KR101246051B1

KR101246051B1 - Lng regasification system

Info

Publication number: KR101246051B1
Application number: KR1020100111932A
Authority: KR
Inventors: 김승혁; 엄영철
Original assignee: 삼성중공업 주식회사
Priority date: 2010-11-11
Filing date: 2010-11-11
Publication date: 2013-03-26
Also published as: KR20120050598A

Abstract

A liquefied natural gas regasification apparatus is disclosed.
According to an embodiment of the present invention, a regasification line for providing a moving path for regasification of liquefied natural gas, and a steam condensation water circulation line installed in the regasification line for circulating and supplying high temperature high pressure steam or high temperature high pressure condensate; A steam vaporizer for vaporizing the liquefied natural gas into a vaporized natural gas by the high temperature and high pressure steam, and a natural gas heater for heating the vaporized natural gas by the high temperature and high pressure condensed water discharged from the steam vaporizer.

Description

LNG Regasification System {LNG REGASIFICATION SYSTEM}

The present invention relates to a liquefied natural gas regasification apparatus for directly regasifying liquefied natural gas in ships and offshore structures.

Recently, LNG carriers for delivering liquefied natural gas (hereinafter referred to as 'LNG') are equipped with a separate regasification system to supply natural gas to consumers at sea. In addition to forms, structures that are constructed to carry out the same role by mounting a regasification system on top of offshore structures are also emerging.

The regasification system mounted on such a ship or offshore structure may use various facilities for vaporizing LNG using seawater or other fruits, depending on the method of vaporizing LNG.

In the conventional regasification system, the direct vaporization method using the fruit was mainly applied, but indirect vaporization method using the fruit is recently used due to environmental regulations. As a fruit, an antifreeze such as propane or glycol may be used, and is used in the form of a mixed refrigerant.

For example, the regasification facility of the ship according to the prior art, as shown in Figure 1, the transport pipe of the liquefied natural gas (2) connecting between the storage tank (1) of the liquefied natural gas carrier ship and the land terminal (3) Have

Conventional vessel regasification facility is equipped with a first pump (4) which is mounted to the transport pipe (2) to draw the liquefied natural gas from the storage tank (1), and is mounted to the transport pipe (2) to primary liquefied natural gas It has a 1st heating part 10 to heat, the 2nd heating part 20 attached to the transport pipe 2, and the secondary heating of liquefied natural gas, and the boiler 30 for steam generation.

Here, the first heating unit 10 is a heat transfer fluid or ethylene glycol (Ethylene Glycol), a closed loop pipe 14, a second pump 116, a closed loop pipe 14 and the boiler A first heat exchanger 18 mounted at the cross section of the steam pipe 22 of the steam pipe 22, and a second heat exchanger in the form of a vaporizer installed at the cross section of the closed loop pipe 14 and the transport pipe 2 ( 12).

In addition, the second heating unit 20 is installed in the cross section of the steam pipe 22 and the transport pipe 2 of the boiler 30, the liquefied natural gas and the first heat exchanger passing through the first heating unit 10. And a third heat exchanger (24) for causing heat exchange between the condensation steam passing through (18).

Here, the first heating unit 10 may be understood as an indirect vaporization method in which the heat of steam is transferred to the liquefied natural gas via a fruit or heating fluid, and the second heating unit 20 is a condensation steam. The heat of may be understood as a direct vaporization method in which the liquefied natural gas passing through the first heating unit 10, that is, the vaporized natural gas is transferred.

However, conventionally, the system for realizing the regasification by the direct vaporization method after the indirect vaporization method has a heat loss compared to the system using only the direct vaporization method in terms of thermal efficiency.

In general, in the case of the heat exchanger, when the indirect method is applied at an efficiency of about 80 to 90%, there is a heat loss as the number of heat exchangers for transferring energy increases, and there is also a heat loss in the heating medium piping.

On the other hand, when the vaporizer is configured using steam is configured to use only the latent heat of steam due to the problem of internal freezing. That is, since the temperature of the liquefied natural gas is very low in the steam vaporizer, when condensation steam or condensate is stagnated in the heat exchanger region of the steam vaporizer, freezing may occur in the steam vaporizer.

In this case, when the low pressure steam is applied, there is no large loss because the sensible heat of the condensed water by the low pressure steam is small, but if the high temperature and high pressure steam is applied to the conventional vaporizer without any measures to reduce the size of the steam pipe or increase the capacity of the vaporizer, This loss of sensible heat can only be greater.

