EP1853846B1 - Plant for regasification of liquefied natural gas - Google Patents
Plant for regasification of liquefied natural gas Download PDFInfo
- Publication number
- EP1853846B1 EP1853846B1 EP06709300A EP06709300A EP1853846B1 EP 1853846 B1 EP1853846 B1 EP 1853846B1 EP 06709300 A EP06709300 A EP 06709300A EP 06709300 A EP06709300 A EP 06709300A EP 1853846 B1 EP1853846 B1 EP 1853846B1
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- EP
- European Patent Office
- Prior art keywords
- regasification
- exchanger
- methanol
- plant
- lng
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
- F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
- F17C7/00—Methods or apparatus for discharging liquefied, solidified, or compressed gases from pressure vessels, not covered by another subclass
- F17C7/02—Discharging liquefied gases
- F17C7/04—Discharging liquefied gases with change of state, e.g. vaporisation
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
- F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
- F17C9/00—Methods or apparatus for discharging liquefied or solidified gases from vessels not under pressure
- F17C9/02—Methods or apparatus for discharging liquefied or solidified gases from vessels not under pressure with change of state, e.g. vaporisation
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
- F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
- F17C9/00—Methods or apparatus for discharging liquefied or solidified gases from vessels not under pressure
- F17C9/02—Methods or apparatus for discharging liquefied or solidified gases from vessels not under pressure with change of state, e.g. vaporisation
- F17C9/04—Recovery of thermal energy
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
- F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
- F17C2221/00—Handled fluid, in particular type of fluid
- F17C2221/01—Pure fluids
- F17C2221/013—Carbone dioxide
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
- F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
- F17C2221/00—Handled fluid, in particular type of fluid
- F17C2221/03—Mixtures
- F17C2221/032—Hydrocarbons
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
- F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
- F17C2221/00—Handled fluid, in particular type of fluid
- F17C2221/03—Mixtures
- F17C2221/032—Hydrocarbons
- F17C2221/033—Methane, e.g. natural gas, CNG, LNG, GNL, GNC, PLNG
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
- F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
- F17C2221/00—Handled fluid, in particular type of fluid
- F17C2221/03—Mixtures
- F17C2221/032—Hydrocarbons
- F17C2221/035—Propane butane, e.g. LPG, GPL
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
- F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
- F17C2223/00—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel
- F17C2223/01—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel characterised by the phase
- F17C2223/0146—Two-phase
- F17C2223/0153—Liquefied gas, e.g. LPG, GPL
- F17C2223/0161—Liquefied gas, e.g. LPG, GPL cryogenic, e.g. LNG, GNL, PLNG
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
- F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
- F17C2223/00—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel
- F17C2223/03—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel characterised by the pressure level
- F17C2223/033—Small pressure, e.g. for liquefied gas
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
- F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
- F17C2225/00—Handled fluid after transfer, i.e. state of fluid after transfer from the vessel
- F17C2225/01—Handled fluid after transfer, i.e. state of fluid after transfer from the vessel characterised by the phase
- F17C2225/0107—Single phase
- F17C2225/0123—Single phase gaseous, e.g. CNG, GNC
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
- F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
- F17C2225/00—Handled fluid after transfer, i.e. state of fluid after transfer from the vessel
- F17C2225/03—Handled fluid after transfer, i.e. state of fluid after transfer from the vessel characterised by the pressure level
- F17C2225/033—Small pressure, e.g. for liquefied gas
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
- F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
- F17C2225/00—Handled fluid after transfer, i.e. state of fluid after transfer from the vessel
- F17C2225/03—Handled fluid after transfer, i.e. state of fluid after transfer from the vessel characterised by the pressure level
- F17C2225/035—High pressure, i.e. between 10 and 80 bars
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
- F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
- F17C2227/00—Transfer of fluids, i.e. method or means for transferring the fluid; Heat exchange with the fluid
- F17C2227/03—Heat exchange with the fluid
- F17C2227/0302—Heat exchange with the fluid by heating
- F17C2227/0309—Heat exchange with the fluid by heating using another fluid
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
- F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
- F17C2227/00—Transfer of fluids, i.e. method or means for transferring the fluid; Heat exchange with the fluid
- F17C2227/03—Heat exchange with the fluid
- F17C2227/0302—Heat exchange with the fluid by heating
- F17C2227/0309—Heat exchange with the fluid by heating using another fluid
- F17C2227/0323—Heat exchange with the fluid by heating using another fluid in a closed loop
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
- F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
- F17C2227/00—Transfer of fluids, i.e. method or means for transferring the fluid; Heat exchange with the fluid
- F17C2227/03—Heat exchange with the fluid
- F17C2227/0302—Heat exchange with the fluid by heating
- F17C2227/0327—Heat exchange with the fluid by heating with recovery of heat
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
- F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
- F17C2227/00—Transfer of fluids, i.e. method or means for transferring the fluid; Heat exchange with the fluid
- F17C2227/03—Heat exchange with the fluid
- F17C2227/0367—Localisation of heat exchange
- F17C2227/0388—Localisation of heat exchange separate
- F17C2227/0393—Localisation of heat exchange separate using a vaporiser
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
- F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
- F17C2260/00—Purposes of gas storage and gas handling
- F17C2260/03—Dealing with losses
- F17C2260/031—Dealing with losses due to heat transfer
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
- F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
- F17C2265/00—Effects achieved by gas storage or gas handling
- F17C2265/05—Regasification
Definitions
- the present invention relates to a regasification plant for liquefied natural gas and a method used in such an installation.
