KR102132076B1 - Regasification System of Gas and Ship having the Same - Google Patents

Abstract

A gas regasification system according to an embodiment of the present invention includes a regasification supply line for regasifying liquefied gas and supplying it to a consumer. A heat exchanger provided on the regasification supply line; A first seawater heat exchanger and a second seawater heat exchanger supplying heat medium to the heat exchanger; And a heat source circulation line having the first seawater heat exchanger and the second seawater heat exchanger, wherein the heat source circulation line is branched downstream of the first seawater heat exchanger and connected to the second seawater heat exchanger and the heat exchanger. It is characterized by.

Description

Regasification System of Gas and Ship having the Same

The present invention relates to a gas regasification system and a ship having the same.

As environmental regulations have recently been strengthened, the use of liquefied natural gas, which is close to eco-friendly fuel, is increasing among various fuels. Liquefied natural gas is generally transported through an LNG carrier, where the liquefied natural gas can be stored in a tank of the LNG carrier in a liquid state by lowering the temperature to -162°C or less under 1 atmosphere. When the liquefied natural gas is in a liquid state, its volume is reduced to one-sixth of that of the gas, so transport efficiency can be increased.

However, since liquefied natural gas is generally consumed in a gaseous state rather than in a liquid state, a liquefied natural gas stored and transported in a liquid state needs to be regasified, so a regasification facility is used.

At this time, the regasification facilities are LNG carrier, FLNG. It can be mounted on a ship such as FSRU or provided on land, and the regasification facility implements regasification by heating a liquefied natural gas using a heat source such as seawater.

However, the liquid liquefied natural gas is placed in an extremely low temperature close to -160°C, and a large amount of liquefied natural gas must be re-evaporated, so the space occupied by the regasification equipment is very expensive, and the design is not easy.

Therefore, in recent years, in the process of regasifying the liquefied natural gas stored in the liquid phase, a lot of research and development has been made in the direction of optimizing energy and simplifying the regasification facility while stably operating various components.

KR 10-2016-0120187 A KR 10-2018-0091982 A KR 10-2017-0091491 A

The present invention was created to improve the conventional technology, and an object of the present invention is to provide a gas regasification system capable of reducing the construction cost by reducing the size of the system and optimizing energy, and a ship having the same. .

A gas regasification system according to an embodiment of the present invention includes a regasification supply line for regasifying liquefied gas and supplying it to a consumer. A heat exchanger provided on the regasification supply line; A first seawater heat exchanger and a second seawater heat exchanger supplying heat medium to the heat exchanger; And a heat source circulation line having the first seawater heat exchanger and the second seawater heat exchanger, wherein the heat source circulation line is branched downstream of the first seawater heat exchanger and connected to the second seawater heat exchanger and the heat exchanger. It is characterized by.

Specifically, the second seawater heat exchanger may be configured to process the above-described fluid and have a heat treatment capacity that is less than or equal to the heat treatment capacity of the first seawater heat exchanger that processes a single-phase fluid.

Specifically, the heat exchanger is composed of a first heat exchanger and a second heat exchanger based on the flow of the liquefied gas on the regasification supply line, and the heat source circulation line is branched downstream of the first seawater heat exchanger A first branch line connected to the second seawater heat exchanger; And a second branch line branched downstream of the first sea water heat exchanger to include the second heat exchanger, and a second branch line formed in parallel with the first branch line, wherein the first branch line is the first sea water heat exchange. It may include a pressure-reducing valve to reduce the pressure of the liquid heat medium supplied from the group to convert to at least some gas phase to supply to the second seawater heat exchanger.

Specifically, provided on the heat source circulation line, further comprising a heat source pump for supplying the heat medium to the first seawater heat exchanger, the first branch line and the second branch line, the heat source on the heat source circulation line It can be joined upstream of the pump.

Specifically, on the heat source circulation line further comprises a buffer tank provided between the upstream of the heat source pump and the confluence point of the first branch line and the second branch line to temporarily store the heat medium, wherein the heat source pump comprises: Only the liquid heat medium may be supplied from the buffer tank and supplied to the first seawater heat exchanger.

Specifically, the first seawater heat exchanger can receive and process only the liquid heat medium from the heat source pump, and the second seawater heat exchanger can receive and process the heat medium in which the liquid phase and the gas phase are mixed from the pressure reducing valve.

Specifically, the first branch line may be joined to the second branch line upstream of the buffer tank after passing through the first heat exchanger downstream of the second seawater heat exchanger.

