KR101609624B1 - Storage tank of liquefied natural gas - Google Patents
Storage tank of liquefied natural gas Download PDFInfo
- Publication number
- KR101609624B1 KR101609624B1 KR1020140030373A KR20140030373A KR101609624B1 KR 101609624 B1 KR101609624 B1 KR 101609624B1 KR 1020140030373 A KR1020140030373 A KR 1020140030373A KR 20140030373 A KR20140030373 A KR 20140030373A KR 101609624 B1 KR101609624 B1 KR 101609624B1
- Authority
- KR
- South Korea
- Prior art keywords
- lng
- temperature
- pipe
- storage tank
- pump
- Prior art date
Links
Images
Landscapes
- Filling Or Discharging Of Gas Storage Vessels (AREA)
Abstract
A liquefied natural gas storage tank capable of suppressing pressure rise due to evaporation gas is provided. A liquefied natural gas (LNG) storage tank comprises: a tank body for storing LNG; An LNG injecting part connected to a pump for pumping LNG by a connecting pipe and having a first nozzle for injecting LNG into an evaporation gas area in an upper portion of the tank main body; And an LNG circulation unit connected to the branch pipe and having a second nozzle positioned below the LNG to circulate the LNG through the connection pipe and the branch pipe.
Description
The present invention relates to a liquefied natural gas storage tank of a liquefied natural gas carrier, and more particularly to a liquefied natural gas storage tank capable of suppressing a pressure rise due to evaporative gas.
In general, natural gas is liquefied at extremely low temperatures in drilling facilities and becomes liquefied natural gas (hereinafter referred to as "LNG"), which is transported to the destination in the LNG storage tank of the carrier. LNG storage tanks are usually constructed with double insulation structure, but LNG is vaporized by boiling-off gas due to constantly shaking marine environment and heat input from the outside. Evaporation gas is a risk factor for increasing the pressure of the LNG storage tank.
A method of restricting the pressure rise of the LNG storage tank due to the evaporation gas, a method of re-liquefying the evaporated gas and returning it to the LNG storage tank, and a method of restricting the evaporation gas in the LNG storage tank to 200 And a method of maintaining the high pressure of about atmospheric pressure or less to suppress further generation of evaporative gas in the LNG storage tank.
However, the first method requires a complicated liquefaction facility and consumes a lot of power for liquefaction of evaporation gas. The second method is to increase the LNG storage tank to a considerably large thickness in order to accommodate the high-pressure evaporation gas at about 200 atmospheres. Therefore, the manufacturing cost of the LNG storage tank is increased and additional devices such as a high- need.
The present invention provides a LNG storage tank capable of suppressing an increase in the pressure of the LNG storage tank by slowing the generation rate of the evaporation gas by a simple device configuration and a control method.
A liquefied natural gas (LNG) storage tank according to an embodiment of the present invention includes a tank main body for storing LNG; An LNG injecting part connected to a pump for pumping LNG by a connecting pipe and having a first nozzle for injecting LNG into an evaporation gas area in an upper portion of the tank main body; And an LNG circulation unit connected to the branch pipe and having a second nozzle positioned below the LNG to circulate the LNG through the connection pipe and the branch pipe.
The LNG circulation section can operate when the pressure in the tank body is equal to or higher than the set pressure. When the temperature in the tank body reaches the saturation temperature, the LNG injection part can operate.
The connecting pipe can be located inside and outside the tank body, and the branch pipe can be located inside the tank body. The connection pipe may be divided into a front end connected to the pump with respect to one point and a rear end connected with the first nozzle, and a portion of the front end may be located outside the tank main body.
The LNG injection unit may include a first control valve provided at the front end portion and a second control valve provided at the rear end portion. The LNG circulation portion may include a third control valve installed in the branch pipe.
The LNG storage tank includes: a temperature sensor for measuring the LNG temperature inside the front end; The control unit may further include a control unit that receives a measurement signal from the temperature sensor and is electrically connected to the first to third control valves to control operations of the first to third control valves. The temperature sensor is installed close to the branch in the front end and can measure the LNG temperature immediately before entering the branch from the front end.
