 A KR20170086289 A KR 20170086289A KR 101864150 B1 KR101864150 B1 KR 101864150B1
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KR
South Korea
Prior art keywords
container
natural gas
lng
liquefied
storage unit
Prior art date
Application number
KR1020170086289A
Other languages
Korean (ko)
Inventor
김정
박용환
박태윤
송창우
이성주
전상배
천진솔
Original Assignee
삼성중공업 주식회사
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
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Publication date
Application filed by 삼성중공업 주식회사 filed Critical 삼성중공업 주식회사
Priority to KR1020170086289A priority Critical patent/KR101864150B1/en
Application granted granted Critical
Publication of KR101864150B1 publication Critical patent/KR101864150B1/en

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    • 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
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B63—SHIPS OR OTHER WATERBORNE VESSELS; RELATED EQUIPMENT
    • B63B—SHIPS OR OTHER WATERBORNE VESSELS; EQUIPMENT FOR SHIPPING 
    • B63B27/00—Arrangement of ship-based loading or unloading equipment for cargo or passengers
    • B63B27/30—Arrangement of ship-based loading or unloading equipment for transfer at sea between ships or between ships and off-shore structures
    • B63B27/34—Arrangement of ship-based loading or unloading equipment for transfer at sea between ships or between ships and off-shore structures using pipe-lines
    • 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
    • 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
    • F17C2265/035—Treating the boil-off by recovery with cooling with subcooling the liquid 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
    • 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

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  • Engineering & Computer Science (AREA)
  • Mechanical Engineering (AREA)
  • Chemical & Material Sciences (AREA)
  • Combustion & Propulsion (AREA)
  • Ocean & Marine Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Filling Or Discharging Of Gas Storage Vessels (AREA)

Abstract

The present invention provides a liquefied natural gas (LNG) transport system which can minimize boil-off gas (BOG) produced when transporting liquefied natural gas. According to an aspect of the present invention, the liquefied natural gas transport system comprises: a main line to transport liquefied natural gas from a first storage unit storing the liquefied natural gas to an external second storage unit; a loading device having a container enclosing the main line and having a prescribed space formed therein; a cooling device to supercool a portion of the liquefied natural gas stored in the first storage unit to supply the supercooled liquefied natural gas to the container; and a steam return line to supply boil-off gas (BOG) produced from the liquefied natural gas transported to the second storage unit to the container. The liquefied natural gas injected through the steam return line is re-liquefied by the supercooled liquefied natural gas supplied to the container.

Description

[0001] LNG transfer system [0002]

The present invention relates to a liquefied natural gas transportation system, and more particularly, to a liquefied natural gas transportation system capable of minimizing boil-off gas (BOG) generated when transporting liquefied natural gas.

In general, natural gas is transported in the form of gas through land or sea gas pipelines or stored in a cargo tank of a carrier in the form of liquefied natural gas (LNG) Can be transported to the customer's destination.

This LNG is obtained by cooling the natural gas to a cryogenic temperature of approximately -163 ° C, and its volume is reduced to approximately 1/600 of that of the natural gas in the gaseous state, making it well suited for long distance transportation through the sea.

LNG can generate boil off gas (BOG) when it is supplied, loaded or unloaded and natural boil off gas (NBOG) is generated naturally. do.

An LNG carrier, a floating production storage vessel, or both loading and unloading devices for the cargo window of such an LNG storage or loading facility typically loads or unloads LNG into the storage tank through a system equipped with a loading arm.

However, as described above, a large amount of BOG and NBOG are generated or increased as the LNG is vaporized during the transfer of the LNG. In other words, if the generated BOG is not properly discharged, it can act as a factor that hinders the flow of LNG.

Also, the BOG generated in the piping flows into the storage tank of the cargo hold to increase the internal pressure of the storage tank, and when the BOG exceeds the reference level, the BOG is generated.

To solve this problem, some LNG carriers use the vent master to vent air and use it as fuel for the engine, which increases the waste of BOG. In addition, even if the liquefaction equipment is equipped, not only the cost for the equipment is added but also the cost due to continuous operation is added.