Specifically, the second seawater heat exchanger may be disposed on the upper deck of the ship.

Specifically, the first seawater heat exchanger may be disposed under the upper deck.

Specifically, the first heat exchanger may be a vaporizer, and the second heat exchanger may be a trim heater.

Specifically, a feeding pump provided on the regasification supply line to discharge liquefied gas stored in the liquefied gas storage tank; A temporary storage tank provided downstream of the feeding pump on the regasification supply line and temporarily storing liquefied gas supplied from the feeding pump; And a boosting pump provided between the first heat exchanger and the temporary storage tank on the regasification supply line, and supplying liquefied gas supplied from the temporary storage tank to the first heat exchanger.

Specifically, the heat medium may be a phase change material.

Specifically, the heat medium may be a non-explosive phase change material or propane.

Specifically, it may be a vessel equipped with the gas regasification system.

The gas regasification system according to the present invention has an effect of using a second seawater heat exchanger as a single-phase heat exchanger by constructing a pressure reducing valve after the second seawater heat exchanger provided downstream of the trim heater, thereby causing the second seawater heat exchange There is an effect of reducing the size and cost of the equipment by reducing the size of the group, reducing the cost, and reducing the pipe diameter of the fruit circulation line.

In addition, the gas regasification system according to the present invention, by supplying the fruit to the second seawater heat exchanger and trim heater, which is the branching of the fruit circulation line downstream of the first seawater heat exchanger, which is a single phase disposed downstream of the heat exchange pump, The above has the effect of reducing the heat capacity of the second seawater heat exchanger, thereby reducing the size and cost of the high cost second seawater heat exchanger.

1 is a conceptual diagram of a ship having a gas regasification system according to an embodiment of the present invention.
2 is a conceptual diagram of a gas regasification system according to an embodiment of the present invention.
3 is a conceptual diagram of a gas regasification system according to a first embodiment of the present invention.
4 is a graph showing a phase change in the control valve of the gas regasification system according to the first embodiment of the present invention.
5 is a conceptual diagram of a gas regasification system according to a second embodiment of the present invention.

The objects, specific advantages and novel features of the present invention will become more apparent from the following detailed description and preferred embodiments, which are associated with the accompanying drawings. In addition, it should be noted that, in addition to reference numerals to the components of each drawing in the present specification, the same components have the same numbers as possible, even if they are displayed on different drawings. In addition, in the description of the present invention, when it is determined that detailed descriptions of related known technologies may unnecessarily obscure the subject matter of the present invention, detailed descriptions thereof will be omitted.

Hereinafter, in the present specification, liquefied gas may be used in a sense to encompass all gas fuels that are generally stored in a liquid state, such as LNG or LPG, ethylene, ammonia, and may, for example, mean LNG (Liquefied Natural Gas) , If not in a liquid state by heating or pressurization, it can also be expressed as liquefied gas for convenience. Evaporative gas can be applied as well.

Also, for convenience, LNG can be used to encompass not only NG (Natural Gas) in liquid state, but also NG in supercritical state, and evaporation gas means BOG (Boil Off Gas), which is natural vaporized LNG, and gas state. It can be used in a sense to include not only the evaporation gas of the liquefied evaporation gas.

Liquefied gas can be referred to regardless of state changes such as liquid state, gas state, liquid-gas mixture state, supercooled state, supercritical state, and the like, and it is noted that evaporated gas is also the same. In addition, it is apparent that the present invention is not limited to liquefied gas, and may be a liquefied gas treatment system and/or an evaporated gas treatment system, and the systems of each figure to be described below can be applied to each other.

Hereinafter, preferred embodiments of the present invention will be described in detail with reference to the accompanying drawings.

1 is a conceptual diagram of a ship having a gas regasification system according to an embodiment of the present invention, and FIG. 2 is a conceptual diagram of a gas regasification system according to an embodiment of the present invention.

1 and 2, the vessel 1 having a gas regasification system according to an embodiment of the present invention, a liquefied gas storage tank 10, a regasification device 20, a liquefied gas supply device 30.

The ship 1 equipped with a gas regasification system includes a liquefied gas storage tank 10 inside the hull 1a, and a regasification device 20 and a liquefied gas supply device 30 on the hull 1a Can have

Here, the regasification device 20 accommodates the gas regasification system 2 according to an embodiment of the present invention, and is provided as an example on the upper deck of the bow side, but this is only an example and is also arranged in the center of the bow Can be.