- the gas is transported in liquefied form by land vehicles or boats (usually LNG tankers) between the site production and the operating site.
- land vehicles or boats usually LNG tankers
- 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 in liquid form into tanks for land or sea transport to the operating 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 site of operation or transported in gaseous form via pipelines. to other places of exploitation.
- 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 tanker 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.
- 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.
- 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.
- 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.
- seawater is a corrosive agent for all the metal parts of the exchangers and therefore leads to greater maintenance of these exchangers.
- the seawater must travel these exchangers with a large flow rate so as to avoid forming crystals, which necessitates pumping installations. 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.
- the present invention relates to a regasification plant of liquefied natural gas as defined by claim 1.
- the installation may comprise a heating unit of the heat transfer agent.
- the reheating unit can be traversed by air.
- the heat transfer agent may have a crystallization temperature of between -90 ° C. and -150 ° C.
- 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 heat exchanger.
- 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.
- the hydrocarbon may be propane.
- the installation may also include means for trapping CO 2 by the heat transfer medium.
- the heat transfer agent may be used as a CO 2 solvent.
- the figure 1 schematically shows a regasification plant of a liquefied natural gas (LNG) which comprises a storage tank 10 LNG at atmospheric pressure and at a temperature of -160 ° C, a regasification device with a unit of heat exchangers 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.
- LNG liquefied natural gas
- the coolant is an organic fluid whose crystallization point is close to that of LNG and has a viscosity sufficiently low to be able to be easily circulated in pipes even at very low temperatures.
- this agent remains in the liquid state under conditions of use at atmospheric pressure and at room temperature.
- this heat transfer agent may be an alcohol or a hydrocarbon or a compound thereof.
- 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.
- 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.
- 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.
- this reheating air can also come from any devices present at the place of operation, such as fumes discharged by a gas turbine.
- 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.
- the methanol present in the reservoir 26 is pumped by the pump 18 and is sent via line 20 into the regasifier 12.
- the calories present in the methanol are transmitted to the LNG and heat it up 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 temperature of the methanol at the inlet of the regasifier 12 is about 20 ° C. and about -160 ° C. for the LNG flowing in the pipe 34.
- the natural gas is at a temperature close to of 5 ° C while the methanol reaches a temperature of about -70 ° C at the exit of this regasifier in line 22.
- 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 a methanol heated in the pipe 24 and consequently in the 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 of about 30 ° C. After heat exchange in this unit, the methanol is discharged at the outlet of the unit at a temperature of 0 ° C while the air leaves at a temperature of 5 ° C.
- 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.
- the heating unit 14 comprises a heat exchanger comprising a vertical calender 42 with an air inlet 44 and an air outlet 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.
- 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.
- 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.
- 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 .
- the regasifier comprises a vertical envelope 58 which contains at least two exchangers in which the gas and the methanol circulate, an upper exchanger 60 placed in the upper part of the envelope and a lower exchanger 62 placed in the lower part of this envelope.
- these exchangers are in the form of heat exchangers. plates and fin brazed, preferably aluminum.
- the upper exchanger is said against the current because the natural gas and methanol flow in opposite directions while the lower exchanger is said to co-current, the fluids flowing in the same direction.
- the lower exchanger 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.
- 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 ° 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.
- 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 .
- the co-current exchanger 62 is in the form of a tube and shell heat exchanger and comprises the inlets 64, 68 and the outlets 66, 70 of methanol and LNG.
- the outlets 66 and 70 are connected by the lines 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.
- 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.
- figure 5 shows a variant of the regasification facility illustrated in figure 4 and which, for that, includes the same references for the common parts.
- This variant is distinguished by the fact that regasification is carried out in several stages.
- the countercurrent exchanger 60 is in two parts 60A, 60B and a phase separator 84 is provided between these two exchanger parts.
- the natural gas exiting the co-current heat exchanger 62 with tubes and calender through 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 60A of the 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 pipe 92, from this separator to the inlet of the part 60B 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.
- the temperature at the exit of the natural gas regasifier is of the order of 0 ° C. and that of the methanol is approximately -70 ° C.
- 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 of the LNG into the regasifier in the gas phase.
- the central 102 is supplied with air through a path 104 and natural gas via a path 106, this path being able to be a bypass of the pipe 36 described previously.
- the combustion of the air-natural gas mixture within the turbine generates, after recovery of the generated calories (abbreviated to HRSG), at the outlet 108 of the fumes with temperatures of the order of 130 ° C.
- HRSG generated calories
- these fumes are introduced through an inlet 110 in a heat exchanger assembly 112, separated into at least three parts 112A, 112B, 112C, to emerge by an evacuation 114 and then be directed by a conduit 116 to any suitable means, such as a fireplace.
- 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.
- a pipe 130 called liquid pipe
- a pipe 132 called gas line
- a line 134 brings the propane in gaseous form pressurized to an expansion turbine 136 rotatably connected to all energy producing means, such as an alternator 138.
- the propane gas is supplied by a pipe 140 to a heat exchanger 142, said condenser, for cooling the propane gas and thus change phase to obtain a liquid phase before it returns through a pipe 144 to the tank 120.
- 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.
- the 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 gaseous form in the separator to achieve 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.
- 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.
- the liquid propane is stored in the tank 120.
- the treatment group as schematically illustrated on the figure 7 shows a potential use of the LNG regasification facility with a methanol loop to capture and liquefy the CO 2 contained in releases, such as fumes from gas turbine fumes.
- an LNG regasification unit 146 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 coming from the pipe 34.