In addition, if a separate cooling device is used to reduce the temperature of the superheated condensate in order to smoothly discharge the superheated condensate that may be generated after the steam is used for vaporization, it is complicated to prevent re-evaporation when recovering the condensate to the boiler. Facility structural problems may arise, such as requiring equipment.

That is, the temperature of the natural gas vaporized by steam should be designed to always have the temperature of the image to prevent freezing problems inside the vaporizer. In addition, if the amount of vaporized natural gas has a designed flow rate, it will have a temperature at the design level, but if the flow rate becomes small, the temperature of the vaporized natural gas may be overheated to a temperature higher than the design.

This high temperature natural gas is then heat exchanged with the condensation steam, as in the prior art mentioned above, resulting in a higher temperature than necessary, resulting in difficulty in temperature control and unnecessary energy consumption.

If a device such as a heat exchanger using separate cooling water, for example, seawater is used to solve this problem, unnecessary energy consumption and environmental pollution may occur due to high temperature seawater discharge.

Embodiment of the present invention, when the high temperature and high pressure condensate is used for re-gasification by direct vaporization method, the efficient control of the temperature of the vaporized natural gas, the use of high temperature and high pressure condensate and temperature control, smooth condensate recovery by ship and offshore structure It is intended to realize the regasification of liquefied natural gas suitable for.

According to an aspect of the present invention, a regasification line for providing a moving path for regasification of liquefied natural gas, and a steam condensation water circulation line installed in the regasification line for circulating and supplying high temperature high pressure steam or high temperature high pressure condensate; Liquefied natural gas including a steam vaporizer for vaporizing the liquefied natural gas into a vaporized natural gas by the high temperature and high pressure steam, and a natural gas heater for heating the vaporized natural gas by the high temperature and high pressure condensed water discharged from the steam vaporizer. A regasification device may be provided.

In addition, the present embodiment may include a mixing temperature control unit installed between the steam vaporizer and the natural gas heater to receive the liquefied natural gas bypassed from the regasification line.

The mixing temperature control unit may include a bypass pipe member branched from the regasification line, a mixer to which the bypass pipe member is coupled, and the bypass pipe member to control the flow of liquefied natural gas in the bypass pipe member. It may include a control valve coupled to.

The mixer may further include a case part having a connection part to which the bypass pipe member is connected, a baffle structure geometrically intersecting in the case part, an inlet part and an outlet part formed to penetrate the regasification line. It may include wealth.

In addition, the present embodiment may further include a liquefied natural gas buffer tank installed in the regasification line between the liquefied natural gas cargo hold and the high pressure pump.

In addition, the present embodiment may further include a high temperature condensed water level control tank installed in the steam condensed water circulation line between the steam vaporizer and the natural gas heater.

In addition, the present embodiment may further include a low temperature condensate treatment unit installed in the steam condensate circulation line between the natural gas heater and the boiler.

The low temperature condensate treatment unit may include a low temperature condensate pump installed in the steam condensate circulation line and a low temperature condensate pump coupled to the steam condensation circulation line to suck the low temperature condensate from the low temperature condensate tank and supply the condensate to the boiler. .

Embodiment of the present invention by using the high-temperature high-pressure steam or high-temperature high-pressure condensate in the direct vaporization method, solve the problem of heat exchanger loss, heat loss of the heating medium pipe and sensible heat loss of steam in the indirect vaporization method, regasification of LNG The thermal efficiency can be improved.

Since the embodiment of the present invention can reduce the size of the device facility by using a direct vaporization method, it is possible to increase the utilization of the device installation space in the vessel.

Embodiment of the present invention is mixed with the liquefied natural gas to the first vaporized natural gas to make a mixed natural gas, and the condensed water recovery smoothly by treating the temperature of the high temperature and high pressure condensate through heat exchange between the mixed natural gas and high temperature high pressure condensate Can be done.

An embodiment of the present invention is to use the mixing temperature control unit or natural gas heater, without using sea water when excessive temperature change occurs in accordance with the use of steam or high temperature and high pressure condensate, to re-liquefy liquefied natural gas There is an effect that can prevent the destruction of marine ecosystems and environmental pollution by the use of inflow or outflow of external seawater into the ship.