In addition, the liquefied gas supply device 30 processes the liquefied gas stored in the liquefied gas storage tank 10 and supplies it to the propulsion engine E to drive the shaft S to the ship 1 through the propeller P. It is a device for generating a driving force, and for example, may be provided on the upper deck of the hull center side.

The gas regasification system 2 discharges the liquefied gas stored in the liquefied gas storage tank 10 through the feeding pump 21, as shown in FIG. 2, and the discharged liquefied gas to the temporary storage tank 22. After being supplied to the boosting pump 23, the boosting pump 23 is supplied to the heat exchanger 24 in a pressurized state at a pressure required by the demanding destination 40 to regasify and then supplied to the demanding destination 40. .

Hereinafter, each embodiment of the gas regasification system 2 accommodated in the regasification apparatus 20 will be described in detail based on FIGS. 3 and 5.

3 is a conceptual diagram of a gas regasification system according to a first embodiment of the present invention.

As shown in FIG. 3, the gas regasification system 2 according to the first embodiment of the present invention includes a liquefied gas storage tank 10, a feeding pump 21, a temporary storage tank 22, and a boosting pump ( 23), a heat exchanger (24a) and a destination (40).

Hereinafter, a gas regasification system 2 according to an embodiment of the present invention will be described with reference to FIG. 3.

Before describing the individual configurations of the gas treatment system 2 according to the embodiment of the present invention, basic flow paths for organically connecting the individual configurations will be described. Here, the flow path may be a line through which the fluid flows, and is not limited thereto, and may be any structure in which the fluid flows.

In an embodiment of the present invention, a regasification supply line L1, a heat source circulation line L2a, a first seawater supply line L3a, and a second seawater supply line L4a may be further included. Valves capable of adjusting the opening degree (not shown) may be installed in each line, and the amount of evaporation gas or liquefied gas may be controlled according to the opening degree of each valve.

The regasification supply line L1 connects the liquefied gas storage tank 10 and the customer 40 and passes through the boosting pump 23 and the heat exchanger 24, and liquefied gas stored in the liquefied gas storage tank 10 Is processed by the boosting pump 23 and the heat exchanger 24a to be supplied to the demand destination 40.

That is, the regasification supply line L1 regasifies the liquefied gas and supplies it to the demand destination 40.

The heat source circulation line L2a is connected to circulate the first and second heat exchangers 241a and 242a and the first and second seawater heat exchangers 245a and 246a, and the first and second heat exchangers 241a, 242a) and the first and second seawater heat exchangers 245a and 246a, a buffer tank 243a, a heat source pump 244a, and a control valve 247a, wherein the heat medium as a phase change material is the first and second It is formed to circulate the heat exchangers 241a, 242a, the first and second seawater heat exchangers 245a, 246a, the buffer tank 243a, the heat source pump 244a, and the control valve 247a.

Here, the heat source circulation line L2a may supply heat medium to the first and second heat exchangers 241a and 242a.

The first seawater supply line (L3a) is connected to the first seawater heat exchanger (245a) to supply seawater to the first seawater heat exchanger (245a) so that the seawater and the heat medium are exchanged so that the heat source of the seawater can be supplied to the heat medium. have.

The second seawater supply line (L4a) is connected to the second seawater heat exchanger (246a) to supply seawater to the second seawater heat exchanger (246a) so that the seawater and the heat medium are exchanged so that the heat source of the seawater can be supplied to the heat medium. have.

Hereinafter, individual configurations that are organically formed by the lines L1 to L4a described above to implement the gas regasification system 2 will be described.

The liquefied gas storage tank 10 stores liquid liquefied gas. The liquefied gas storage tank 10 can store liquefied gas at a pressure of about 1 bar or so, and the liquefied gas stored in the liquefied gas storage tank 10 is discharged to the outside of the liquefied gas storage tank 10 and then heat exchanger It can be vaporized by (24) and delivered to the demand destination (40).

Here, the demand destination 40 is, for example, an engine or a turbine that produces energy, or may be a city gas and a general household, but is not particularly limited, and the liquefied gas is delivered to the demand location 40 in a vaporized state by the heat exchanger 24. Can be.

The liquefied gas storage tank 10 may be provided in plural, and may be arranged side by side inside the hull 1a. As an example, at least four liquefied gas storage tanks 10 in the hull 1a may be arranged in a certain direction (front-rear direction) as shown in FIG. 1, but the number or arrangement of the liquefied gas storage tanks 10 is limited as above. It is not done.

