US20080302103A1 - Liquefied Natural Regasification Plant - Google Patents

Liquefied Natural Regasification Plant Download PDF

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Publication number
US20080302103A1
US20080302103A1 US11/816,288 US81628806A US2008302103A1 US 20080302103 A1 US20080302103 A1 US 20080302103A1 US 81628806 A US81628806 A US 81628806A US 2008302103 A1 US2008302103 A1 US 2008302103A1
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heat carrier
regasification
plant
regasification plant
methanol
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Ari Minkkinen
Alexandre Rojey
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IFP Energies Nouvelles IFPEN
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IFP Energies Nouvelles IFPEN
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Assigned to INSTITUT FRANCAIS DU PETROLE reassignment INSTITUT FRANCAIS DU PETROLE ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: MINKKINEN, ARI, ROJEY, ALEXANDRE
Publication of US20080302103A1 publication Critical patent/US20080302103A1/en
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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
    • 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
    • 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
    • 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
    • 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
    • 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
    • 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
    • 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
    • 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
    • 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
    • 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
    • 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
    • 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
    • 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
    • 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
    • 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
    • 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
    • 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 liquefied natural gas regasification plant and to a method used in same.
  • the gas is transported in liquefied form by land vehicle or by boat (generally LNG carriers) between the production site and the exploitation site.
  • the natural gas is therefore liquefied in the vicinity of the production site during compression and cooling operations to a temperature of ⁇ 160° C.
  • the liquefied natural gas (LNG) is thereafter stored in suitable tanks, then transferred in liquid form to tanks for ground transportation or shipping to the exploitation site. Once on this site, this liquefied gas is unloaded into LNG storage tanks from which this gas can be regasified on demand and used either directly on the exploitation site or transported in gaseous form through pipelines to other exploitation sites.
  • the liquefied gas is stored, then transported in the vicinity of the shore terminal in isothermal tanks of the LNG carrier.
  • This liquefied gas is either regasified from the LNG carrier tanks, then transported in gaseous form through pipelines to exploitation sites, or sent in liquid form to tanks of the shore terminal where they are stored and regasified on demand.
  • the gas in liquid form is pumped from the tank, then it flows through a set of heat exchangers acting as vaporizers or regasifiers.
  • seawater possibly heated, is sent through this set of heat exchangers so that the calories present in this water are transmitted to the gas. This calories transmission allows the gas to be heated as it progresses through the set of exchangers, it progressively changes state and leaves the set of exchangers in gaseous form.
  • seawater that has passed through the heat exchangers is discharged at sea at a very low temperature, which causes degradation of the submarine flora and fauna.
  • seawater is a corrosive agent towards all the metallic parts of the exchangers and it therefore requires closer maintenance of these exchangers.
  • the seawater has to flow through the exchangers with a high flow rate so as to prevent crystal formation, which requires large-size and expensive pumping facilities.
  • the present invention aims to overcome the aforementioned drawbacks by means of a regasification plant using a heat carrier allowing to respect the environment and that can be used far from shore terminals.
  • the present invention thus relates to a liquefied natural gas regasification plant comprising a tank for storing the gas in liquefied form and an LNG regasification device through which a heat carrier and the natural gas flow, characterized in that the plant comprises a loop circuit in which the heat carrier circulates in form of a low-viscosity and low-crystallization point organic fluid, and in that the regasification device comprises at least two exchangers.
  • the plant can comprise a heat carrier heating unit.
  • air can flow through the heating unit.
  • the heat carrier can have a crystallization temperature ranging between ⁇ 90° C. and ⁇ 150° C.
  • the heat carrier can be an alcohol such as methanol, ethanol or propanol.
  • One of the exchangers can be co-current between the LNG and the heat carrier and the other exchanger can be counter-current.
  • the counter-current exchanger can be in two parts between which a phase separator is interposed.
  • the heat carrier circulation circuit can comprise an additional heating exchanger.