1 is a block diagram of a vessel regasification plant according to the prior art.
2 is a block diagram of a liquefied natural gas regasification apparatus according to an embodiment of the present invention.
3 is a configuration diagram of the steam vaporizer shown in FIG.
Figure 4 is a block diagram of the mixing temperature control unit shown in FIG.
5 is a block diagram showing another embodiment of the present invention.

Hereinafter, embodiments of the present invention will be described in detail with reference to the accompanying drawings. In the following description of the present invention, detailed description of known functions and configurations incorporated herein will be omitted when it may make the subject matter of the present invention rather unclear.

2 is a block diagram of a liquefied natural gas regasification apparatus according to an embodiment of the present invention.

2, the present embodiment may be applied to a ship or an offshore structure.

As used herein, the term "ship" is not limited to meaning a structure that sails aquatic waters, but is used to include not only structures that sail aquatic waters, but also marine structures, such as FLNG, which float and perform operations in aquatic waters. . The ship of the present embodiment may be, for example, LNGC or FLNG, but the present invention is not limited thereto.

This embodiment may include a regasification line 102, steam condensation water circulation line 202, boiler 200, steam vaporizer 300, mixing temperature control unit 400, natural gas heater 500. .

Regasification line 102 may be configured to provide a movement path for the regasification of liquefied natural gas.

For example, the regasification line 102 may be connected to be installed between the LNG cargo hold 100 and the land terminal 90 or other demand destination.

In addition, the liquefied natural gas buffer tank 104 may be installed between the liquefied natural gas cargo hold 100 and the high pressure pump 105 coupled to the regasification line (102).

In addition, the regasification line 102 is a liquefied natural gas transfer pipe member, a pipe member connecting member, various liquefied natural gas detection sensor members (e.g. temperature sensor, flow sensor, pressure sensor), and normal liquefaction It may be configured to include a natural gas transfer control means (for example, a controller for controlling the operation of the pump, etc. based on the sensor input value).

The steam condensation water circulation line 202 may be installed in the regasification line 102 and configured to circulate and supply the high temperature high pressure steam (HS) or the high temperature high pressure condensate (SC) or the low temperature condensate (W).

For example, the steam condensation water circulation line 202 is a loop structure that circulates through an intersection section or an intersection point of the regasification line 102, and is withdrawn from the steam outlet of one side of the boiler 200 and circulated, and then the other side of the boiler 200. It can be coupled to the cold condensate inlet.

To this end, the steam condensation water circulation line 202 is a high temperature high pressure steam (HS) or high temperature high pressure condensate (SC) or low temperature condensate (W) pipe member for transport, a member for connecting the pipe member, a sensor member (for example, a temperature sensor , Flow sensor, pressure sensor, gas detection sensor), and conventional fluid supply control means (not shown).

Since the steam condensation water circulation line 202 uses a high-pressure environment pipe member and a pipe member connection member having a pressure of 16 bar or more, it is reduced to about 35% (cross-sectional basis) compared to the conventional general pressure 5 bar low pressure environment pipe member size. Can be formed.

The boiler 200 may generate a high temperature high pressure steam (HS) having a pressure of about 16 to 20 bar and a temperature of about 200 to 250 ° C., and may be configured as a facility capable of recovering and recycling the low temperature condensed water (W).

The steam vaporizer 300 is configured to realize a vaporization method in which heat exchange between liquefied natural gas and high temperature high pressure steam (HS) is performed, and serves to vaporize liquefied natural gas into primary vaporized natural gas by high temperature and high pressure steam (HS). Can be in charge of

To this end, the steam vaporizer 300 may be mounted at the first intersection between the regasification line 102 and the steam condensation water circulation line 202.

The mixing temperature controller 400 receives the liquefied natural gas bypassed from the regasification line 102 between the steam vaporizer 300 and the natural gas heater 500, and as a result, to make the mixed natural gas. It may be installed in the regasification line 102.

The natural gas heater 500 may be configured to realize a vaporization method in which heat exchange is performed between the mixed natural gas and the high temperature and high pressure condensate (SC). That is, the natural gas heater 500 heats the mixed natural gas leaving the mixer 410 of the mixing temperature control unit 400 with the high temperature and high pressure condensed water (SC) discharged from the steam vaporizer 300, and then vaporizes the secondary gas. At the same time to create the natural gas can be cooled to convert the high temperature and high pressure condensate (SC) to low temperature condensate (W).