The feeding pump 21 discharges the liquefied gas stored in the liquefied gas storage tank 10 to the outside of the liquefied gas storage tank 10, wherein the liquefied gas may be somewhat pressurized by the feeding pump 21. The pressurization by the feeding pump 21 may not be achieved until the required pressure of the demand destination 40. Therefore, the boosting pump 23 to be described later pressurizes the liquefied gas by the difference between the pressure of the liquefied gas pressurized by the feeding pump 21 and the required pressure of the demand destination 40.

The feeding pump 21, for example, may be configured as a centrifugal pump on the outside of the liquefied gas storage tank 10, or may be formed as a latent type inside.

A liquefied gas supply line (L1) may be provided from the feeding pump (21) to a customer (40), and three liquefied gas supply lines (L1) may be formed in parallel to form first to third trains. .

The feeding pump 21 may pressurize the liquefied gas stored in the liquefied gas storage tank 10 to 6 to 8 bar and supply it to the temporary storage tank 22. Here, the feeding pump 20 may pressurize the liquefied gas discharged from the liquefied gas storage tank 10 to increase the pressure and temperature somewhat, and the pressurized liquefied gas may still be in a liquid state.

The temporary storage tank 22 may be provided on the regasification supply line L1 to receive and temporarily store liquefied gas from the liquefied gas storage tank 10.

Specifically, the temporary storage tank 22 may receive liquefied gas stored in the liquefied gas storage tank 10 from the feeding pump 21 through the regasification supply line L1, and temporarily store the supplied liquefied gas By doing so, the liquefied gas can be separated into a liquid phase and a gas phase, and the separated liquid phase can be supplied to the boosting pump 23.

That is, the temporary storage tank 22 temporarily stores the liquefied gas to separate the liquid phase from the gas phase, and then supplies the complete liquid to the boosting pump 23 so that the boosting pump 23 satisfies the effective suction head (NPSH). In this way, it is possible to prevent cavitation in the boosting pump 23.

The boosting pump 23 pressurizes the liquefied gas discharged from the feeding pump 21, specifically, the liquefied gas supplied from the temporary storage tank 22.

Specifically, the boosting pump 21 may be provided between the temporary storage tank 22 and the heat exchanger 24a on the regasification supply line L1, and liquefied gas or temporary supplied from the feeding pump 21. The liquefied gas supplied from the storage tank 22 may be pressurized to 50 to 120 bar to be supplied to the heat exchanger 24a.

The liquefied gas pressurized by the boosting pump 23 may be greater than or equal to the required pressure of the demand destination 40 and may be configured as a centrifugal pump, and further pressurize the liquefied gas between the boosting pump 23 and the demand destination 40 There may be no means.

The heat exchanger 24a is composed of a first heat exchanger 241a and a second heat exchanger 242a provided on the regasification supply line L1, and is liquefied by receiving heat medium through the heat source circulation line L2a. The gas is re-evaporated and supplied to the demand destination 40. Here, the heat medium may be, for example, propane or a non-explosive phase change material as a phase change material.

The heat exchanger 24a includes a heat source circulation line L2a, a buffer tank 243a, a heat source pump 244a, a first seawater heat exchanger 245a, a second seawater heat exchanger 246a and a control valve 247a. It can contain.

The first heat exchanger 241a and the second heat exchanger 242a are provided on the regasification supply line L1 and receive heat medium from the heat source circulation line L2a to regasify the liquefied gas.

Here, the regasification supply line L1 may be arranged in order of the first heat exchanger 241a and the second heat exchanger 242a based on the flow of liquefied gas, and the first heat exchanger 241a is a vaporizer , The second heat exchanger 242a may be a trim heater.

The heat source circulation line L2a supplies a heat medium for regasifying liquefied gas to the first heat exchanger 241a and the second heat exchanger 242a, and the buffer tank 243a, the heat source pump 244a, and the first seawater heat exchange The group 245a may include a second seawater heat exchanger 246a and a control valve 247a.

Here, the heat source circulation line (L2a), the first sea water heat exchanger (245a), the second heat exchanger (242a), the second sea water heat exchanger (246a), the control valve 247a, the first heat exchange based on the flow of the heat medium The group 241a, the buffer tank 243a, and the heat source pump 244a may be arranged in this order.

The buffer tank 243a is provided upstream of the heat source pump 244a on the heat source circulation line L2a to temporarily store a heat medium.