  • the plant can comprise means for liquefying a hydrocarbon by calorific exchange with the heat carrier.
  • the hydrocarbon can be in gaseous form after being used for driving a turbine.
  • the hydrocarbon can be propane.
  • the plant can also comprise means for CO 2 trapping by the heat carrier.
  • the heat carrier can be used as solvent of the CO 2 .
  • FIG. 1 diagrammatically shows the LNG regasification plant according to the invention
  • FIG. 2 is a partial sectional view of the heater used in the plant according to the invention.
  • FIG. 3 is a diagrammatic sectional view of the regasifier used in this plant.
  • FIG. 4 is a first variant of the regasification plant according to the invention.
  • FIG. 6 shows an example of a particular use of the plant according to the invention.
  • FIG. 7 shows another example of a use of the plant according to the invention.
  • FIG. 1 diagrammatically shows a liquefied natural gas (LNG) regasification plant comprising a storage tank 10 for storing the LNG at atmospheric pressure and at a temperature close to ⁇ 160° C., a regasification device with a heat exchanger unit, or regasifier 12 , through which a heat carrier and the LNG from the tank flow, and a heat carrier heating unit 14 .
  • LNG liquefied natural gas
  • the heat carrier is an organic fluid whose crystallization point is close to that of the LNG and it has a viscosity that is low enough to be led to readily circulate in these pipes even at very low temperatures. Furthermore, this heat carrier remains in the liquid state under conditions of use at atmospheric pressure and at ambient temperature.
  • this heat carrier can be an alcohol or a hydrocarbon or one of their compounds.
  • the organic fluid considered by way of example is methanol whose crystallization point is approximately ⁇ 98° C., but it is also possible to use other alcohols such as ethanol (crystallization point: ⁇ 114° C.) or propanol (crystallization point: ⁇ 126° C.).
  • This plant comprises a heat carrier circulation loop 16 that, in the example shown, is a closed loop with a warm part and a cold part.
  • This loop comprises a circulation pump 18 , a line 20 for circulation of the heat carrier between the pump and regasifier 12 , a circulation line 22 between the regasifier and heating unit 14 , a return line 24 between this heating unit and the circulation pump, a heat carrier tank 26 being arranged on this return line.
  • the plant also comprises an LNG suction pump 28 generally immersed in tank 10 , a LNG circulation line 30 between this pump and a circulation pump 32 , a line 34 bringing the LNG from this circulation pump to regasifier 12 , and an outlet line 36 intended to carry the gas in gaseous form from the regasifier to any suitable means.
  • a heating fluid 38 that is, in the example illustrated, outside air at ambient temperature also flows through the heating unit comprising a line 40 for discharge of the condensates from this air.
  • this heating air can also come from any equipment present in the exploitation site, such as the fumes discharged by a gas turbine.
  • the LNG is pumped from tank 10 by pumps 28 and 32 , then it circulates in lines 30 and 34 to be sent to regasifier 12 .
  • This gas circulates in the regasifier through which the methanol used as heat carrier also flows.
  • the methanol present in tank 26 is therefore pumped by pump 18 and it is sent through line 20 to regasifier 12 .
  • the calories present in the methanol are transmitted to the LNG and heat it so that the liquid phase of the LNG is changed into a gas phase by vaporization then, if necessary, it is overheated to reach a temperature close to the ambient temperature.
  • the temperature of the methanol at the inlet of regasifier 12 is about 20° C. and the temperature of the LNG circulating in line 34 is about ⁇ 160° C.
  • the natural gas is at a temperature close to 5° C. whereas the methanol reaches a temperature of about ⁇ 70° C. at the outlet of this regasifier in line 22 .
  • the methanol is cooled to a temperature above its crystallization point, i.e. ⁇ 70° C. for the example considered.
  • the cold methanol is sent through line 22 to heating unit 14 so that the air circulating in this unit, whose temperature is higher than that of the cold methanol, exchanges its calories with this methanol to obtain a heated methanol in line 24 and, consequently, in tank 26 .