The liquefied natural gas transfer system according to the embodiment of the present invention can effectively reduce the BOG generated during LNG transfer and minimize the operation cost.

According to an aspect of the present invention, there is provided a liquefied natural gas (LNG) delivery system, comprising: a main line for transferring the liquefied natural gas from a first reservoir where the liquefied natural gas is stored to an external second reservoir; A loading device having a container surrounding the main line and having a predetermined space formed therein; A cooling device for subcooling a portion of the liquefied natural gas stored in the first storage section and providing the part to the container; And a vapor return line for providing vaporized natural gas (BOG) generated from the liquefied natural gas transferred to the second storage unit to the container, wherein the vaporized natural gas injected through the vapor return line is supplied to the container, A liquefied natural gas transfer system which is re-liquefied by sub-cooled liquefied natural gas can be provided.

The steam return line may be connected to the first storage unit through the container.

The apparatus may further include a vapor line for supplying natural convection gas (NBOG) generated in the first storage unit to the container.

Further, the natural evaporation gas injected through the steam line can be re-liquefied by the sub-cooled liquefied natural gas provided in the container.

The steam line may be connected to the second storage unit through the container.

The cooling device may also include a subcooling fluid supply line for providing subcooled liquefied fuel gas to the container and a spray line for selectively providing subcooled liquefied fuel gas.

Further, when the temperature and pressure inside the container are measured and the temperature and pressure inside the container are lower than a predetermined reference value, the temperature and pressure in the container can be maintained by injecting the supercooled liquefied fuel gas through the spray line.

The apparatus may further include a fluid return line for allowing the subcooled liquefied fuel gas provided in the container to selectively flow into the first reservoir.

The liquefied natural gas transfer system according to an embodiment of the present invention can effectively reduce BOG by supercooling LNG stored in the first storage unit and re-liquefying BOG and NBOG generated during LNG transfer through the supercooled LNG, The operation cost can be minimized.

Also, there is an effect of providing a stable LNG transportation system by periodically or selectively injecting super-cooled LNG to the re-liquefaction facility so as to keep the temperature and pressure constant.

BRIEF DESCRIPTION OF THE DRAWINGS The present invention will be described in detail with reference to the following drawings, which illustrate preferred embodiments of the present invention, and thus the technical idea of the present invention should not be construed as being limited thereto.
1 is a schematic diagram of an LNG delivery system in accordance with an embodiment of the present invention.
Figure 2 is a schematic representation of an LNG delivery system in accordance with another embodiment of the present invention.

Hereinafter, embodiments of the present invention will be described in detail with reference to the accompanying drawings. The following embodiments are provided to fully convey the spirit of the present invention to a person having ordinary skill in the art to which the present invention belongs. The present invention is not limited to the embodiments shown herein but may be embodied in other forms. For the sake of clarity, the drawings are not drawn to scale, and the size of the elements may be slightly exaggerated to facilitate understanding.

1 is a schematic diagram of an LNG delivery system in accordance with an embodiment of the present invention.

1, an LNG transfer system 1 according to an embodiment of the present invention is for transferring a fluid, i.e., LNG, between a first storage unit 10 and a second storage unit 20, And it is an object of the present invention to reduce the generated BOG and NBOG. Accordingly, the first storage unit 10 in which the LNG is stored may be a ship, and the second storage unit 20 may be a ship, a floating type, or a fixed type terminal, but is not limited thereto. In addition, the present invention can be applied to fluid transfer between the first storage unit 10 and the second storage unit 20, which constitute various structures performing relative motion.

The LNG transfer system 1 includes a main line 40 for transferring the LNG from the first storage unit 10 to the second storage unit 20 and a main line 40 surrounding the main line 40, A loading device 30 having a container 32 and a cooling device 70 and a second storage section 20 which provide the container 32 with a part of the LNG stored in the first storage section 10, And a vapor return line 50 that provides the BOG generated from the LNG to the container 32.