Specifically, the buffer tank 243a is disposed between the heat source pump 244a and the first heat exchanger 241a on the heat source circulation line L2a, and temporarily stores heat medium supplied from the first heat exchanger 241a. , It is possible to maintain the pressure so that the circulation inside the heat source circulation line (L2a), which is a closed system, and also, by supplying only the liquid component to the heat source pump 244a, cavitation of the heat source pump 244a can be prevented. .

The heat source pump 244a is provided on the heat source circulation line L2a to circulate the heat medium.

Specifically, the heat source pump 244a may be disposed between the buffer tank 243a on the heat source circulation line L2a and the first seawater heat exchanger 245a, and receives only the liquid heat medium from the buffer tank 243a. It can be supplied to the first sea water heat exchanger (245a).

The first seawater heat exchanger 245a and the second seawater heat exchanger 246a are provided on the heat source circulation line L2a, so that heat source is supplied from the seawater to the heat medium by exchanging heat with the seawater.

Here, the first seawater heat exchanger 245a and the second seawater heat exchanger 246a can exchange heat with seawater in a state where both heat mediums are in a liquid state. That is, both the first seawater heat exchanger 245a and the second seawater heat exchanger 246a can process a single phase fluid.

The first seawater heat exchanger 245a can heat the heat medium and seawater to supply the heat medium to the second heat exchanger 242a, and the second seawater heat exchanger 246a is discharged from the second heat exchanger 242a. The heat medium can be exchanged with seawater.

That is, the second seawater heat exchanger 246a is located upstream of the control valve 247a on the heat source circulation line L2a, so that only the liquid phase is present rather than processing more than a mixture of gas phase and liquid phase. It is configured to handle.

In the case of the heat exchanger that processes the gas phase, since the gas phase is bulkier than the liquid phase, a large amount of flow is required to process the same heat capacity, which requires a plurality of heat exchangers in parallel.

In order to solve these drawbacks and achieve the same effect, in the present invention, as described above, a control valve 247a is built downstream of the second seawater heat exchanger 246a so that only the second seawater heat exchanger 246a is liquid. It is configured to handle fluids, which can reduce the size of the heat exchanger and reduce construction costs.

In addition, because of this, it is possible to reduce the section in which the heat medium having a large diameter flows on the heat source circulation line L2a, thereby reducing the overall size of the facility and reducing the overall construction cost.

The control valve 247a is provided between the first heat exchanger 241a and the second heat exchanger 242a on the heat source circulation line L2a, and converts the heat medium into at least some gas phase in the liquid phase. Here, the regulating valve 247a may be a pressure reducing valve.

Specifically, the control valve 247a is formed between the first heat exchanger 241a and the second seawater heat exchanger 246a on the heat source circulation line L2a, and is discharged from the second seawater heat exchanger 246a. It may be supplied to the first heat exchanger 241a by receiving a liquid heat medium and converting it into at least some gas phase.

Specifically, the graph illustrated in FIG. 4 will be described together.

4 is a graph showing a phase change in the control valve of the gas regasification system according to the first embodiment of the present invention.

In FIG. 4, the horizontal axis represents enthalpy, the vertical axis represents pressure, A1 is a liquid phase region, A2 is a 2phase region in which liquid phase and gas phase are mixed, and A3 represents a gas phase region.

The control valve 247a is supplied with a liquid heat medium discharged from the second seawater heat exchanger 246a to reduce pressure to convert it into a gas phase.

Referring to FIG. 4, the liquid heat medium discharged from the second seawater heat exchanger 246a corresponding to the B1 position is vertically moved from B1 to B2, thereby reducing the state of the decompressed heat medium to the A2 area, which is the 2Phase area. It enters and converts (B2) into at least some weather.

That is, in the present invention, the control valve 247a is disposed downstream of the second seawater heat exchanger 246a rather than upstream, so that the second seawater heat exchanger 246a can process only a single phase liquid phase, thereby reducing its size. It has the effect of reducing the construction cost.

The demand destination 40 can receive and consume liquefied gas regasified by the heat exchanger 24a. Here, the demand destination 40 may be used by receiving liquefied gas of gaseous phase by regasifying liquefied gas, and may be a land terminal installed on land or a sea terminal floating on the sea.

As described above, the gas regasification system 2 according to the present invention is constructed by constructing a pressure reducing valve 247a after the second seawater heat exchanger 246a provided downstream of the trim heater 242a on the heat source circulation line L2a. , Has the effect of using the second sea water heat exchanger (246a) as a single-phase heat exchanger, thereby reducing the size and cost of the second sea water heat exchanger (246a) and reducing the pipe diameter of the heat source circulation line (L2a) equipment It has the effect of reducing the size and cost.

