EP1853846A1

EP1853846A1 - Plant for regasification of liquefied natural gas

Info

Publication number: EP1853846A1
Application number: EP06709300A
Authority: EP
Inventors: Alexandre Rojey; Ari Minkkinen
Original assignee: IFP Energies Nouvelles IFPEN
Current assignee: IFP Energies Nouvelles IFPEN
Priority date: 2005-02-17
Filing date: 2006-02-13
Publication date: 2007-11-14
Anticipated expiration: 2026-02-13
Also published as: ES2385575T3; WO2006087452A1; US20080302103A1; ATE553330T1; PT1853846E; FR2882129A1; KR20070114167A; JP2008530472A; EP1853846B1

Abstract

The invention relates to a plant for regasification of liquefied natural gas (GNL), comprising a liquefied gas storage reservoir (10) and a regasification device (12) for the GNL through which the natural gas and a heat transfer medium flow. According to the invention, the plant comprises a loop circuit (16) in which the heat transfer medium circulates in the form of a low-viscosity organic liquid with a low crystallisation point and the regasification device (12) comprises at least two exchangers (60, 62).

Description

Regasification plant for liquefied natural gas

The present invention relates to a regasification plant for liquefied natural gas and a method used in such an installation.

Generally, when natural gas is to be transported between a production site and an operating site that are close to each other, this transportation is done through onshore or submerged pipelines. In this case, the natural gas is transported in its gaseous form and can be used as such at its place of destination.

However, when the two sites are too far apart or the configuration of the land does not allow the laying of pipelines, the gas is transported in liquefied form by land vehicles or boats (usually LNG tankers) between the site production and the operating site. For this purpose, the natural gas is liquefied near the production site during compression and cooling operations to a temperature of -160 ^° C. The liquefied natural gas (LNG) is then stored in appropriate tanks and then transferred under liquid form in tanks for its land or sea transport to the site of exploitation. Once arrived at this site, this liquefied gas is discharged into LNG storage tanks from which this gas can be regasified on demand and used, either directly on the operating site or transported in gaseous form via pipelines. to other places of exploitation.

Usually, in the case of maritime transport of LNG, the liquefied gas is stored and transported to the vicinity of the coastal terminal in isothermal tanks of the LNG carrier. This liquefied gas is either regasified from the tanks of the LNG carrier and then transported in gaseous form via pipelines to the operating sites, or sent in liquid form to tanks of the coastal terminal for storage and regasification on demand. Currently, in order to perform the regasification operation, the gas in liquid form is pumped from the tank or tank and then passes through a set of heat exchangers that act as a vaporizer or vaporizer. regasification. In order to ensure a heat exchange, this set of heat exchangers is traversed by sea water, possibly heated, so that the calories present in this water are transmitted to the gas. Thanks to the transmission of these calories, the gas is warmed along its path in the heat exchanger assembly and gradually changes state to emerge from this set of exchangers in gaseous form.

Such provisions have significant disadvantages both in terms of nature preservation and the integrity of the exchangers.

Indeed, the seawater that has passed through the heat exchangers is discharged into the sea with a very low temperature, resulting in a degradation of the flora and fauna underwater. In addition, seawater is a corrosive agent for all the metal parts of the exchangers and therefore leads to greater maintenance of these exchangers. In addition, given that LNG circulates in the exchangers with a very low temperature, the seawater must travel these exchangers with a high flow rate so as to avoid forming crystals, which requires pumping installations of large size with a high cost.

The present invention proposes to overcome the disadvantages mentioned above through a regasification installation that uses a heat-transfer agent that is environmentally friendly and that can be used far from any coastal terminal.

Thus, the present invention relates to a regasification plant for liquefied natural gas comprising a gas storage tank in liquefied form and a regasification device for LNG covered by a heat transfer medium and natural gas, characterized in that the installation comprises a loop circuit in which circulates the heat transfer medium in the form of a low viscosity organic fluid and a low crystallization temperature point and in that the regasification device comprises at least two exchangers. The installation may include a reheat unit _. the heat transfer agent.

Advantageously, the reheating unit can be traveled _. by air.

The heat transfer agent may have a crystallization temperature of between -90 ° C. and -150 ° C.