The LNG transport system 1 includes manifolds 11 and 12 provided on the sides of the first and second storage units 10 and 20 for connection between the first storage unit 10 and the second storage unit 20, 21). The manifolds 11 and 21 can be understood as a unit and a structure used for the transfer operation of the LNG including a multi-branch pipe, a multi-branch pipe support, and a platform under the multi-branch pipe support. Since these manifolds 11 and 21 are well known in the art, their detailed description will be omitted.

A loading device 30 is provided between the manifolds 11 and 21. The loading device 30 is connected to various lines 40 connecting the first storage part 10 and the second storage part 20, , 50, 60, 71, 74, 80). The container 32 may be provided in a closed form having a predetermined space therein. Further, the container 32 is connected to the interior space by communicating with the various lines 40, 50, 60, 71, 74 and 80, or the lines 40, 50, 60, 71, 74, And is connected to the first and second storage units 10 and 20 so that stable LNG transfer can be performed. Here, the 'line' represented in the description of the present invention may be a flexible hose or a rigid pipe or the like.

Meanwhile, the loading device 30 may be provided in the form of a loading arm. Accordingly, the container 32 can have a structure capable of responding to a front-back surge and a vertical motion according to an external environment.

The main line 40 passes through the container 32 of the loading device 30 and is connected to the manifolds 11 and 21 provided in the first and second storage units 10 and 20. The main line 40 is connected to the main pump 42 installed in the first storage unit 10. That is, according to the operation of the main pump 42, the LNG is transferred to the second storage unit 20 through the main line 40.

A large amount of BOG is generated as the LNG is vaporized according to the internal temperature of the second storage unit 20 or the external environment during transportation when the LNG is transferred to the second storage unit 20 through the main line 40. [ The steam return line 50 is provided to provide the BOG generated from the LNG transferred to the second storage unit 20 to the container 32.

The steam return line 50 may be connected to the container 32 via a manifold 21 provided on the second storage 20 side. According to an aspect of the present invention, a cooling device 70 for re-liquefying the BOG discharged into the container 32 through the steam return line 50 is provided. The cooling device 70 recools the BOG by performing a supercooling operation to lower the temperature of the existing LNG and heat-exchanging the BOG with the supercooled LNG.

More specifically, the cooling device 70 serves to supercool the LNG stored in the first storage unit 10 by receiving a predetermined amount of the LNG. The cooling device 70 can be subcooled by receiving the LNG through the sub-pump 72 installed in the first storage part 10. [ The LNG stored in the first storage unit 10 may be supercooled and supplied to the container 32. The LNG may be supercooled LNG (hereinafter referred to as " supercooled LNG " ). The cooling device 70 may be connected to the container 32 through the subcooling fluid supply line 71. Thus, the supercooled LNG is supplied to the inside of the container 32 through the subcooling fluid providing line 71 so that the inside of the container 32 is filled with the subcooled LNG.

As described above, since the main line 40 is wrapped by the supercooled LNG when the LNG is fed through the main line 40 in the state where the container 32 is filled with the supercooled LNG, the BOG generation is reduced. Further, when the BOG generated from the second storage unit 20 is pumped into the container 32, the BOG is heat-exchanged with the supercooled LNG to be re-liquefied.

Meanwhile, the temperature of the supercooled LNG gradually increases as the BOG is heat-exchanged and re-liquefied in the container 32. That is, the temperature and the pressure rise in the container 32 are caused. In order to maintain the temperature and pressure in the container 32, a spray device 75 for spraying the subcooled LNG into the container 32 is further provided.

The spray device 75 is installed inside the container 32. The spray device 75 is connected to the cooling device 70 through a spray line 74. The spray device 75 measures the temperature and pressure inside the container 32 through a sensor unit (not shown) and injects the supercooled LNG when the temperature and pressure are below a predetermined reference value.

The supercooled LNG to be filled in the container 32 may be configured to discharge the supercooled LNG in the container 32 in accordance with the re-liquefaction of the BOG and the supply of the subcooled LNG through the spray device 75. For example, it may further include a fluid return line 80 connecting the first storage unit 10 and the container 32.

The fluid return line 80 connects the container 32 and the first storage unit 10 so that the subcooled LNG provided to the container 32 is selectively introduced into the first storage unit 10. [ The flow of this subcooled LNG can be controlled through a control valve 82 provided in the fluid return line 80.