  • the temperature of the methanol at the heating unit inlet is of the order of ⁇ 70° C., whereas the air is fed into this heater at a temperature close to 30° C.
  • the methanol is discharged at the unit outlet at a temperature close to 0° C., whereas the air leaves the unit at a temperature close to 5° C.
  • the warm part of loop 16 is made up of line 24 , tank 26 , pump 18 and line 20 , whereas the cold part of this loop comprises line 22 .
  • heating unit 14 comprises a heat exchanger including a vertical shell 42 with an air inlet 44 and an air outlet 46 arranged at each end of this shell.
  • This shell houses a set of vertical tubes 48 connected, at one end thereof, by an intake manifold 50 to an inlet 52 for the cold methanol coming from the regasifier and, at the other end thereof, by a discharge manifold 54 to an outlet 56 linked to line 24 leading to methanol tank 26 .
  • the methanol flows in through inlet 52 , enters intake manifold 50 , circulates in all the vertical tubes 48 and ends in discharge manifold 54 prior to being discharged through outlet 56 .
  • air either at ambient temperature or heated by any known means, is fed into shell 42 through inlet 44 , then it scavenges all the tubes and the manifolds. During scavenging, the calories contained in this air are transmitted to the methanol so as to heat it and to obtain a warm methanol at outlet 56 . During this exchange, the water droplets contained in the air are condensed, then they fall through gravity at the bottom of shell 42 prior to being discharged in form of condensates through line 40 .
  • Tubes 48 can be coated with a hydrophobic material film (water shedding film) of polymethylsiloxane type to facilitate separation of the water droplets.
  • the regasifier comprises a vertical shell 58 that contains at least two exchangers in which the gas and the methanol circulate, an upper exchanger 60 arranged in the upper part of the shell and a lower exchanger 62 arranged in the lower part of this shell.
  • these exchangers are in form of brazed plate-fin exchangers, advantageously made of aluminium.
  • the upper exchanger referred to as counter-current exchanger because the natural gas and the methanol circulate in opposite directions whereas the lower exchanger is referred to as co-current exchanger, the fluids circulating in the same direction.
  • the lower exchanger comprises, on one of its sides and in the lower part thereof, a methanol inlet 64 connected to line 20 and an outlet 66 on one side of the exchanger.
  • This lower exchanger also comprises an inlet 68 , connected to LNG line 34 , which is located in the lower part and on the side opposite the methanol inlet, and an outlet 70 located in the upper part of the exchanger.
  • the methanol and LNG streams circulate in the same direction, i.e. from the bottom to the top of this exchanger.
  • the skin temperature within this exchanger therefore remains above ⁇ 100° C. and the exchange surfaces can be minimized.
  • Methanol outlet 66 is connected by a line 72 to an inlet 74 of the upper exchanger that is located in the upper part and on one side of this exchanger.
  • natural gas outlet 70 is connected by a line 76 to a gas inlet 78 located in the lower part of this exchanger.
  • the gas in vapour form is discharged through an outlet 80 located in the upper part of this exchanger whereas methanol outlet 82 is located in the lower part of this exchanger and connected to line 22 leading to the heating unit.
  • This exchanger is thus referred to as counter-current exchanger because the gas and methanol streams circulate in opposite directions, the gas from the bottom to the top of the exchanger and the methanol from the top to the bottom of the exchanger.
  • co-current exchanger 62 comes in form of a shell-and-tube exchanger, and it comprises inlets 64 , 68 and outlets 66 , 70 for methanol and LNG.
  • Outlets 66 and 70 are connected by lines 72 , 76 to counter-current exchanger 60 that is a brazed plate-fin exchanger, advantageously made of aluminium, comprising inlets 74 , 78 and outlets 82 , 80 for methanol and natural gas.