- CO 2 capture / separation unit. 148 comprises an absorption column 154 containing transfer elements 156 with an entry 158 of methanol from the regasifier, an entry of a gaseous fluid 160 containing CO 2 , an evacuation 162 of gaseous fluid stripped of CO 2 and an exit 164 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 to the figures 1 and 2 , that is to say a heater traversed by the methanol coming from, in the illustrated example of the figure 7 from the outlet 170 of the flask 166 by a reheating 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 by 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.
- an intermediate fluid such as ethane
- 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 pipe 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.
- the ethane vapor is introduced into the upper ethane condenser 186 through an inlet 198 located on the upper part of the condenser, through this condenser to result in a liquid ethane outlet 200 located in the lower part 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.
- the LNG substantially follows the same regime as that described in relation to the figure 1 with the only difference that a bypass of the LNG line 34 leads to the inlet 192 of the CO 2 liquefaction unit 150 to pass through the upper condenser 186 and exit through the outlet 194 to join the line 36.
- 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.
- 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 -freeed fluid is discharged through the outlet 162 to any appropriate means.
- the mixture of CO 2 and methanol is separated in the expansion flask 166 from which the CO 2 in the 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.
- the residual CO 2 contained in the methanol is separated once more from this methanol in the expansion tank 175.
- the CO 2 is evacuated 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.
Abstract
Description
La présente invention se rapporte à une installation de regazéification de gaz naturel liquéfié et à un procédé utilisé dans une telle installation.The present invention relates to a regasification plant for liquefied natural gas and a method used in such an installation.
Généralement, lorsque le gaz naturel doit être transporté entre un site de production et un site d'exploitation qui sont proches l'un de l'autre, ce transport s'effectue grâce à des pipelines terrestres ou submergés. Dans ce cas, le gaz naturel est transporté sous sa forme gazeuse et est utilisable en tant que tel sur son lieu de destination.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.
Cependant lorsque les deux sites sont trop éloignés l'un de l'autre ou que la configuration du terrain n'autorise pas la pose de pipelines, le gaz est transporté sous forme liquéfiée par véhicules terrestres ou bateaux (généralement des méthaniers) entre le site de production et le site d'exploitation. Pour cela le gaz naturel est liquéfié à proximité du site de production lors d'opérations de compression et de refroidissement jusqu'à une température de -160°C. Le gaz naturel liquéfié (GNL) est ensuite stocké dans des citernes appropriées puis transvasé sous forme liquide dans des cuves pour son transport terrestre ou maritime vers le site d'exploitation. Une fois arrivé sur ce site, ce gaz liquéfié est déchargé dans des réservoirs de stockage de GNL à partir desquels ce gaz peut être regazéifié à la demande et utilisé, soit directement sur le site d'exploitation, soit transporté sous forme gazeuse par des pipelines vers d'autres lieux d'exploitation.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, 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 in liquid form into tanks for land or sea transport to the operating site. 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 site of operation or transported in gaseous form via pipelines. to other places of exploitation.
Habituellement, dans le cas de transport maritime de GNL, le gaz liquéfié est conservé puis transporté jusqu'au voisinage du terminal côtier dans des cuves isothermes du méthanier. Ce gaz liquéfié est soit regazéifié à partir des cuves du méthanier puis transporté sous forme gazeuse par des pipelines vers les lieux d'exploitation, soit envoyé sous forme liquide dans des réservoirs du terminal côtier pour y être stocké et être regazéifié à la demande.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 tanker 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.
Actuellement, pour réaliser l'opération de regazéification, le gaz sous forme liquide est pompé à partir de la cuve ou du réservoir puis traverse un ensemble d'échangeurs de chaleur faisant office de vaporisateur ou de regazéificateur. De façon à assurer un échange de chaleur, cet ensemble d'échangeurs de chaleur est traversé par de l'eau de mer, éventuellement réchauffée, de manière à ce que les calories présentes dans cette eau soient transmises au gaz. Grâce à la transmission de ces calories, le gaz est réchauffé tout au long de son cheminement dans l'ensemble d'échangeurs et change progressivement d'état pour ressortir de cet ensemble d'échangeurs sous forme gazeuse.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.
Il est également connu par la demande de brevet
De telles dispositions présentent des inconvénients non négligeables tant au niveau de la préservation de la nature que de l'intégrité des échangeurs.Such provisions have significant disadvantages both in terms of nature preservation and the integrity of the exchangers.
En effet, l'eau de mer qui a traversé les échangeurs de chaleur est rejetée dans la mer en ayant une température très basse, ce qui entraîne une dégradation de la flore et de la faune sous-marine. Par ailleurs, l'eau de mer est un agent corrosif pour toutes les parties métalliques des échangeurs et entraîne donc une maintenance plus importante de ces échangeurs. De plus, compte tenu du fait que le GNL circule dans les échangeurs avec une température très basse, l'eau de mer doit parcourir ces échangeurs avec un grand débit de manière à éviter de former des cristaux, ce qui nécessite des installations de pompage de grande taille avec un coût élevé.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 the fact that LNG circulates in the exchangers with a very low temperature, the seawater must travel these exchangers with a large flow rate so as to avoid forming crystals, which necessitates pumping installations. large size with a high cost.
La présente invention se propose de remédier aux inconvénients mentionnés ci-dessus grâce à une installation de regazéification qui utilise un agent caloporteur permettant de respecter l'environnement et qui peut être utilisée loin de tous terminaux côtiers.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.
Ainsi, la présente invention concerne une installation de regazéification de gaz naturel liquéfié telle que définie par la revendication 1.Thus, the present invention relates to a regasification plant of liquefied natural gas as defined by claim 1.