As described above, the supercooled LNG stored in the first storage unit 10 is supercooled and the super-cooled LNG supplied to the container 32 and the re-liquefied LNG and spray device 75 of the BOG discharged from the second storage unit 20 So that the supercooled LNG injected into the container 32 flows into the first storage unit 10 again, so that the super-cooled LNG can be circulated without waste of the cheap LNG.

Meanwhile, the LNG stored in the first storage unit 10 naturally generates NBOG. Accordingly, it is possible to further include a steam line 60 for supplying the NBOG to the container 32.

The steam line 60 may be connected to the container 32 through a manifold 11 provided on the first storage 10 side. The NBOG injected through the steam line 60 can be re-liquefied when it is heat-exchanged with the subcooled LNG filled in the inside of the container 32. Accordingly, the NBOG can be re-liquefied like the BOG described above, and then selectively introduced into the first storage unit 10 again.

In addition, each of the lines 40, 50, 60, and 80 connecting the first storage unit 10 with the container 32 and the second storage unit 20, the cooling device 70 and the container 32, A control valve for controlling the flow of the gas and the fluid is provided on the lines 71 and 74 for connecting the gas and the fluid.

The LNG transfer system 1 according to an aspect of the present invention includes a steam return line 50 connecting the second storage unit 20 and the container 32 and a steam return line 50 connecting the first storage unit 10 and the container 32. [ The vapor return line 50 and the vapor line 60 are shown as being resiliently liquefied within the container 32 in communication with the interior of the container 32, And may be connected to the first and second storage units 10 and 20, respectively. Such an embodiment is shown in Fig. Figure 2 is a schematic representation of an LNG delivery system in accordance with another embodiment of the present invention. Here, the same reference numerals as in the drawings shown above indicate members having the same function.

2, the LNG transfer system 1 'according to the present embodiment includes a main line 40 for transferring the LNG of the first storage unit 10 to the second storage unit 20, A cooling device 70 for providing the container 32 with the LNG under a supercooling condition and a second storage section 20 for storing the supercooled LNG, A steam return line 50 'for discharging BOG generated from the LNG, a steam line 60' for discharging the NBOG generated naturally from the first storage unit 10, and a subcooled LNG 1 storage unit 10, as shown in FIG.

The steam return line 50 'for discharging the BOG from the second storage unit 20 is provided in the first storage unit 10 and the second storage unit 20 through the container 32, And is connected to the manifolds 11 and 21. Thus, the BOG passing through the steam return line 50 'is heat-exchanged by the supercooled LNG filled in the container 32 and is re-liquefied. Thus, the re-liquefied BOG is stored in the first storage unit 10 via the steam return line 50 '.

The steam line 60 'for discharging the NBOG from the first storage unit 10 is connected to the manifolds 11 and 12 provided in the first storage unit 10 and the second storage unit 20 through the container 32, 21). Accordingly, the NBOG passing through the steam line 60 'is heat-exchanged by the supercooled LNG filled in the container 32 and re-liquefied. Thus, the reclaimed NBOG is transferred to the second storage section 20 through the steam line 60 '.

As a result, the LNG transfer system (1, 1 ') according to the present invention not only reduces the occurrence of BOG through the subcooled LNG during LNG transfer, but also re-liquefies BOG and NBOG generated during LNG transfer, Can be effectively reduced. Also, by operating the LNG stored in the storage unit, the operation cost can be reduced, and the LNG transporting system can be stably maintained by maintaining the temperature and the pressure of the loading unit constant by periodically or selectively injecting the undercooled LNG .

While the present invention has been particularly shown and described with reference to exemplary embodiments thereof, it is to be understood that the invention is not limited to the disclosed exemplary embodiments. It will be understood that various modifications and changes may be made without departing from the scope of the appended claims.