The LNG circulation part may operate before the LNG injection part operates to cool the connection pipe, and the LNG injection part may operate when the temperature of the LNG flowing through the connection pipe reaches the saturation temperature to inject the LNG into the evaporation gas area.
According to this embodiment, the temperature of the evaporation gas region can be lowered by spraying low-temperature LNG in the evaporation gas region, which is relatively higher in temperature than the LNG, so that the generation rate of the evaporation gas can be reduced. Also, by operating the LNG circulation unit before the LNG injection unit is operated to cool the connection pipe, it is possible to prevent an abrupt pressure increase that may occur at the beginning of operation of the LNG injection unit.
1 is a schematic view of a liquefied natural gas storage tank according to one embodiment of the present invention.
FIG. 2 is a flowchart showing a method of suppressing evaporation gas according to an embodiment of the present invention.
Hereinafter, exemplary embodiments of the present invention will be described in detail with reference to the accompanying drawings, which will be readily apparent to those skilled in the art to which the present invention pertains. The present invention may be embodied in many different forms and is not limited to the embodiments described herein.
1 is a schematic view of a liquefied natural gas storage tank according to one embodiment of the present invention.
Referring to FIG. 1, a liquefied natural gas (hereinafter referred to as LNG)
The
In the case of the LNG carrier, the evaporative gas of the
The
The
The
The
The
A part of the connecting
The
The
The
The
The
FIG. 2 is a flowchart showing a method of suppressing evaporation gas according to an embodiment of the present invention.
1 and 2, the method for suppressing evaporation gas includes a first step (S10) of measuring the pressure of the tank
In the first step S10, the
In the second step S20, when the pressure of the tank
The LNG pumped by the
In the third step S30, the
During the initial operation of the
In the fourth step S40, when the sensed temperature of the LNG reaches the saturation temperature of the LNG, the
As described above, in the method of suppressing the evaporation gas according to the present embodiment, a predetermined amount of LNG is initially circulated without injecting the pumped LNG directly into the evaporation gas region A10, thereby reaching the saturation temperature of the LNG, It is possible to effectively suppress the rapid pressure rise that may occur at the beginning of the operation of the
While the present invention has been described in connection with what is presently considered to be practical exemplary embodiments, it is to be understood that the invention is not limited to the disclosed embodiments, but, on the contrary, Of course.
100: LNG storage tank 10: tank body
A10: Evaporation gas area 20: LNG distributing part
21: pump 22: first nozzle
23:
30: LNG circulation part 31: Branch engine
32: second nozzle 33: third control valve
41: Temperature sensor 42: Pressure sensor
50:
Claims (9)
A pump for pumping LNG; a first nozzle for injecting the LNG pumped from the pump into an evaporation gas area above the LNG; and a connection unit for connecting the pump and the first nozzle, An LNG injection part having a pipe; And
A branch pipe branching toward the LNG from one point of a portion of the connection pipe that contacts the first nozzle in the tank main body and the whole branch is located inside the tank main body; And an LNG circulation unit for circulating the LNG pumped by the pump through the connection pipe and the branch pipe,
The LNG circulation unit operates before the operation of the LNG injection unit to cool a portion of the connection pipe located outside the tank body,
Wherein the LNG injection unit operates when the temperature of the LNG flowing through the connection pipe reaches a saturation temperature to inject LNG into the evaporation gas area.
Wherein the LNG circulation section operates when the pressure in the tank body is equal to or higher than a set pressure.
And an LNG storage tank in which the LNG injection unit operates when the temperature in the tank body reaches a saturation temperature.
The connection pipe is divided into a front end connected to the pump and a rear end connected to the first nozzle with respect to the one point,
And a part of the front end portion is located outside the tank body.
Wherein the LNG injector includes a first control valve installed at the front end and a second control valve installed at the rear end,
And the LNG circulation unit includes a third control valve installed in the branch pipe.