Preferably, the heat transfer agent may be an alcohol such as methanol, ethanol or propanol.

One of the exchangers can be co-current between the LNG and the heat transfer agent and the other exchangers can be against the current.

The countercurrent exchanger may be in two parts between which is interposed a phase separator.

At least the countercurrent exchanger may be of the type with brazed plates and fins.

The circulation circuit of the heat transfer agent may comprise an additional heating drainer.

The installation may comprise means for liquefying a hydrocarbon by heat exchange with the heat transfer medium.

The hydrocarbon can be in gaseous form after its application to driving a turbine.

Advantageously, the hydrocarbon may be propane. The installation may also include means for trapping CO ₂ by the heat transfer medium.

Preferably, the heat transfer agent may be used as a CO ₂ solvent.

The other characteristics and advantages of the invention will appear better on reading the description which follows, given solely by way of illustration and in no way limiting, with reference to the appended drawings in which:

FIG. 1 is a schematic view of the LNG regasification plant according to the invention;

- Figure 2 is a partial sectional view of the heater used in the installation according to the invention; FIG. 3 is a diagrammatic sectional view of the regasifier used in this installation;

FIG. 4 is a first variant of the regasification installation according to the invention;

FIG. 5 is another variant of the regasification plant according to the invention;

FIG. 6 shows an example of a particular use of the installation according to the invention and

- Figure 7 shows another example of a use of the installation according to the invention.

FIG. 1 schematically shows a regasification plant for a liquefied natural gas (LNG) which comprises an LNG storage tank 10 at atmospheric pressure and at a temperature in the region of -160 ^° C., a regasification device with a unit of heat exchanger, or regasifier 12, traversed by a heat transfer agent and by the LNG from the tank, and a heating unit 14 of the heat transfer medium. The heat transfer agent is an organic fluid whose crystallization point is close to that of LNG and has a sufficiently low viscosity so that it can be easily circulated in pipes even at very low temperatures. In addition, this agent remains in the liquid state under conditions of use at atmospheric pressure and at room temperature. Preferably, this heat transfer agent may be an alcohol or a hydrocarbon or a compound thereof. In the following description, the organic fluid considered by way of example is methanol whose crystallization point is around -98 ° C but it can also be used other alcohols such as ethanol (point of crystallization: - 114 ° C) or propanol (crystallization point: -126 ° C).

This installation comprises a circulation loop 16 of the heat transfer medium which, in the example shown, is a closed loop with a hot part and a cold part. This loop comprises a circulation pump 18, a circulation line 20 of this agent between the pump and the regasifier 12, a circulation line 22 between the regasifier and the reheating unit 14, a return line 24 between this unit of reheating and the circulation pump, a tank 26 of coolant being interposed on this return line. The installation also comprises an LNG suction pump 28 generally immersed in the tank 10, a circulation pipe 30 of the LNG between this pump and a circulation pump 32, a pipe 34 bringing the LNG of this circulation pump to the regasifier. 12, and an outlet conduit 36 for conveying gas in gaseous form exiting the regasifier to any suitable means. The heating unit is also traversed by a heating fluid 38 which is, in the example shown, outside air at room temperature and comprises a discharge 40 of the condensates from this air. Of course, this reheating air can also come from any devices present at the place of operation, such as fumes discharged by a gas turbine. To perform the regasification, the LNG is pumped from the tank 10 by the pumps 28 and 32, circulates in the lines 30 and 34 to be sent into the regasifier 12. This gas circulates in the regasifier which is also traversed by the methanol as heat transfer agent. To do this, the methanol present in the tank 26 is pumped by the pump 18 and is sent via line 20 into the regasifier 12. In this regasifier, the calories present in the methanol are transmitted to the LNG and heat it so that that the liquid phase of the LNG is changed into a gas phase by vaporization and then, if necessary, superheated to reach a temperature close to that of the ambient temperature.

The methanol temperature at the regasifier 12 inlet is about

20 ^° C. and about -160 ° C. for the LNG circulating in line 34. At the exit of this regasifier, the natural gas is at a temperature of about 5 ° C. while the methanol reaches a temperature of about 70 ° C at the exit of this regasifier in line 22.