1, 1 ': LNG transport system 10: First storage unit
11, 21: manifold 20: second storage section
30: Loading device 32: Container
40: main line 50, 50 ': steam return line
60, 60 ': steam line 70: cooling device
71: Subcooled fluid supply line 74: Spray line
75: Sprayer 80: Fluid return line

Claims (8)

In a liquefied natural gas (LNG) delivery system,
A main line for transferring the liquefied natural gas from the first storage unit where the liquefied natural gas is stored to an external second storage unit;
A loading device having a container surrounding the main line and having a predetermined space formed therein;
A cooling device for subcooling a portion of the liquefied natural gas stored in the first storage section and providing the part to the container; And
And a vapor return line for supplying vaporized natural gas (BOG) generated from the liquefied natural gas transferred to the second storage unit to the container,
Wherein the vaporized natural gas injected through the steam return line is re-liquefied by the sub-cooled liquefied natural gas provided in the container. The method according to claim 1,
Wherein the steam return line is connected to the first reservoir through the container. The method according to claim 1,
Further comprising a vapor line providing natural convection gas (NBOG) occurring naturally in said first reservoir to said container. The method of claim 3,
Wherein the natural vapor gas injected through the steam line is re-liquefied by the sub-cooled liquefied natural gas provided in the container. The method of claim 3,
Wherein the steam line passes through the container and is connected to the second reservoir. The method according to claim 1,
Wherein the cooling device comprises a subcooling fluid supply line for providing subcooled liquefied fuel gas to the container and a spray line for selectively providing subcooled liquefied fuel gas. The method according to claim 6,
Wherein the temperature and pressure inside the container are measured and the superheated liquefied fuel gas is sprayed through the spray line to maintain the temperature and pressure in the container when the measured temperature and pressure are lower than a predetermined reference value. The method according to claim 1,
Further comprising a fluid return line that allows the subcooled liquefied fuel gas provided in the container to selectively flow into the first reservoir.
KR1020170086289A 2017-07-07 2017-07-07 LNG transfer system KR101864150B1 (en)

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Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
KR20190135669A (en) * 2018-05-29 2019-12-09 주식회사 엔케이 Reliquefaction system of boil off gas and reliquefaction method of boil off gas using the same
KR20200046532A (en) * 2018-10-24 2020-05-07 주식회사 엔케이 Reliquefaction system of boil off gas comprising single mixed refrigerant and reliquefaction method of boil off gas using the same

Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
KR20150020964A (en) * 2013-08-19 2015-02-27 대우조선해양 주식회사 LNG Offloading System And Method For FLNG
KR20150093003A (en) * 2014-02-06 2015-08-17 현대중공업 주식회사 A Treatment System Of Liquefied Gas
KR20160139312A (en) * 2015-05-27 2016-12-07 대우조선해양 주식회사 LNG Offloading System And Method For FLNG
KR20160141394A (en) * 2015-05-22 2016-12-09 삼성중공업 주식회사 Fuel gas supplying system in ships

Patent Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
KR20150020964A (en) * 2013-08-19 2015-02-27 대우조선해양 주식회사 LNG Offloading System And Method For FLNG
KR20150093003A (en) * 2014-02-06 2015-08-17 현대중공업 주식회사 A Treatment System Of Liquefied Gas
KR20160141394A (en) * 2015-05-22 2016-12-09 삼성중공업 주식회사 Fuel gas supplying system in ships
KR20160139312A (en) * 2015-05-27 2016-12-07 대우조선해양 주식회사 LNG Offloading System And Method For FLNG

Cited By (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
KR20190135669A (en) * 2018-05-29 2019-12-09 주식회사 엔케이 Reliquefaction system of boil off gas and reliquefaction method of boil off gas using the same
KR102096902B1 (en) * 2018-05-29 2020-05-27 주식회사 엔케이 Reliquefaction system of boil off gas and reliquefaction method of boil off gas using the same
KR20200046532A (en) * 2018-10-24 2020-05-07 주식회사 엔케이 Reliquefaction system of boil off gas comprising single mixed refrigerant and reliquefaction method of boil off gas using the same
KR102137384B1 (en) * 2018-10-24 2020-08-13 주식회사 엔케이 Reliquefaction system of boil off gas comprising single mixed refrigerant and reliquefaction method of boil off gas using the same

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