L'installation peut comprendre une unité de réchauffage de l'agent caloporteur.The installation may comprise a heating unit of the heat transfer agent.
De manière avantageuse, l'unité de réchauffage peut être parcourue par de l'air.Advantageously, the reheating unit can be traversed by air.
L'agent caloporteur peut posséder une température de cristallisation comprise entre -90° C et -150° C.The heat transfer agent may have a crystallization temperature of between -90 ° C. and -150 ° C.
De manière préférentielle, l'agent caloporteur peut être un alcool comme du méthanol, de l'éthanol ou du propanol.Preferably, the heat transfer agent may be an alcohol such as methanol, ethanol or propanol.
L'un des échangeurs peut être à co-courant entre le GNL et l'agent caloporteur et l'autre des échangeurs peut être à contre courant.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.
L'échangeur à contre-courant peut être en deux parties entre lesquelles est intercalé un séparateur de phase.The countercurrent exchanger may be in two parts between which is interposed a phase separator.
Au moins l'échangeur à contre courant peut être du type à plaques et ailettes brasées.At least the countercurrent exchanger may be of the type with brazed plates and fins.
Le circuit de circulation de l'agent caloporteur peut comprendre un échangeur de chauffage additionnel.The circulation circuit of the heat transfer agent may comprise an additional heat exchanger.
L'installation peut comprendre des moyens de liquéfaction d'un hydrocarbure par échange calorifique avec l'agent caloporteur.The installation may comprise means for liquefying a hydrocarbon by heat exchange with the heat transfer medium.
L'hydrocarbure peut être sous forme gazeuse après son application à l'entraînement d'une turbine.The hydrocarbon can be in gaseous form after its application to driving a turbine.
Avantageusement, l'hydrocarbure peut être du propane.Advantageously, the hydrocarbon may be propane.
L'installation peut également comprendre des moyens de piégeage de CO2 par l'agent caloporteur.The installation may also include means for trapping CO 2 by the heat transfer medium.
Préférentiellement, l'agent caloporteur peut être utilisé en tant que solvant du CO2.Preferably, the heat transfer agent may be used as a CO 2 solvent.
Les autres caractéristiques et avantages de l'invention apparaîtront mieux à la lecture de la description qui va suivre, donnée uniquement à titre illustratif et nullement limitatif, en se référant aux dessins annexés sur lesquels :
- la
figure 1 est une vue schématique de l'installation de regazéification du GNL selon l'invention ; - la
figure 2 est une vue en coupe partielle du réchauffeur utilisé dans l'installation selon l'invention ; - la
figure 3 est une vue en coupe schématique du regazéificateur utilisé dans cette installation ; - la
figure 4 est une première variante de l'installation de regazéification selon l'invention ; - la
figure 5 est une autre variante de l'installation de regazéification selon l'invention ; - la
figure 6 montre un exemple sur une utilisation particulière de l'installation selon l'invention et - la
figure 7 montre un autre exemple d'une utilisation de l'installation selon l'invention.
- the
figure 1 is a schematic view of the regasification plant of LNG according to the invention; - the
figure 2 is a partial sectional view of the heater used in the installation according to the invention; - the
figure 3 is a schematic sectional view of the regasifier used in this installation; - the
figure 4 is a first variant of the regasification plant according to the invention; - the
figure 5 is another variant of the regasification plant according to the invention; - the
figure 6 shows an example of a particular use of the installation according to the invention and - the
figure 7 shows another example of a use of the installation according to the invention.
La
L'agent caloporteur est un fluide organique dont le point de cristallisation se rapproche de celui du GNL et a une viscosité suffisamment faible pour pouvoir être amené à circuler facilement dans des conduites même à des températures très basses. De plus, cet agent reste à l'état liquide en condition d'utilisation à la pression atmosphérique et à la température ambiante. Préférentiellement, cet agent caloporteur peut être un alcool ou un hydrocarbure ou un de leurs composés. Dans la suite de la description, le fluide organique considéré à titre d'exemple est du méthanol dont le point de cristallisation est situé aux environs de -98° C mais il peut aussi être utilisé d'autres alcools comme l'éthanol (point de cristallisation : - 114°C) ou du propanol (point de cristallisation : - 126°C).The coolant is an organic fluid whose crystallization point is close to that of LNG and has a viscosity sufficiently low to be able to 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).