During the exchange in the regasifier, the methanol is cooled to a temperature above its crystallization point, in this case -70 ^° C. for the example under consideration. The cold methanol is sent via the pipe 22 to the reheating unit 14 so that the air circulating in this unit, and whose temperature is higher than that of the cold methanol, exchanges its calories with this methanol to obtain methanol heated in line 24 and consequently in reservoir 26.

The temperature of the methanol at the inlet of the heating unit is of the order of -70 ^° C. whereas the air is introduced into this heater at a temperature in the region of 30 ^° C. After heat exchange in this unit, the methanol is discharged at the outlet of the unit at a temperature of 0 ⁰ C while the air leaves at a temperature of 5 ⁰ C. Thus, the hot part of the loop 16 is formed by the pipe 24, the reservoir 26, the pump 18 and the pipe 20, while the cold part of this loop comprises the pipe 22.

To achieve reheating of methanol at the exit of the regasifier, and as shown in FIG. 2, the heating unit 14 comprises a heat exchanger comprising a vertical calender 42 with an air inlet 44 and an outlet of air 46 disposed at each end of this calender. Inside this shell is housed a set of vertical tubes 48 connected at one of their ends by an intake manifold 50 with an inlet 52 for cold methanol from the regasifier and at the other their ends by an exhaust manifold 54 with an outlet 56 connected to the pipe 24 leading to the methanol tank 26. In this heat exchanger, the methanol arrives through the inlet 52, enters the intake manifold 50, circulates in all vertical tubes 48, to open into the exhaust manifold 54 and be discharged through the outlet 56. Simultaneously, air, either at room temperature, or heated by any known means, is introduced into the calender 42 through the inlet 44, then scans all the tubes as well as the collectors. During this sweep, the calories contained in this air are transmitted to methanol so as to heat it up and obtain a hot methanol at the outlet 56. During this exchange, the water droplets contained in the air are condensed and then fall by gravity to the bottom of the calender 42 to be then discharged in the form of condensates through the pipe 40. The tubes 48 may be coated with a film of hydrophobic material ("water shedding film") of polymethylsiloxane type to facilitate the separation of water droplets .

Referring now to FIG. 3, the regasifier comprises a vertical envelope 58 containing at least two exchangers in which gas and methanol circulate, an upper exchanger 60 placed in the upper part of the envelope and a lower exchanger 62 placed in lower part of this envelope. Preferably, these exchangers are in the form of heat exchangers. plates and fin brazed, preferably aluminum. The upper exchanger is said to be against the flow because natural gas and methanol circulate in opposite directions while the lower exchanger is said to co-current, fluids flowing in the same direction. Thus for the lower exchanger, it comprises, on one of its sides and in the lower part of this exchanger, an inlet 64 of the methanol connected to the pipe 20 and an outlet 66 on one side of the exchanger. This lower heat exchanger also comprises an inlet 68, connected to the LNG pipe 34, which is located at the bottom and on the side opposite to that of the methanol inlet, and an outlet 70 placed in the upper part of the exchanger. Thus, in the lower exchanger 62, the flows of methanol and LNG flow in the same direction, that is to say from the bottom to the top of this exchanger. Thanks to this, the skin temperature inside this exchanger remains above -100 ⁰ C and the exchange surfaces can be minimized. The outlet 66 of methanol is connected via a line 72 to an inlet 74 of the upper exchanger which is located at the top and on one side of this exchanger. Similarly, the outlet 70 of natural gas is connected by a pipe 76 to a gas inlet 78 located on the lower part of this exchanger. The vapor form gas is discharged through an outlet 80 which is located on the upper part of this exchanger while the outlet 82 of the methanol is located in the lower part of this exchanger to be connected to the pipe 22 leading to the reheating unit . This exchanger is therefore called a countercurrent heat exchanger because the flow of gas and methanol flow in opposite directions, for the gas from the bottom to the top of the exchanger and for methanol from the top to the bottom of this exchanger .