5 is a conceptual diagram of a gas regasification system according to a second embodiment of the present invention.

5, the gas regasification system 2 according to the second embodiment of the present invention includes a liquefied gas storage tank 10, a feeding pump 21, a temporary storage tank 22, and a boosting pump ( 23), a heat exchanger (24b), and a destination (40).

Here, the gas regasification system 2 according to the second embodiment of the present invention has a change in the structure of the heat exchanger 24b, unlike the gas regasification system 2 according to the first embodiment. Details thereof will be described later.

Therefore, the configuration other than the heat exchanger 24b in the gas regasification system 2 according to the second embodiment of the present invention is the same as the respective reference numerals in the gas regasification system 2 according to the first embodiment for convenience. Can be used, but does not necessarily refer to the same configuration.

Hereinafter, the gas treatment system 2 according to the second embodiment of the present invention will be described with reference to FIG. 5, and the heat exchanger 24b will be mainly described.

The heat exchanger 24b is composed of a first heat exchanger 241b and a second heat exchanger 242b provided on the regasification supply line L1, and is liquefied by being supplied with a heat medium through a heat source circulation line L2b. The gas is re-evaporated and supplied to the demand destination 40. Here, the heat medium may be, for example, propane or a non-explosive phase change material as a phase change material.

The heat exchanger 24b includes a heat source circulation line L2b, a buffer tank 243b, a heat source pump 244b, a first seawater heat exchanger 245b, a second seawater heat exchanger 246b and a control valve 247b. It can contain.

The first heat exchanger 241b and the second heat exchanger 242b are provided on the regasification supply line L1 and receive heat medium from the heat source circulation line L2b to regasify the liquefied gas.

Here, the regasification supply line L1 may be arranged in order of the first heat exchanger 241b and the second heat exchanger 242b based on the flow of liquefied gas, and the first heat exchanger 241b is a vaporizer , The second heat exchanger 242b may be a trim heater.

The heat source circulation line L2b supplies a heat medium for regasifying liquefied gas to the first heat exchanger 241b and the second heat exchanger 242b, and the buffer tank 243b, the heat source pump 244b, and the first seawater heat exchange The unit 245b may include a second seawater heat exchanger 246b and a control valve 247b.

Here, the heat source circulation line (L2b) is branched to the first branch line (L5) and the second branch line (L6) downstream of the first seawater heat exchanger (245a) based on the flow of the heat medium, and the first branch line (L5) ) And the second branch line L6 are formed to be joined upstream of the buffer tank 243b after being connected to the second seawater heat exchanger 246b and the second heat exchanger 242b, respectively.

The first branch line (L5) is branched downstream of the first sea water heat exchanger (245a) based on the flow of the heat medium on the heat source circulation line (L2b), and is connected to the second sea water heat exchanger (246b), and a control valve ( 247b) and a first heat exchanger 241b.

The first branch line (L5), by reducing the pressure of the liquid heat medium supplied from the first sea water heat exchanger (245a) through a control valve (247b) to convert at least some gas phase to supply to the second sea water heat exchanger (246b) After that, it may be supplied to the first heat exchanger 241b.

The second branch line L6 may be branched downstream of the first seawater heat exchanger 245a based on the flow of the heat medium on the heat source circulation line L2b, and may be connected to the second heat exchanger 242b. It may be formed in parallel with the line (L5).

The second branch line L6 may supply the liquid heat medium supplied from the first seawater heat exchanger 245a to the second heat exchanger 242b.

The heat source circulation line L2b is arranged in the order of the heat source pump 244a and the first seawater heat exchanger 245b based on the flow of the heat medium, and then the first branch line L5 and the second branch line L6. Branched, in the first branch line (L5), the control valve 247b, the second sea water heat exchanger (246b) and the first heat exchanger (241b) are arranged in the order, the second branch line (L6) in the second heat exchanger (242b) is disposed is formed in parallel with the first branch line (L5), the first branch line (L5) and the second branch line (L6) after the confluence of the buffer tank (243b), heat source pump (244a) Can be placed in order.

The buffer tank 243b is provided upstream of the heat source pump 244b on the heat source circulation line L2b to temporarily store the heat medium.

Specifically, the buffer tank 243b is disposed between the heat source pump 244b and the first branch line L5 and the second branch line L6 joined on the heat source circulation line L2b, and the first heat exchange By temporarily storing the heat medium supplied from the group 241b and the heat medium supplied from the second heat exchanger 242b, the pressure can be maintained to allow circulation inside the heat source circulation line L2b, which is a closed system. By supplying only the components of the heat source pump 244b, cavitation of the heat source pump 244b can be prevented.