Cette installation comprend une boucle de circulation 16 de l'agent caloporteur qui, dans l'exemple montré, est une boucle fermée avec une partie chaude et une partie froide. Cette boucle comprend une pompe de circulation 18, une conduite de circulation 20 de cet agent entre la pompe et le regazéificateur 12, une conduite de circulation 22 entre le regazéificateur et l'unité de réchauffage 14, une conduite de retour 24 entre cette unité de réchauffage et la pompe de circulation, un réservoir 26 d'agent caloporteur étant intercalé sur cette conduite de retour. L'installation comporte également une pompe d'aspiration 28 du GNL généralement immergée dans le réservoir 10, une conduite de circulation 30 du GNL entre cette pompe et une pompe de circulation 32, une conduite 34 amenant le GNL de cette pompe de circulation au regazéificateur 12, et une conduite de sortie 36 destinée à convoyer le gaz sous forme gazeuse sortant du regazéificateur vers tous moyens appropriés. L'unité de réchauffage est également parcourue par un fluide de réchauffage 38 qui est, dans l'exemple illustré, de l'air extérieur à température ambiante et comporte une évacuation 40 des condensats provenant de cet air. Bien entendu, cet air de réchauffage peut aussi provenir de tous appareils présents sur le lieu d'exploitation, comme les fumées rejetées par une turbine à gaz.This installation comprises a
Pour réaliser la regazéification, le GNL est pompé du réservoir 10 par les pompes 28 et 32, circule dans les conduites 30 et 34 pour être envoyé dans le regazéificateur 12. Ce gaz circule dans le regazéificateur qui est également parcouru par le méthanol en tant qu'agent caloporteur. Pour ce faire, le méthanol présent dans le réservoir 26 est pompé par la pompe 18 et est envoyé par la conduite 20 dans le regazéificateur 12. Dans ce regazéificateur, les calories présentes dans le méthanol sont transmises au GNL et le réchauffent de manière à ce que la phase liquide du GNL soit changée en une phase gazeuse par vaporisation puis, si nécessaire, surchauffée pour atteindre une température voisine de celle de la température ambiante.To perform the regasification, the LNG is pumped from the
La température du méthanol à l'entrée du regazéificateur 12 est d'environ 20 °C et d'environ -160 °C pour le GNL circulant dans la conduite 34. A la sortie de ce regazéificateur, le gaz naturel est à une température voisine de 5 °C alors que le méthanol atteint une température d'environ -70 °C à la sortie de ce regazéificateur dans la conduite 22.The temperature of the methanol at the inlet of the
Durant l'échange dans le regazéificateur, le méthanol est refroidi à une température supérieure à son point de cristallisation, en l'occurrence -70 °C pour l'exemple considéré. Le méthanol froid est envoyé par la conduite 22 à l'unité de réchauffage 14 de façon à ce que l'air qui circule dans cette unité, et dont la température est supérieure à celle du méthanol froid, échange ses calories avec ce méthanol pour obtenir un méthanol réchauffé dans la conduite 24 et conséquemment dans le réservoir 26.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
La température du méthanol à l'entrée de l'unité de réchauffage est de l'ordre de -70 °C alors que l'air est introduit dans ce réchauffeur à une température voisine de 30 °C. Après échange calorifique dans cette unité, le méthanol est évacué à la sortie de l'unité à une température voisine de 0 °C alors que l'air en sort à une température voisine de 5 °C.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 of about 30 ° C. After heat exchange in this unit, the methanol is discharged at the outlet of the unit at a temperature of 0 ° C while the air leaves at a temperature of 5 ° C.
Ainsi, la partie chaude de la boucle 16 est formée par la conduite 24, le réservoir 26, la pompe 18 et la conduite 20, alors que la partie froide de cette boucle comprend la conduite 22.Thus, the hot part of the
Pour réaliser le réchauffage du méthanol à la sortie du regazéificateur, et comme cela est illustré sur la
En se rapportant maintenant à la
Dans la variante représentée à titre d'exemple sur la
Préférentiellement, l'échangeur à tubes et calandre comprend un joint mécanique d'expansion 83 qui absorbe toutes les variations dimensionnelles de cet échangeur lors du passage du GNL et du méthanol.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.
Dans cette variante, le fonctionnement de l'installation est identique à celui décrit en relation avec les
On se reporte maintenant à la
Cette variante se distingue par le fait que la regazéification se réalise en plusieurs étapes. De plus, l'échangeur à contre-courant 60 est en deux parties 60A, 60B et qu'il est prévu un séparateur de phases 84 placé entre ces deux parties d'échangeur.This variant is distinguished by the fact that regasification is carried out in several stages. In addition, the
Le gaz naturel sortant de l'échangeur à co-courant 62 à tubes et calandre par la sortie 70 est préchauffé à son point d'ébullition correspondant à la pression dans le séparateur 84. Ce gaz naturel liquide chauffé traverse la partie basse 60A de l'échangeur à contre courant 60 pour réaliser une transformation de phase par vaporisation. Ce gaz naturel transformé est envoyé par une conduite 86 dans le séparateur 84 où a lieu la séparation du gaz naturel sous forme gazeuse en partie haute 88 de ce séparateur avec une composition, un poids moléculaire et un pouvoir calorifique inférieur et sous forme liquide en partie basse 90 de ce séparateur. Le gaz naturel sous forme vapeur présent dans le séparateur est ensuite dirigé, par une conduite 92, de ce séparateur vers l'entrée de la partie 60B de l'échangeur 60 où il subit, par échange avec le méthanol qui y circule, une élévation de température jusqu'à la sortie 80. La phase liquide, qui a un poids moléculaire et un pouvoir calorifique supérieurs à celui de la vapeur, est extraite par une pompe 94 reliée à ce séparateur par une conduite 96. La phase liquide sortant de la pompe 94 est dirigée par une conduite 98 vers tous moyens de stockage pour y être ensuite traitée. Avantageusement, il est possible de contrôler la composition et le pouvoir calorifique du gaz naturel sous forme gazeuse dans la conduite 92 avant qu'il pénètre dans l'échangeur 60 en y injectant une quantité prédéterminée de liquide provenant du séparateur par une conduite 98A prenant naissance après la pompe 94 sur la conduite 98 et aboutissant sur la conduite 92.The natural gas exiting the
Dans cette configuration, la température à la sortie du regazéificateur du gaz naturel est de l'ordre de 0°C et celle du méthanol est d'environ de -70 °C.In this configuration, the temperature at the exit of the natural gas regasifier is of the order of 0 ° C. and that of the methanol is approximately -70 ° C.