To this end, the natural gas heater 500 may be mounted at a second intersection point where the regasification line 102 and the steam condensation water circulation line 202 meet again.

In addition, the natural gas heater 500 includes a well-known heat exchanger configuration, such as countercurrent exchange, to perform heat exchange between the mixed natural gas and the high temperature and high pressure condensate (SC).

3 is a general configuration diagram of the steam vaporizer shown in FIG.

3 exemplarily illustrated in the present embodiment, the general shell and tube heat exchanger is illustrated, but other types of heat exchangers may also be applied, and thus may not be limited thereto.

Referring to FIG. 3, in order to prevent freezing that may occur when the high temperature and high pressure condensate (SC) stays or stagnates in the steam vaporizer 300, the steam vaporizer 300 of the present embodiment immediately changes the high temperature and high pressure condensate (SC). It is configured to discharge immediately out of the steam vaporizer (300).

For example, the steam vaporizer 300 is installed inside the LNG steam heat exchange chamber 310 and recovers the LNG steam heat exchange chamber 310 for realizing direct heat transfer between liquefied natural gas and high temperature high pressure steam (HS). Steam inlet 330 for connecting the supply pipe of the steam condensed water circulation line 202 to one side of the LNG steam heat exchange chamber 310 and the U-shaped heat transfer pipe member 320 connected to the fire line 102. And, the other side of the LNG steam heat exchange chamber 310 may include a high temperature and high pressure condensation outlet 340 for connecting the discharge side pipe of the steam condensation water circulation line 202.

The high temperature high pressure steam (HS) supplied from the boiler 200 is converted into high temperature condensed water (SC) after heat exchange with liquefied natural gas in the steam vaporizer 300, and then the natural gas through the high temperature high pressure condensation export unit 340 It may be fed towards the heater 500.

Figure 4 is a block diagram of the mixing temperature control unit shown in FIG.

Referring to FIG. 4, the mixing temperature controller 400 may include a bypass pipe member 420 branched from the regasification line 102 (see FIG. 3 in parallel), and a mixer to which the bypass pipe member 420 is coupled ( 410 and a control valve 430 coupled to the bypass pipe member 420 to control the flow of liquefied natural gas in the bypass pipe member 420.

Here, the mixer 410 uses the baffle structure 413 inside the case part 412, and naturally mixes the primary vaporized natural gas and the liquefied natural gas, thereby controlling the temperature of the primary vaporized natural gas. can do.

To this end, the mixer 410 may include a case part 412 having a connection part 411 to which the bypass pipe member 420 is connected, a baffle structure 413 geometrically intersecting the inside of the case part 412, and It may include an inlet 414 and an outlet 415 formed in the case portion 412 so as to penetrate the regasification line 102.

Here, the baffle structure 413 may have a shape for stirring the fluid inside the static mixer. For example, the baffle structure 413 may be formed in various shapes such as spiral and wire shapes, and any shape capable of mixing primary vaporized natural gas and liquid natural gas may be used, and thus the shape itself is not limited thereto. Can be.

In addition, one side of the connection portion 411 of the mixer 410 may be formed with a screw for coupling the bypass pipe member 420 to the connection hole of the case portion 412.

In addition, an outlet or a nozzle through which the liquefied natural gas bypassed may be formed at the other side of the connection part 411 of the mixer 410.

Hereinafter, the operation of the liquefied natural gas regasification apparatus of the present invention will be described.

2 to 4, according to the present embodiment, the liquefied natural gas stored in the liquefied natural gas cargo hold 100 is a liquefied natural gas buffer on the regasification line 102 by an unloading pump 103 which is a low pressure pump. It may be fed towards the tank 104.

The liquefied natural gas of the liquefied natural gas buffer tank 104 may be pressurized to 100 bar or more by the high pressure pump 105 and flow into the steam vaporizer 300 along the regasification line 102.

Meanwhile, the high temperature high pressure steam (HS) generated from the boiler 200 (eg, a pressure of 16 bar and a temperature of 200 ° C.) may also flow into the steam vaporizer 300 along the steam condensation water circulation line 202.

In the steam vaporizer 300, the heat exchange between the liquefied natural gas and the high temperature and high pressure steam (HS) can be made.

Accordingly, the high temperature and high pressure steam (HS) may be the high temperature and high pressure condensate (SC) while passing through the steam vaporizer 300, and the liquefied natural gas may be the primary vaporized natural gas while passing through the steam vaporizer (300). .