  • the shell-and-tube exchanger comprises a mechanical expansion joint 83 that absorbs all the dimensional variations of this exchanger as the LNG and the methanol flow therethrough.
  • FIG. 5 shows a variant of the regasification plant illustrated in FIG. 4 , which therefore comprises the same reference numbers for the common elements.
  • counter-current exchanger 60 is in two parts 60 A, 60 B and a phase separator 84 is provided between these two parts of the exchanger.
  • the natural gas leaving co-current shell-and-tube exchanger 62 through outlet 70 is preheated to its boiling point corresponding to the pressure in separator 84 .
  • This heated liquid natural gas flows through lower part 60 A of counter-current exchanger 60 to achieve a phase conversion through vaporization.
  • This converted natural gas is sent through a line 86 to separator 84 where separation of the natural gas in gaseous form occurs in upper part 88 of this separator with a lower composition, molecular weight and calorific value, and in liquid form in lower part 90 of this separator.
  • the natural gas in vapour form present in the separator is then sent, through a line 92 , from this separator to the inlet of part 60 B of exchanger 60 where it undergoes, by exchange with the methanol circulating therein, a temperature rise until it reaches outlet 80 .
  • the liquid phase whose molecular weight and calorific value are higher than that of the vapour, is extracted by a pump 94 connected to this separator by a line 96 .
  • the liquid phase leaving pump 94 is sent through a line 98 to any storage means prior to being treated.
  • the temperature of the natural gas at the regasifier outlet is of the order of 0° C.
  • the temperature of the methanol is about ⁇ 70° C.
  • a heat exchanger 100 for exchange between the methanol and a warm fluid that is commonly used in or close to this regasification plant, such as warm water from trickle towers.
  • the methanol at the regasifier outlet is at low temperature, of the order of ⁇ 70° C., and it has to be heated to provide conversion of the LNG to gas phase in the regasifier. It is therefore possible to take advantage of the presence on the site of an electric power plant with a combined cycle gas turbine as illustrated in FIG. 6 .
  • plant 102 is supplied with air through a channel 104 and with natural gas through a channel 106 ; this channel can be a bypass of line 36 described above. Combustion of the air-natural gas mixture within the turbine generates, after recovery of the calories generated (HRSG), at outlet 108 , fumes with temperatures of the order of 130° C. As shown in FIG.
  • these fumes are fed through an inlet 110 into a heat exchanger assembly 112 , divided into at least three parts 112 A, 112 B, 112 C, and leave through a discharge line 114 prior to being sent through a line 116 to any suitable means, such as a chimney.
  • a phase-change fluid such as propane also flows through the heat exchanger assembly and circulates in a closed loop 118 .
  • This loop comprises a liquid propane tank 120 , a circulation pump 122 connected to the tank by a line 124 and a propane phase separator 126 connected to the pump by a line 128 E carrying the liquid propane to part 112 A of the heat exchanger assembly and a line 128 S carrying the propane, preheated to its boiling point, into this separator.
  • a line 130 referred to as liquid line, wherein the liquid contained in the separator is brought to part 112 B of the heat exchanger assembly, then flows therethrough and flows back in gaseous form into separator 126
  • a line 132 referred to as gas line, that carries the gas phase of the propane contained in the separator to part 112 C of the heat exchanger assembly so as to overheat this propane gas.
  • a line 134 brings the propane in pressurized gaseous form to an expansion turbine 136 coupled in rotation to any energy producing means such as an alternator 138 .
  • the propane gas is sent through a line 140 to a heat exchanger 142 , referred to as condenser, in order to cool this propane gas and thus to cause a phase change so as to obtain a liquid phase before it flows back to tank 120 through a line 144 .
  • condenser a heat exchanger 142
  • the methanol circulating in line 22 flows through condenser 142 and, at the outlet of this condenser, the methanol is at a higher temperature than at the inlet because it has collected the calories contained in the propane in gas phase.
  • the propane in liquid form is pumped from tank 120 and flows through part 112 A of exchanger assembly 112 .