Additionnellement, il est envisageable de chauffer le méthanol à la sortie de la pompe 18 en plaçant sur la conduite 20 un échangeur de chaleur 100 entre le méthanol et un fluide chaud qui est habituellement utilisé sur ou à proximité de cette installation de regazéification, comme de l'eau chaude provenant de tours à ruissellement.Additionally, it is conceivable to heat the methanol at the outlet of the
Comme précédemment décrit, le méthanol à la sortie du regazéificateur est à basse température de l'ordre de -70 °C et doit être réchauffé pour pouvoir assurer la transformation en phase gazeuse du GNL dans le regazéificateur. Pour cela, il peut être tiré profit de la présence sur le site d'une centrale électrique avec une turbine à gaz à cycle combiné comme cela est illustré sur la
En fonctionnement, le propane sous forme liquide est pompé du réservoir 120 pour traverser la partie 112A de l'ensemble échangeur 112. Après cette traversée, le propane préchauffé sous forme liquide est envoyé dans le séparateur 126. La phase liquide extraite de ce séparateur traverse la partie 112B de l'ensemble 112 pour retourner sous forme quasi gazeuse dans le séparateur pour réaliser la séparation entre la phase liquide et la phase gazeuse du propane. La phase gazeuse contenue dans ce séparateur est également extraite pour traverser la partie 112C de l'ensemble échangeur 112 pour y être totalement transformée en phase gazeuse et surchauffée si nécessaire. Le propane sous forme gazeuse traverse la turbine 136 qu'il entraîne en rotation, laquelle turbine entraîne en rotation l'alternateur 138. A la sortie de la turbine, le propane sous forme gazeuse traverse le condenseur 142 où il change de phase et passe en phase liquide grâce à l'échange de ses calories avec le méthanol froid qui circule également dans ce condenseur. A la sortie de ce condenseur, le propane liquide est stocké dans le réservoir 120.In operation, the propane in liquid form is pumped from the
Le groupe de traitement tel que schématiquement illustré sur la
Dans cette configuration, il est prévu une unité de regazéification 146 de GNL, une unité de capation/séparation du CO2 148, une unité de réchauffage 149 du méthanol et une unité 150 de liquéfaction du CO2.In this configuration, there is provided an
L'unité de regazéification 146, comme déjà décrite en relation avec les figures précédentes, comprend un regazéificateur 12 parcouru par du méthanol chaud circulant dans une boucle 152 et par du GNL provenant de la conduite 34.The
L'unité de captation/séparation du CO2. 148 comprend une colonne à absorption 154 contenant des éléments de transfert 156 avec une entrée 158 de méthanol issu du regazéificateur, une entrée d'un fluide gazeux 160 contenant du CO2, une évacuation 162 de fluide gazeux débarrassé du CO2 et une sortie 164 d'un mélange de méthanol et de CO2. Cette unité de captation/séparation du CO2 comprend également un ballon de détente 166 avec une arrivée du mélange de méthanol et de CO2, une sortie 168 de CO2 sous forme gazeuse et une sortie 170 de méthanol débarrassé d'une très grande partie de CO2.CO 2 capture / separation unit. 148 comprises an
L'unité de réchauffage 149 comprend des éléments identiques à ceux déjà décrit en relation avec les
L'unité de liquéfaction 150 comprend un condenseur 181 qui a la particularité d'utiliser un fluide intermédiaire, comme de l'éthane, pour participer à la liquéfaction du CO2 et au chauffage du gaz naturel sous forme vapeur.The
Ce condenseur comprend une enceinte 182 qui contient au moins deux parties de condenseurs 184 et 186, chacun à contre-courant et préférentiellement sous forme de plaques et ailettes brasées en aluminium, dans lesquels circulent le CO2 sous forme vapeur et l'éthane pour l'une et le GNL et l'éthane pour l'autre. Le condenseur inférieur 184 est placé en partie basse de l'enceinte et comprend, sur l'un de ses côtés et dans la partie haute de ce condenseur, une entrée 188 du CO2 connectée à la conduite 180 et une sortie de CO2 liquide 190 sur la partie basse du condenseur. Le condenseur supérieur 186 comprend une entrée 192 de GNL, connectée à la conduite 34 de GNL, qui est située en partie basse de ce condenseur et une sortie 194 placée en partie haute de l'échangeur. Une boucle fermée d'éthane 196 permet à l'éthane de circuler entre les deux échangeurs. Plus précisément, l'éthane vapeur est introduit dans le condenseur d'éthane supérieur 186 par une entrée 198 située sur la partie haute du condenseur, traverse ce condenseur pour aboutir à une sortie d'éthane liquide 200 située en partie basse de ce condenseur, est amené par une conduite 202 à une entrée d'éthane liquide 204 localisée en partie basse du condenseur de CO2 inférieur, traverse le condenseur inférieur pour aboutir à une sortie 206 située en partie haute de ce condenseur puis aboutit à l'entrée 198 par une conduite 208.This condenser comprises an
Lors du fonctionnement du groupe de traitement décrit ci-dessus, le GNL suit sensiblement le même régime que celui décrit en relation avec la
En sortie du regazéificateur, le méthanol est envoyé par l'entrée 158 dans la colonne 156 qui reçoit également un fluide contenant une partie non négligeable de CO2, de l'ordre de 12%, par l'entrée 160. Après traitement dans cette colonne, le CO2 est capté par le méthanol et un mélange de méthanol et de CO2 dissout est évacué par la sortie 164. Le fluide débarrassé du CO2 est évacué par la sortie 162 vers tous moyens appropriés. Le mélange de CO2 et de méthanol subit une séparation dans le ballon de détente 166 d'où le CO2 en phase vapeur est évacué par la sortie 168 vers la conduite 180 et d'où le méthanol en phase liquide issu de la sortie 170 est chauffé dans l'unité de réchauffage par traversée successive du réchauffeur et de l'échangeur 174. A la sortie de l'échangeur 174, le CO2 résiduel contenu dans le méthanol est séparé encore une fois de ce méthanol dans le ballon de détente 175. Lors de cette séparation, le CO2 est évacué par la sortie 178 pour rejoindre la conduite 180 connectée à la sortie 168 et le méthanol débarrassé du CO2 rejoint, par la sortie 176, la pompe 18 de la boucle de méthanol. Le CO2 en phase vapeur est liquéfiée dans le condenseur inférieur 184 dans lequel il échange ses calories avec l'éthane qui circule en boucle entre les deux condenseurs. Après cet échange, le CO2 est sous forme liquide à la sortie 190 et il est peut être envoyé vers un réservoir de stockage d'où il pourra être retiré pour être éventuellement séquestré dans des réservoirs souterrains.At the outlet of the regasifier, the methanol is sent via the
Claims (11)
- A liquefied natural gas (LNG) regasification plant comprising a tank (10) for storing the gas in liquefied form and an LNG regasification device (12) through which a heat carrier and the natural gas flow, a loop circuit (16) in which the heat carrier that circulates is methanol, ethanol or propanol, the regasification device (12) comprising at least two exchangers (60, 62), characterized in that one (62) of the exchangers is co-current between the LNG and the heat carrier, and in that the other (60) exchanger is counter-current, exchanger (60) being in two parts (60A, 60B) between which a phase separator (84) is interposed.