Here, since the temperature of the primary vaporized natural gas may have a temperature value of about 5 ~ 20 ℃, the temperature is not maintained below zero in the steam vaporizer 300 can be solved the existing freezing problem.

In addition, since the high temperature and high pressure condensate (SC) immediately exits from the steam vaporizer 300, theoretically, only latent heat of the high temperature and high pressure steam (HS) may be used in the steam vaporizer 300, and eventually high temperature and high pressure steam (HS). ), And the temperature difference between the high temperature and high pressure condensate (SC) hardly occurs and maintains the temperature value close to 200 ° C.

Thus, condensate cooling is necessarily required in order to circulate back to the boiler 200 because the temperature of the high temperature and high pressure condensate (SC) is very high.

That is, when circulating toward the boiler 200 without adjusting the temperature of the high temperature and high pressure condensate (SC), the temperature of the high temperature and high pressure condensate (SC) is too high, the re-evaporation phenomenon is made in the steam condensed water circulation line (202) As a result, smooth condensate recovery or drainage may be difficult.

In order to control the temperature of the high temperature and high pressure condensate (SC) and to increase the regasification efficiency, the primary vaporized natural gas having a temperature value of about 5 to 20 ° C. via the steam vaporizer 300 is a mixed temperature controller 400. ) Into the mixer 410.

When the valve operation of the control valve 430 is controlled, the liquefied natural gas may flow into the mixer 410 of the mixing temperature controller 400 through the bypass pipe member 420.

The mixer 410 mixes liquefied natural gas and primary vaporized natural gas to reduce the temperature of the primary vaporized natural gas.

In the interior of the mixer 410, a mixed natural gas having a liquefied natural gas and a primary vaporized natural gas having a supercritical fluid characteristic may be formed by the baffle structure 413 that is geometrically intersected.

The mixed natural gas may have a low temperature value between −30 and −5 ° C. while leaving the mixer 410.

This mixed natural gas flows along the regasification line 102 between the mixer 410 and the natural gas heater 500, and then flows into the natural gas heater 500.

In addition, the high temperature and high pressure condensed water (SC) close to 200 ° C. or less exiting the steam vaporizer 300 also flows along the steam condensed water circulation line 202 and then flows into the natural gas heater 500.

In the natural gas heater 500, heat exchange between the mixed natural gas and the high temperature and high pressure condensate (SC) may be performed.

At this time, the natural gas heater 500 may reduce the temperature of the high temperature and high pressure condensed water (SC) with the mixed natural gas having a low temperature value, thereby generating low temperature condensed water (W) of 100 ° C or less.

In addition, the mixed natural gas of a low temperature value may be a secondary vaporized natural gas having a temperature value of about 0 ~ 20 ℃ through heat exchange with the high temperature and high pressure condensate (SC).

As such, the present embodiment is adjusted to a temperature suitable for condensate recovery (eg, 100 ° C. or less) and a regasification titration temperature (eg, 0 to 20 ° C.), so that the high temperature high pressure steam (HS) or the high temperature high pressure condensate (SC) Energy consumption can be prevented more than necessary to control the excessive temperature change caused by the application.

In addition, as the steam condensation water circulation line 202 is provided with a gas detection sensor (not shown), a leak occurs in the steam vaporizer 300 and the natural gas heater 500 so that the steam condensation water circulation line 202 is provided. When the gas flows into the boiler 200 can be prevented through, general leakage alarm means for this, safety valves for suppressing the liquefied natural gas movement according to the leakage may be further provided.

5 is a block diagram showing another embodiment of the present invention.

Referring to FIG. 5, the steam condensation water circulation line 202 may further include a high temperature condensate water level control tank 600 between the steam vaporizer 300 and the natural gas heater 500.

The high temperature condensate water level control tank 600 serves as a buffer for stably supplying the high temperature and high pressure condensate (SC) generated when the high temperature high pressure steam (HS) is directly heat-exchanged with liquefied natural gas in the steam condensation water circulation line (202). I can be in charge.

At this time, the high temperature condensed water level control tank 600 is provided with a normal level control means for preventing backflow (not shown), thereby preventing the high temperature and high pressure condensed water (SC) from flowing into the steam vaporizer 300 by the level control means. The level of condensate in the tank can be controlled.