  • the preheated propane in liquid form is thereafter sent to separator 126 .
  • the liquid phase extracted from this separator flows through part 112 B of assembly 112 and flows back in nearly gaseous form into the separator for separation of the liquid phase and the gas phase of the propane.
  • the gas phase contained in this separator is also extracted to flow through part 112 C of exchanger assembly 112 to be totally converted to gas phase and overheated if necessary.
  • the propane in gaseous form flows through turbine 136 that it drives into rotation, said turbine driving alternator 138 into rotation.
  • the propane in gaseous form flows through condenser 142 where it undergoes phase change and changes to the liquid phase by exchanging its calories with the cold methanol that also circulates in this condenser.
  • the liquid propane is stored in tank 120 .
  • the treating group as diagrammatically shown in FIG. 7 shows a potential use of the LNG regasification plant with a methanol loop for collecting and liquefying the CO 2 contained in discharges, such as the fumes from gas turbines.
  • This configuration involves an LNG regasification plant 146 , a CO 2 collection/separation plant 148 , a methanol heating unit 149 and a CO 2 liquefaction unit 150 .
  • Regasification plant 146 comprises a regasifier 12 through which flow warm methanol circulating in a loop 152 and LNG coming from line 34 .
  • CO 2 collection/separation unit 148 comprises an absorption column 154 containing transfer elements 156 with an inlet 158 for the methanol from the regasifier, an inlet 160 for a CO 2 — containing gaseous fluid, an outlet 162 for a CO 2 -freed gaseous fluid and an outlet 164 for a mixture of ethanol and CO 2 .
  • This CO 2 collection/separation unit also comprises a flash drum 166 with an inlet for the methanol-CO 2 mixture, an outlet 168 for the CO 2 in gaseous form and an outlet 170 for the methanol freed of a very large part of the CO 2 .
  • Heating unit 149 comprises elements identical to those already described in connection with FIGS. 1 and 2 , i.e. a heater through which flow the methanol coming, in the example illustrated in FIG. 7 , from outlet 170 of drum 166 and a heating fluid 38 that can be outside air at ambient temperature.
  • This exchanger also comprises a discharge line 40 for the condensates from this outside air.
  • This unit finally comprises a heat exchanger 174 allowing to heat the methanol after its passage through the heater through an outlet 172 and a flash drum 175 allowing to separate the methanol in liquid form, which is then sent through a line 176 to the methanol loop, and the CO 2 in gaseous form that joins, through a line 178 , a line 180 also connecting CO 2 line 168 of flash drum 166 .
  • Liquefaction unit 150 comprises a condenser 181 whose specific feature is to use an intermediate fluid, such as ethane, to take part in the liquefaction of the CO 2 and in heating the natural gas in vapour form.
  • an intermediate fluid such as ethane
  • This condenser comprises an enclosure 182 that contains at least two condenser parts 184 and 186 , each one counter-current and preferably in form of brazed aluminium plates and fins, in which circulate the CO 2 in vapour form and the ethane for the first one and the LNG and the ethane for the second.
  • Lower condenser 184 is arranged in the lower part of the enclosure and comprises, on one side thereof and in the upper part of this condenser, a CO 2 inlet 188 connected to line 180 and a liquid CO 2 outlet 190 on the lower part of the condenser.
  • Upper condenser 186 comprises an LNG inlet 192 , connected to LNG line 34 , that is arranged in the lower part of this condenser and an outlet 194 arranged in the upper part of the exchanger.
  • a closed ethane loop 196 allows the ethane to circulate between the two exchangers.
  • the vapour ethane is fed into upper ethane condenser 186 through an inlet 198 located in the upper part of the condenser, flows through this condenser and ends at a liquid ethane outlet 200 arranged in the lower part of this condenser, is brought through a line 202 to a liquid ethane inlet 204 located in the lower part of the lower CO 2 condenser, flows through the lower condenser and reaches an outlet 206 in the upper part of this condenser, and eventually reaches inlet 198 through a line 208 .