The heat source pump 244b is provided on the heat source circulation line L2b to circulate the heat medium.

Specifically, the heat source pump 244b may be disposed between the buffer tank 243b on the heat source circulation line L2b and the first seawater heat exchanger 245b, and only receive the liquid heat medium from the buffer tank 243b It can be supplied to the first sea water heat exchanger (245b).

The first seawater heat exchanger (245b) and the second seawater heat exchanger (246b) are provided on the heat source circulation line (L2b) so that heat is supplied from the seawater to the heat medium by exchanging heat between the seawater and the heat medium.

The first seawater heat exchanger 245b can heat the liquid heat medium and seawater from the heat source pump 244b, and supply the heated heat medium to the second heat exchanger 242b and the second seawater heat exchanger 246b, Only liquid heat medium can be exchanged with sea water.

The first seawater heat exchanger 245b processes a single-phase fluid, and may be configured such that the heat treatment capacity is greater than the heat treatment capacity of the second seawater heat exchanger 246b that processes the fluid.

The second seawater heat exchanger 246b may be discharged from the first seawater heat exchanger 246b and depressurized by the control valve 247b to heat-exchange the heat medium mixed with the gas phase and liquid phase with seawater.

The second seawater heat exchanger 246b processes the above-described fluid, and the heat treatment capacity may be configured to be smaller than the heat treatment capacity of the first seawater heat exchanger 245b for processing a single-phase fluid.

The second seawater heat exchanger 246b is disposed downstream of the control valve 247b on the first branch line L5 to process more fluids in which gaseous phase and liquid phase are mixed, thereby causing a single merchant liquid phase. When all of the amount of fluid supplied from the first seawater heat exchanger 245b for processing the fluid is processed, there is a problem that the size of the heat exchanger is large and the construction cost is increased compared to the first seawater heat exchanger 245b.

In order to solve this, in the present invention, as described above, a significant portion of the heat treatment capacity of the second seawater heat exchanger 246b is first processed in the first seawater heat exchanger 245b to heat-treat the second seawater heat exchanger 246b. The dose was reduced.

Through this, the second seawater heat exchanger 246b is configured to have the same or smaller heat treatment capacity than the first seawater heat exchanger 245b, and instead, the heat source circulation line L2a downstream of the first seawater heat exchanger 245b is eliminated. Branching to the first and second branching lines L5 and L6 may be distributed such that at least a portion is supplied to the first branching line L5 and the rest is supplied to the second branching line L6. At this time, only the corresponding heat medium of the second branch line L6 is processed by the second seawater heat exchanger 246b.

Due to this, it is possible to reduce the size and construction cost of the second seawater heat exchanger 246b for processing the above-described fluid, and it is possible to reduce the diameter of the section in which the gaseous heat medium flows on the heat source circulation line L2a. The overall size of the equipment can be reduced and the overall construction cost can be reduced.

Here, the first sea water heat exchanger 245b may be disposed under the upper deck (not shown) of the ship 1, and the second sea water heat exchanger 246b may be disposed above the upper deck. This is because the size of the second seawater heat exchanger 246b is reduced, so that it can be disposed on the upper deck.

The control valve 247b is provided between the first seawater heat exchanger 245b and the second seawater heat exchanger 246a on the heat source circulation line L2b, and converts the heat medium into a gas phase by depressurizing the heat medium. Here, the regulating valve 247b may be a pressure reducing valve.

That is, the regulating valve 247b may depressurize the liquid heat medium supplied from the first seawater heat exchanger 245a and convert it to at least some gas phase to supply it to the second seawater heat exchanger 246b.

Specifically, the control valve (247b), the first branch line (L5) on the heat source circulation line (L2b) on the first branch line (L5) and the second branch line (L6) branching point and the second seawater heat exchange It is formed between the groups 246b and receives the liquid heat medium discharged from the first seawater heat exchanger 245b and converts it into at least some gas phase to be supplied to the second seawater heat exchanger 246b.

As described above, the gas regasification system 2 according to the present invention is a second phase in which the fruit circulation line L2b is branched from the downstream of the first seawater heat exchanger 245b, which is a single phase disposed downstream of the heat source pump 244b. By supplying the fruit to the seawater heat exchanger 246b and the trim heater 242b, there is an effect of reducing the heat capacity of the above-described second seawater heat exchanger 246b, and thus the high cost of the second seawater heat exchanger 246b It has the effect of reducing size and cost.