- A regasification plant as claimed in claim 1, characterized in that it comprises a heat carrier heating unit (14).
- A regasification plant as claimed in claim 2, characterized in that air flows through heating unit (14).
- A regasification plant as claimed in any one of the previous claims, characterized in that the heat carrier has a crystallization temperature ranging between -90°C and -150°C.
- A regasifcation plant as claimed in any one of the previous claims, characterized in that at least counter-current exchanger (60) is of brazed plate-fin exchanger type.
- A regasification plant as claimed in any one of the previous claims, characterized in that heat carrier circulation circuit (16) comprises an additional heating exchanger (100).
- A regasification plant as claimed in any one of the previous claims, characterized in that it comprises means for liquefying a hydrocarbon by calorific exchange with the heat carrier.
- A regasification plant as claimed in claim 7, characterized in that the hydrocarbon is in gaseous form after being used for driving a turbine (136).
- A regasification plant as claimed in claim 7 or 8, characterized in that the hydrocarbon is propane.
- A regasification plant as claimed in any one of claims I to 6, characterized in that it comprises means for CO2 trapping by the heat carrier.
- A regasification plant as claimed in claim 10, characterized in that the heat carrier is used as solvent of the CO2.
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
FR0501646A FR2882129A1 (en) | 2005-02-17 | 2005-02-17 | LIQUEFIED NATURAL GAS REGASIFICATION INSTALLATION |
PCT/FR2006/000318 WO2006087452A1 (en) | 2005-02-17 | 2006-02-13 | Plant for regasification of liquefied natural gas |
Publications (2)
Publication Number | Publication Date |
---|---|
EP1853846A1 EP1853846A1 (en) | 2007-11-14 |
EP1853846B1 true EP1853846B1 (en) | 2012-04-11 |
Family
ID=35004364
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
EP06709300A Not-in-force EP1853846B1 (en) | 2005-02-17 | 2006-02-13 | Plant for regasification of liquefied natural gas |
Country Status (9)
Country | Link |
---|---|
US (1) | US20080302103A1 (en) |
EP (1) | EP1853846B1 (en) |
JP (1) | JP2008530472A (en) |
KR (1) | KR20070114167A (en) |
AT (1) | ATE553330T1 (en) |
ES (1) | ES2385575T3 (en) |
FR (1) | FR2882129A1 (en) |
PT (1) | PT1853846E (en) |
WO (1) | WO2006087452A1 (en) |
Families Citing this family (15)
Publication number | Priority date | Publication date | Assignee | Title |
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JP4677338B2 (en) * | 2005-12-15 | 2011-04-27 | 石油コンビナート高度統合運営技術研究組合 | Cold supply method |
CN103697326A (en) | 2006-09-11 | 2014-04-02 | 埃克森美孚上游研究公司 | Transporting and managing liquefied natural gas |
US20080120983A1 (en) * | 2006-11-04 | 2008-05-29 | Dirk Eyermann | System and process for reheating seawater as used with lng vaporization |
US20080178611A1 (en) * | 2007-01-30 | 2008-07-31 | Foster Wheeler Usa Corporation | Ecological Liquefied Natural Gas (LNG) Vaporizer System |
FR2929369A1 (en) * | 2008-03-27 | 2009-10-02 | Air Liquide | METHOD FOR VAPORIZING A CRYOGENIC LIQUID BY EXCHANGING HEAT WITH A CALORIGENE FLUID |
FR2931222B1 (en) * | 2008-05-16 | 2014-02-21 | Batignolles Tech Therm | SYSTEM AND METHOD FOR VAPORIZING A CRYOGENIC FLUID, IN PARTICULAR LIQUEFIED NATURAL GAS, BASED ON CO2 |
FR2952161B1 (en) * | 2009-11-03 | 2012-01-13 | Gea Batignolles Technologies Thermiques | SYSTEM FOR VAPORIZING A CRYOGENIC FLUID WITH CENTRALIZED EXCHANGERS |
NO331474B1 (en) * | 2009-11-13 | 2012-01-09 | Hamworthy Gas Systems As | Installation for gasification of LNG |
US8707730B2 (en) * | 2009-12-07 | 2014-04-29 | Alkane, Llc | Conditioning an ethane-rich stream for storage and transportation |
DE102010056581B4 (en) * | 2010-12-30 | 2013-04-04 | Gea Batignolles Technologies Thermiques | Arrangement for the evaporation of liquid natural gas |
US9903232B2 (en) * | 2011-12-22 | 2018-02-27 | Ormat Technologies Inc. | Power and regasification system for LNG |