  • the LNG substantially follows the same regime as described in connection with FIG. 1 , except that a bypass of LNG line 34 reaches inlet 192 of CO 2 liquefaction unit 150 and runs through upper condenser 186 , then through outlet 194 to join line 36 .
  • the methanol is sent through inlet 158 to column 156 that also receives a fluid containing a substantial part of CO 2 , of the order of 12%, through inlet 160 .
  • the CO 2 is collected by the methanol, and a mixture of methanol and of dissolved CO 2 is discharged through outlet 164 .
  • the CO 2 -freed fluid is discharged through outlet 162 to any suitable means.
  • the mixture of CO 2 and of methanol undergoes separation in flash drum 166 from which the CO 2 in vapour phase is discharged through outlet 168 to line 180 and the methanol in liquid phase from outlet 170 is heated in the heating unit by passing successively through the heater and exchanger 174 .
  • the residual CO 2 contained in the methanol is again separated from this methanol in flash drum 175 .
  • the CO 2 is discharged through outlet 178 to join line 180 connected to outlet 168 and the CO 2 -freed methanol joins, through outlet 176 , pump 18 of the methanol loop.
  • the CO 2 in vapour phase is liquefied in lower condenser 184 where it exchanges its calories with the ethane that circulates in a loop between the two condensers.
  • the CO 2 is in liquid form at outlet 190 and it can be sent to a storage tank from where it can be removed to be possibly sequestered in underground reservoirs.

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  • Engineering & Computer Science (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Filling Or Discharging Of Gas Storage Vessels (AREA)
  • Organic Low-Molecular-Weight Compounds And Preparation Thereof (AREA)
US11/816,288 2005-02-17 2006-02-13 Liquefied Natural Regasification Plant Abandoned US20080302103A1 (en)

Applications Claiming Priority (3)

Application Number Priority Date Filing Date Title
FR0501646A FR2882129A1 (fr) 2005-02-17 2005-02-17 Installation de regazeification de gaz naturel liquefie
FR0501646 2005-02-17
PCT/FR2006/000318 WO2006087452A1 (fr) 2005-02-17 2006-02-13 Installation de regazeification de gaz naturel liquefie

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EP (1) EP1853846B1 (ja)
JP (1) JP2008530472A (ja)
KR (1) KR20070114167A (ja)
AT (1) ATE553330T1 (ja)
ES (1) ES2385575T3 (ja)
FR (1) FR2882129A1 (ja)
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Cited By (10)

* Cited by examiner, † Cited by third party
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US20080178611A1 (en) * 2007-01-30 2008-07-31 Foster Wheeler Usa Corporation Ecological Liquefied Natural Gas (LNG) Vaporizer System
US20100313578A1 (en) * 2008-05-16 2010-12-16 Gea Batignolles Technologies Thermiques co2-based method and system for vaporizing a cryogenic fluid, in particular liquefied natural gas
US20110017429A1 (en) * 2008-03-27 2011-01-27 L'air Liquide Societe Anonyme Pour L'etude Et L'exploitation Des Procedes Georges Claude Method For Vaporizing Cryogenic Liquid Through Heat Exchange Using Calorigenic Fluid
US20110132033A1 (en) * 2009-12-07 2011-06-09 Alkane, Llc Conditioning an Ethane-Rich Stream for Storage and Transportation
US20120222430A1 (en) * 2009-11-13 2012-09-06 Hamworthy Gas Systems As Plant for regasification of lng