Although the present invention has been described in detail through specific examples, the present invention is specifically for describing the present invention, and the present invention is not limited to this, and by those skilled in the art within the technical spirit of the present invention. It will be apparent that the modification and improvement are possible.

All simple modifications or changes of the present invention belong to the scope of the present invention, and the specific protection scope of the present invention will be clarified by the appended claims.

1: ship 1a: hull
2: Gas regasification system 10: Liquefied gas storage tank
20: regasifier 21: feeding pump
22: temporary storage tank 23: boosting pump
24: heat exchanger 241a, 241b: first heat exchanger
242a,242b: second heat exchanger 243a,243b: buffer tank
244a,244b: heat source pump 245a,245b: first seawater heat exchanger
246a,246b: Second sea water heat exchanger 247a,247b: Regulating valve (pressure reducing valve)
30: liquefied gas supply device 40: demand
L1: Regasification supply line L2a, L2b: Heat source circulation line
L3a,L3b: 1st seawater supply line L4a,L4b: 2nd seawater supply line
L5: First branch line L6: Second branch line
E: Propulsion engine P: Propeller
S: propulsion shaft

Claims (14)

A regasification supply line for regasifying liquefied gas and supplying it to a consumer;
A first heat exchanger and a second heat exchanger provided on the regasification supply line;
A first seawater heat exchanger and a second seawater heat exchanger supplying heat medium to the heat exchanger; And
And a heat source circulation line having the first seawater heat exchanger and the second seawater heat exchanger,
The heat source circulation line,
A first branch line branched downstream of the first seawater heat exchanger and connected to a pressure reducing valve, the second seawater heat exchanger, and the first heat exchanger; And
And a second branch line branched downstream from the first seawater heat exchanger and connected to the second heat exchanger.
The second seawater heat exchanger,
The pressure reducing valve is configured such that at least a part of the liquid heat medium is converted into a gas phase to treat the fluid, so that the heat treatment capacity is less than or equal to the heat treatment capacity of the first seawater heat exchanger that processes a single-phase fluid. Gas regasification system. delete According to claim 1,
The second branch line,
Gas regasification system, characterized in that formed in parallel with the first branch line. The method of claim 3,
It is provided on the heat source circulation line, further comprising a heat source pump for supplying the heat medium to the first seawater heat exchanger,
The first branch line and the second branch line,
A gas regasification system characterized in that it is joined upstream of the heat source pump on the heat source circulation line. The method of claim 4,
Further comprising a buffer tank provided on the heat source circulation line between the upstream of the heat source pump and the confluence point of the first branch line and the second branch line to temporarily store the heat medium,
The heat source pump,
Gas regasification system, characterized in that only the liquid heat medium is supplied from the buffer tank and supplied to the first seawater heat exchanger. The method of claim 5,
The first sea water heat exchanger receives and processes only the liquid heat medium from the heat source pump,
The second sea water heat exchanger, the gas regasification system, characterized in that the receiving and processing the heat medium mixed with the liquid phase and gas phase from the pressure reducing valve. The method of claim 6, wherein the first branch line,
A gas regasification system, characterized in that after passing through the first heat exchanger downstream of the second seawater heat exchanger, the second branch line is joined upstream of the buffer tank. The method of claim 7, wherein the second sea water heat exchanger,
Gas regasification system, characterized in that disposed on the upper deck of the ship. The method of claim 8, wherein the first sea water heat exchanger,
Gas regasification system, characterized in that disposed under the upper deck. The method of claim 9,
The first heat exchanger is a vaporizer,
The second heat exchanger is a gas regasification system, characterized in that the trim heater. The method of claim 7,
A feeding pump provided on the regasification supply line to discharge liquefied gas stored in a liquefied gas storage tank;
A temporary storage tank provided downstream of the feeding pump on the regasification supply line and temporarily storing liquefied gas supplied from the feeding pump; And
Gas recovery characterized in that it is provided between the first heat exchanger and the temporary storage tank on the regasification supply line, and further comprising a boosting pump that supplies liquefied gas supplied from the temporary storage tank to the first heat exchanger. System. The method of claim 1, wherein the heating medium,
Gas regasification system, characterized in that the phase change material. The method of claim 1, wherein the heating medium,
Gas regasification system characterized in that it is a non-explosive phase change material or propane. A ship provided with the gas regasification system according to any one of claims 1 and 3 to 13.

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