In the variant shown by way of example in FIG. 4, the regasifier 12 is separated into two distinct parts. Thus, the co-current exchanger 62 is in the form of a tube and shell exchanger and comprises the inlets 64, 68 and the outlets 66, 70 of methanol and LNG. The outputs 66 and 70 are connected by the. conduits 72, 76 to the countercurrent exchanger 60 which is a brazed plate and fin exchanger, advantageously aluminum, and which has the inputs 74, 78 and outputs 82, and 80 of methanol and natural gas.

Preferably, the tube and shell heat exchanger comprises a mechanical expansion joint 83 which absorbs all the dimensional variations of this exchanger during the passage of LNG and methanol.

In this variant, the operation of the installation is identical to that described with reference to FIGS. 1 to 3.

Referring now to Figure 5 which shows a variant of the regasification installation illustrated in Figure 4 and which, for this, has the same references for the common parts.

This variant is distinguished by the fact that regasification is carried out in several stages. In addition, the countercurrent exchanger 60 is in two parts 6OA, 6OB and a phase separator 84 is provided between these two exchanger parts.

The natural gas leaving the co-current heat exchanger 62 with tubes and calender at the outlet 70 is preheated to its boiling point corresponding to the pressure in the separator 84. This heated natural gas passes through the lower part 6OA. countercurrent exchanger 60 for performing a vapor phase transformation. This converted natural gas is sent via line 86 into the separator 84 where separation of the natural gas in gaseous form in the upper part 88 of this separator takes place with a composition, a molecular weight and a lower heating value and in liquid form in part. bass 90 of this separator. The natural gas in vapor form present in the separator is then directed, via a line 92, from this separator to the inlet of the part 6OB of the exchanger 60 where it undergoes, by exchange with the methanol circulating therein, an elevation The liquid phase, which has a molecular weight and a heating value greater than that of the steam, is extracted by a pump 94 connected to this separator by a pipe 96. The liquid phase leaving the pump 94 is directed by a pipe 98 to all storage means to be subsequently treated. Advantageously, it is possible to control the composition and the power heat of natural gas in gaseous form in line 92 before it enters the exchanger 60 by injecting a predetermined quantity of liquid from the separator through a line 98A originating after the pump 94 on line 98 and ending on Ia In this configuration, the temperature at the outlet of the natural gas regasifier is of the order of 0 ^° C. and that of the methanol is approximately -70 ^° C.

Additionally, it is possible to heat the methanol at the outlet of the pump 18 by placing on the pipe 20 a heat exchanger 100 between the methanol and a hot fluid which is usually used on or near this regasification plant, such as hot water from trickling towers.

As previously described, the methanol at the exit of the regasifier is at a low temperature of the order of -70 ^° C. and must be reheated in order to be able to ensure the transformation into gas phase of the LNG in the regasifier. For this, it can be taken advantage of the presence on the site of a power plant with a combined cycle gas turbine as shown in Figure 6. In this case, the central 102 is supplied with air by a channel 104 and natural gas via a channel 106, this channel may be a bypass of the conduit 36 described above. The combustion of the air-natural gas mixture within the turbine generates, after recovery of the generated calories (abbreviated as HRSG), at the exit 108 of the fumes with temperatures of the order of 130 ^° C. As shown in FIG. these fumes are introduced through an inlet 110 in a heat exchanger assembly 112, separated into at least three portions 112A, 112B, 112C, to emerge through an evacuation 114 and then be directed by a conduit 116 to any suitable means, such as a chimney . The heat exchanger assembly is also traversed by a phase-change fluid, such as propane, circulating in a closed loop 118. This loop comprises a liquid propane tank 120, a circulation pump 122 connected to the tank via a pipe 124 and a propane phase separator 126 connected to the pump via a line 128E which brings the liquid propane into the portion 112A of the assembly. heat exchanger and a 128S pipe which directs the propane, preheated to its boiling point, in this separator. From this separator, leave two pipes, a pipe 130, called liquid pipe, wherein the liquid contained in the separator is fed to the portion 112B of the heat exchanger assembly to cross and return in gaseous form in the separator 126, and a pipe 132, called gas line, which brings the gas phase of the propane contained in the separator to the portion 112C of the heat exchanger assembly so as to superheat this propane gas. A line 134 brings propane gas in pressurized form to an expansion turbine 136 rotatably connected to all energy producing means, such as an alternator 138. At the outlet of the expansion turbine, the propane gas is supplied by a pipe 140 to a heat exchanger 142, said condenser, for cooling this propane gas and thus change phase to obtain a liquid phase before it returns through a pipe 144 to the tank 120. To cool the propane, the condenser 142 is traversed by the methanol flowing in the pipe 22, as described above, and at the outlet of this condenser, the methanol is at a temperature higher than that of its introduction because it has captured the calories contained in propane gas phase. In operation, propane in liquid form is pumped from the tank