A temperature sensor for measuring the LNG temperature inside the front end; And
Further comprising a control unit that is provided with a measurement signal from the temperature sensor and is electrically connected to the first to third control valves to control operations of the first to third control valves.
Wherein the temperature sensor measures a temperature of the LNG immediately before the branch pipe is introduced into the branch pipe from the front end of the LNG storage tank.
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
KR1020140030373A KR101609624B1 (en) | 2014-03-14 | 2014-03-14 | Storage tank of liquefied natural gas |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
KR1020140030373A KR101609624B1 (en) | 2014-03-14 | 2014-03-14 | Storage tank of liquefied natural gas |
Publications (2)
Publication Number | Publication Date |
---|---|
KR20150107984A KR20150107984A (en) | 2015-09-24 |
KR101609624B1 true KR101609624B1 (en) | 2016-04-07 |
Family
ID=54246129
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
KR1020140030373A KR101609624B1 (en) | 2014-03-14 | 2014-03-14 | Storage tank of liquefied natural gas |
Country Status (1)
Country | Link |
---|---|
KR (1) | KR101609624B1 (en) |
Families Citing this family (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
JP7050987B1 (en) * | 2020-10-30 | 2022-04-08 | 三菱造船株式会社 | Floating body |
Citations (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
KR100814593B1 (en) | 2007-03-21 | 2008-03-17 | 대우조선해양 주식회사 | Method for decreasing generation of boil-off gas within lng storage tank |
-
2014
- 2014-03-14 KR KR1020140030373A patent/KR101609624B1/en active IP Right Grant
Patent Citations (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
KR100814593B1 (en) | 2007-03-21 | 2008-03-17 | 대우조선해양 주식회사 | Method for decreasing generation of boil-off gas within lng storage tank |
Also Published As
Publication number | Publication date |
---|---|
KR20150107984A (en) | 2015-09-24 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
KR101122549B1 (en) | Boil off gas control apparatus of lng carriers | |
KR101026180B1 (en) | Boil off gas control apparatus of lng carriers | |
KR102189715B1 (en) | Fuel supply system | |
KR101609624B1 (en) | Storage tank of liquefied natural gas | |
KR20150011674A (en) | Bog processing system of lng ship | |
KR102015582B1 (en) | Combustion apparatus using direct injection for lpg | |
CN103827570B (en) | Heat the method for cryogenic liquide again | |
KR102303751B1 (en) | Ship | |
KR20130064194A (en) | System for maintenance liquefied natural gas and liquefied petroleum gas storage tank for ship | |
KR20120119645A (en) | System for protecting pipe | |
KR101205972B1 (en) | Lng supplying system | |
KR100716323B1 (en) | Icing preventing apparatus for an lpi injector | |
KR20120054395A (en) | Tensioner for using low temperature | |
KR20130034702A (en) | Loading and unloading method of lng | |
JP2018204721A (en) | Gas release system | |
KR102027266B1 (en) | Fuel tank and ship comprising the fuel tank | |
KR101508628B1 (en) | Boil off gas control apparatus of lng carriers | |
JP5175595B2 (en) | Cooling device and superconducting device | |
KR20150112673A (en) | Liquid oxygen tank management system for submarine and management method thereof | |
KR101691983B1 (en) | Recovery system for superconducting fault current limiter | |
KR100877254B1 (en) | A boil off gas control apparatus | |
JP7142125B1 (en) | Liquefied gas storage facilities and ships | |
KR20230058246A (en) | Liquefied gas loading and gas treatment system, and method thereof | |
KR20190059547A (en) | Liquified gas carrier and method thereof | |
KR101521611B1 (en) | Heating system of coffer dam in ship |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
A201 | Request for examination | ||
E902 | Notification of reason for refusal | ||
AMND | Amendment | ||
E601 | Decision to refuse application | ||
AMND | Amendment | ||
X701 | Decision to grant (after re-examination) |