EP2708794A1 (en) * | 2012-09-13 | 2014-03-19 | Air Liquide Deutschland GmbH | Method and conditioning device for the discontinuous provision of liquid carbon dioxide |
NO20151639A1 (en) * | 2015-12-01 | 2017-06-02 | Waertsilae Gas Solutions Norway As | A plant and method for regasification of LNG |
CN107560321B (en) * | 2017-09-15 | 2023-04-25 | 长江大学 | BOG recovery and nitrogen liquefaction system and technological method |
CN111188996B (en) * | 2020-02-12 | 2024-03-19 | 中海石油气电集团有限责任公司 | Low-temperature waste heat recovery device of LNG receiving station submerged combustion type gasifier |
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US3410339A (en) * | 1964-05-18 | 1968-11-12 | Cornell Res Foundation Inc | Direct contact heat transfer apparatus having evaporator and condensing means |
US3364685A (en) * | 1965-03-31 | 1968-01-23 | Cie Francaise D Etudes Et De C | Method and apparatus for the cooling and low temperature liquefaction of gaseous mixtures |
FR1551859A (en) * | 1967-01-23 | 1969-01-03 | ||
US3479832A (en) * | 1967-11-17 | 1969-11-25 | Exxon Research Engineering Co | Process for vaporizing liquefied natural gas |
FR2187702B1 (en) * | 1972-06-13 | 1976-11-12 | Nuovo Pignone Spa | |
NO158058C (en) * | 1978-07-17 | 1988-07-06 | Dut Pty Ltd | PROCEDURE FOR THE PREPARATION OF GAS-FORMED AND CONDENSED DEHYDRATED HYDROCARBON PRODUCTS BY METHANOLY ADDITION, COOLING AND SEPARATION. |
US4331129A (en) * | 1979-07-05 | 1982-05-25 | Columbia Gas System Service Corporation | Solar energy for LNG vaporization |
US4437312A (en) * | 1981-03-06 | 1984-03-20 | Air Products And Chemicals, Inc. | Recovery of power from vaporization of liquefied natural gas |
US4372124A (en) * | 1981-03-06 | 1983-02-08 | Air Products And Chemicals, Inc. | Recovery of power from the vaporization of natural gas |
JP3372277B2 (en) * | 1992-11-11 | 2003-01-27 | 三菱重工業株式会社 | Method for producing liquefied carbon dioxide by LNG refrigeration |
US5417074A (en) * | 1993-07-26 | 1995-05-23 | Air Products And Chemicals, Inc. | Liquid nitrogen immersion/impingement freezing method and apparatus |
US5681360A (en) * | 1995-01-11 | 1997-10-28 | Acrion Technologies, Inc. | Landfill gas recovery |
TW432192B (en) * | 1998-03-27 | 2001-05-01 | Exxon Production Research Co | Producing power from pressurized liquefied natural gas |
MXPA02000764A (en) * | 1999-07-22 | 2002-07-22 | Bechtel Corp | A method and apparatus for vaporizing liquid gas in a combined cycle power plant. |
US6813893B2 (en) * | 2001-12-19 | 2004-11-09 | Conversion Gas Imports, L.L.C. | Flexible natural gas storage facility |
EP1478875B1 (en) * | 2002-02-27 | 2009-07-22 | Excelerate Energy Limited Partnership | Method and apparatus for the regasification of lng onboard a carrier |
JP3628309B2 (en) * | 2002-05-21 | 2005-03-09 | 川崎重工業株式会社 | Carbon dioxide liquefaction equipment using LNG cold energy |
-
2005
- 2005-02-17 FR FR0501646A patent/FR2882129A1/en not_active Withdrawn
-
2006
- 2006-02-13 JP JP2007555662A patent/JP2008530472A/en not_active Ceased
- 2006-02-13 EP EP06709300A patent/EP1853846B1/en not_active Not-in-force
- 2006-02-13 PT PT06709300T patent/PT1853846E/en unknown
- 2006-02-13 ES ES06709300T patent/ES2385575T3/en active Active
- 2006-02-13 KR KR1020077021367A patent/KR20070114167A/en not_active Application Discontinuation
- 2006-02-13 WO PCT/FR2006/000318 patent/WO2006087452A1/en active Application Filing
- 2006-02-13 AT AT06709300T patent/ATE553330T1/en active
- 2006-02-13 US US11/816,288 patent/US20080302103A1/en not_active Abandoned
Also Published As
Publication number | Publication date |
---|---|
WO2006087452A1 (en) | 2006-08-24 |
PT1853846E (en) | 2012-07-12 |
ATE553330T1 (en) | 2012-04-15 |
KR20070114167A (en) | 2007-11-29 |
JP2008530472A (en) | 2008-08-07 |
FR2882129A1 (en) | 2006-08-18 |
EP1853846A1 (en) | 2007-11-14 |
ES2385575T3 (en) | 2012-07-26 |
US20080302103A1 (en) | 2008-12-11 |
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