120 to cross the portion 112A of the exchanger assembly 112. After this crossing, the preheated propane in liquid form is sent into the separator 126. The liquid phase extracted from this separator passes through the portion 112B of the assembly 112 to return in form substantially gaseous in the separator to effect the separation between the liquid phase and the gas phase of the propane. The gaseous phase contained in this separator is also extracted to cross the portion 112C of the exchanger assembly 112 to be completely converted into the gas phase and superheated if necessary. The propane in gaseous form passes through the turbine 136 which it drives in rotation, which turbine rotates the alternator 138. At the outlet of the turbine, the gas-form propane passes through the condenser 142 where it changes phase and goes into liquid phase through the exchange of its calories with cold methanol that also circulates in this condenser. At the outlet of this condenser, the liquid propane is stored in the tank 120.

The treatment group as schematically illustrated in FIG. 7 shows a potential use of the LNG regasification facility with a methanol loop for capturing and liquefying the CO ₂ contained in discharges, such as the fumes from the turbine fumes. gas.

In this configuration, there is provided an LNG regasification unit 146, a CO ₂ capture / separation unit 148, a methanol heating unit 149 and a CO ₂ liquefying unit 150.

The regasification unit 146, as already described in connection with the preceding figures, comprises a regasifier 12 traversed by hot methanol circulating in a loop 152 and by LNG from the line 34. The unit for capturing / separating the CO ₂ 148 includes an absorption column 154 containing transfer elements 156 with a methanol inlet 158 from the regasifier, an entry of a gaseous fluid 160 containing CO ₂ , an evacuation 162 of gaseous fluid freed from CO ₂ and an exit 164 of a mixture of methanol and CO ₂ . This CO ₂ capture / separation unit also comprises a flash drum 166 with an inlet of the mixture of methanol and CO ₂ , an outlet 168 of CO ₂ in gaseous form and a 170 output of methanol removed from a very large portion of CO ₂ .

The heating unit 149 comprises elements identical to those already described in relation with FIGS. 1 and 2, that is to say a heater traversed by methanol originating, in the example illustrated in FIG. outlet 170 of the balloon 166, by a heating fluid 38 which may be outside air at room temperature. This exchanger also comprises an evacuation 40 of the condensates coming from this outside air. This unit finally comprises a heat exchanger 174 for heating the methanol after passing through the heater through an outlet 172 and a flash tank 175 for separating methanol in liquid form, which is then directed by a line 176 to the methanol loop, and CO ₂ in gaseous form which joins via a line 178, a line 180 also connecting the CO _{2 line} 168 of the flash tank 166.

The liquefaction unit 150 comprises a condenser 181 which has the particularity of using an intermediate fluid, such as ethane, to participate in the liquefaction of CO ₂ and the heating of the natural gas in vapor form.

This condenser comprises an enclosure 182 which contains at least two parts of condensers 184 and 186, each against the current and preferably in the form of brazed aluminum plates and fins, in which the CO ₂ in vapor form circulates and the ethane for one and LNG and ethane for the other. The lower condenser 184 is placed in the lower part of the enclosure and comprises, on one of its sides and in the upper part of this condenser, an inlet 188 of the CO ₂ connected to the pipe 180 and a liquid CO ₂ outlet 190 on the lower part of the condenser. The upper condenser 186 comprises an LNG inlet 192, connected to the LNG line 34, which is located in the lower part of this condenser and an outlet 194 placed in the upper part of the exchanger. A closed loop of ethane 196 allows the ethane to circulate between the two exchangers. More precisely, the ethane vapor is introduced into the upper ethane condenser 186 via an inlet 198 situated on the upper part of the condenser, passes through this condenser to produce a liquid ethane outlet 200 located at the bottom of this condenser, is fed via a pipe 202 to a liquid ethane inlet 204 located in the lower part of the lower CO ₂ condenser, passes through the lower condenser to reach an outlet 206 located in the upper part of this condenser and then leads to the inlet 198 by a conduct 208.