If, when the water level is increased to the high temperature and high pressure condensate (SC) flows into the steam vaporizer 300, there is a possibility that the freezing problem may occur in the steam vaporizer 300, the high temperature condensate water level control tank 600 Such a phenomenon can be prevented.

In addition, the low temperature condensate treatment unit 700 may be further installed between the natural gas heater 500 and the boiler 200 in the steam condensed water circulation line 202.

Here, the low temperature condensate treatment unit 700 is a steam to suck the low temperature condensate (W) from the low temperature condensate tank 702 and the low temperature condensate tank 702 installed in the steam condensate water circulation line 202 to supply to the boiler 200 side. It may include a low temperature condensate pump 704 coupled to the condensation circulation line 202.

In addition, in this embodiment, in order to facilitate the heat exchange between the liquefied natural gas and the high temperature high pressure steam (HS), or the mixed natural gas and the high temperature high pressure condensate (SC), the low temperature condensed water (W) is a natural gas heater (500) It is very important that the discharge from the) and return to the boiler (200).

In particular, the low temperature condensate (W) is in a state where the temperature and pressure are very far, and the low temperature condensate tank 702 and the distance from the regasification device to the boiler 200 or to prevent the smooth discharge due to the pipe shape Low temperature condensate pump 704 may be used.

Meanwhile, the high temperature condensate water level control tank 600 receives the pressure of the high temperature high pressure steam (HS) supplied through the steam vaporizer 300 and supplies the high temperature high pressure condensed water (SC) toward the natural gas heater 500. A separate pump for pumping the high pressure condensate (SC) toward the natural gas heater 500 may not be used.

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, You will understand. For example, those skilled in the art can change the material, size, etc. of each component according to the application field, or combine or substitute the disclosed embodiments in a form that is not clearly disclosed in the embodiments of the present invention, but this also It does not depart from the scope of the invention. Therefore, it should be understood that the above-described embodiments are to be considered in all respects as illustrative and not restrictive, and that such modified embodiments are included in the technical idea described in the claims of the present invention.

100: LNG natural cargo hold 102: regasification line
103: unloading pump 104: liquefied natural gas buffer tank
105: high pressure pump 200: boiler
202: steam condensate circulation line 300: steam vaporizer
400: mixing temperature control unit 410: mixer
420: bypass pipe member 430: control valve
500: natural gas heater 600: high temperature condensate water level control tank
700: low temperature condensate treatment unit 702: low temperature condensate tank
704: low temperature condensate pump

Claims

A regasification line providing a movement path for regasification of liquefied natural gas,
A steam condensation water circulation line installed in the regasification line for circulating and supplying high temperature high pressure steam or high temperature high pressure condensate;
A steam vaporizer for vaporizing the liquefied natural gas into a vaporized natural gas by the high temperature and high pressure steam;
It includes a natural gas heater for heating the vaporized natural gas by the high temperature and high pressure condensate discharged from the steam vaporizer
LNG Regasification Unit.

The method of claim 1,
It includes a mixing temperature control unit installed between the steam vaporizer and the natural gas heater to receive the liquefied natural gas bypassed from the regasification line
LNG Regasification Unit.

The method of claim 2,
The mixing temperature control unit
A bypass pipe member branched from the regasification line,
A mixer to which the bypass pipe member is coupled;
And a control valve coupled to the bypass pipe member for controlling the flow of liquefied natural gas in the bypass pipe member.
LNG Regasification Unit.

The method of claim 3,
The mixer
A case part having a connection part to which the bypass pipe member is connected;
A baffle structure geometrically intersecting in the case part;
An inlet and an outlet formed in the case to be connected to the regasification line.
LNG Regasification Unit.

The method of claim 1,
Further comprising a LNG buffer tank installed in the regasification line between the LNG cargo hold and the high pressure pump
LNG Regasification Unit.

The method of claim 1,
Further comprising a high temperature condensed water level control tank installed in the steam condensed water circulation line between the steam vaporizer and the natural gas heater.
LNG Regasification Unit.

The method of claim 1,
Further comprising a low temperature condensate treatment unit installed in the steam condensate water circulation line between the natural gas heater and the boiler.
LNG Regasification Unit.

The method of claim 7, wherein
The low temperature condensate treatment unit
A low temperature condensate tank installed in the steam condensate circulation line;
And a low temperature condensate pump coupled to the steam condensation circulation line to suck the low temperature condensate from the low temperature condensate tank and to supply the low temperature condensate to the boiler.
LNG Regasification Unit.