DE102010056581B4 (de) * 2010-12-30 2013-04-04 Gea Batignolles Technologies Thermiques Anordnung zur Verdampfung von flüssigem Erdgas
US20130160486A1 (en) * 2011-12-22 2013-06-27 Ormat Technologies Inc. Power and regasification system for lng
EP2708794A1 (de) * 2012-09-13 2014-03-19 Air Liquide Deutschland GmbH Verfahren und Konditionierungsvorrichtung zum diskontinuierlichen Bereitstellen von flüssigem Kohlenstoffdioxid
WO2017095230A1 (en) * 2015-12-01 2017-06-08 Wärtsilä Oil & Gas Systems As A plant and method for regasification of lng
CN111188996A (zh) * 2020-02-12 2020-05-22 中海石油气电集团有限责任公司 一种lng接收站浸没燃烧式气化器的低温余热回收装置

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JP4677338B2 (ja) * 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 冷熱供給方法
SG174767A1 (en) 2006-09-11 2011-10-28 Exxonmobil Upstream Res Co 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
FR2952161B1 (fr) * 2009-11-03 2012-01-13 Gea Batignolles Technologies Thermiques Systeme de vaporisation d'un fluide cryogenique avec des echangeurs centralises
CN107560321B (zh) * 2017-09-15 2023-04-25 长江大学 Bog回收与氮气液化系统及工艺方法

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Cited By (14)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20080178611A1 (en) * 2007-01-30 2008-07-31 Foster Wheeler Usa Corporation Ecological Liquefied Natural Gas (LNG) Vaporizer System
US20110017429A1 (en) * 2008-03-27 2011-01-27 L'air Liquide Societe Anonyme Pour L'etude Et L'exploitation Des Procedes Georges Claude Method For Vaporizing Cryogenic Liquid Through Heat Exchange Using Calorigenic Fluid
US20100313578A1 (en) * 2008-05-16 2010-12-16 Gea Batignolles Technologies Thermiques co2-based method and system for vaporizing a cryogenic fluid, in particular liquefied natural gas
US9695984B2 (en) * 2009-11-13 2017-07-04 Hamworthy Gas Systems As Plant for regasification of LNG
US20120222430A1 (en) * 2009-11-13 2012-09-06 Hamworthy Gas Systems As Plant for regasification of lng
US8707730B2 (en) 2009-12-07 2014-04-29 Alkane, Llc Conditioning an ethane-rich stream for storage and transportation
US20110132033A1 (en) * 2009-12-07 2011-06-09 Alkane, Llc Conditioning an Ethane-Rich Stream for Storage and Transportation
DE102010056581B4 (de) * 2010-12-30 2013-04-04 Gea Batignolles Technologies Thermiques Anordnung zur Verdampfung von flüssigem Erdgas
US20130160486A1 (en) * 2011-12-22 2013-06-27 Ormat Technologies Inc. Power and regasification system for lng
US9903232B2 (en) * 2011-12-22 2018-02-27 Ormat Technologies Inc. Power and regasification system for LNG
EP2708794A1 (de) * 2012-09-13 2014-03-19 Air Liquide Deutschland GmbH Verfahren und Konditionierungsvorrichtung zum diskontinuierlichen Bereitstellen von flüssigem Kohlenstoffdioxid
WO2014040806A1 (en) * 2012-09-13 2014-03-20 L'air Liquide,Societe Anonyme Pour L'etude Et L'exploitation Des Procedes Georges Claude Process and conditioning device for discontinuous provision of liquid carbon dioxide
WO2017095230A1 (en) * 2015-12-01 2017-06-08 Wärtsilä Oil & Gas Systems As A plant and method for regasification of lng
CN111188996A (zh) * 2020-02-12 2020-05-22 中海石油气电集团有限责任公司 一种lng接收站浸没燃烧式气化器的低温余热回收装置

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PT1853846E (pt) 2012-07-12
ATE553330T1 (de) 2012-04-15
FR2882129A1 (fr) 2006-08-18
JP2008530472A (ja) 2008-08-07
ES2385575T3 (es) 2012-07-26
EP1853846B1 (fr) 2012-04-11
KR20070114167A (ko) 2007-11-29
WO2006087452A1 (fr) 2006-08-24

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