During operation of the treatment group described above, the LNG follows substantially the same regime as that described with reference to FIG. 1 with the only difference that a bypass of the LNG pipe 34 leads to the inlet 192 of the CO ₂ liquefaction unit 150 to cross the upper condenser 186 and exit through the outlet 194 to join the conduit 36. At the outlet of the regasifier, the methanol is sent via the inlet 158 to the column 156 which also receives a fluid containing a significant part of CO ₂ , of the order of 12%, through the inlet 160. After treatment in this column, the CO ₂ is captured by methanol and a mixture of methanol and dissolved CO ₂ is discharged through the outlet 164. The CO ₂ free fluid is discharged through the outlet 162 to any suitable means. The mixture of CO ₂ and methanol is separated in the expansion flask 166 from which the CO ₂ vapor phase is discharged through the outlet 168 to the pipe 180 and from which the methanol in the liquid phase from the outlet 170 is heated in the heating unit by successive crossing of the heater and the exchanger 174. At the outlet of the exchanger 174, the residual CO ₂ contained in the methanol is separated once more from this methanol in the expansion tank 175. During this separation, the CO ₂ is discharged through the outlet 178 to join the pipe 180 connected to the outlet 168 and the CO _2- freed methanol joined, through the outlet 176, the pump 18 of the methanol loop. The CO ₂ in the vapor phase is liquefied in the lower condenser 184 in which it exchanges its calories with the ethane which circulates in a loop between the two condensers. After this exchange, the CO ₂ is in liquid form at the outlet 190 and can be sent to a storage tank where it can be removed for possible sequestration in underground tanks.

The present invention is not limited to the embodiments described but encompasses all variants and all equivalents.

Claims

1) Regasification plant for liquefied natural gas (LNG) comprising a tank (10) for storing gas in liquefied form and a regasification device (12) for LNG covered by a heat transfer medium and natural gas, characterized in that plant comprises a loop circuit (16) in which the heat transfer medium circulates in the form of a low viscosity organic fluid with a low crystallization temperature point and in that the regasification device (12) comprises at least two exchangers (60, 62).

2) regasification plant according to claim 1, characterized in that it comprises a heating unit (14) of the heat transfer medium.

3) regasification plant according to claim 2, characterized in that the reheating unit (14) is traversed by air.

4) regasification plant according to one of the preceding claims, characterized in that the heat transfer agent has a crystallization temperature between -90 ° C and -150 ° C.

5) regasification plant according to one of the preceding claims, characterized in that the heat transfer agent is an alcohol such as methanol, ethanol or propanol.

6) regasification plant according to claim 1, characterized in that one (62) of the exchangers is co-current between the LNG and the heat transfer agent and in that the other (60) exchangers is against current.

7) regasification plant according to claim 6, characterized in that the countercurrent exchanger (60) is in two parts (60A, 60B) between which is inserted a phase separator (84). 8) regasification plant according to claim 6 or 7, characterized in that at least the countercurrent exchanger (60) is of the type plates and brazed fins.

9) Regasification plant according to one of the preceding claims, characterized in that the circuit (16) for circulating the heat transfer agent comprises an additional heating exchanger (100).

10) regasification plant according to one of the preceding claims, characterized in that it comprises means for liquefying a hydrocarbon by heat exchange with the heat transfer agent.

11) regasification plant according to claim 10, characterized in that the hydrocarbon is in gaseous form after its application to driving a turbine (136).

12) regasification plant Ia claim 10 or 11, characterized in that the hydrocarbon is propane.

13) regasification plant according to one of claims 1 to 9, characterized in that it comprises means for trapping CO ₂ by the heat transfer agent.

14) regasification plant according to claim 13, characterized in that the heat transfer agent is used as a CO ₂ solvent.