EP2097698A2 - Procédé et appareil de réduction du pouvoir calorifique du gaz naturel liquéfié - Google Patents

Procédé et appareil de réduction du pouvoir calorifique du gaz naturel liquéfié

Info

Publication number
EP2097698A2
EP2097698A2 EP07869325A EP07869325A EP2097698A2 EP 2097698 A2 EP2097698 A2 EP 2097698A2 EP 07869325 A EP07869325 A EP 07869325A EP 07869325 A EP07869325 A EP 07869325A EP 2097698 A2 EP2097698 A2 EP 2097698A2
Authority
EP
European Patent Office
Prior art keywords
stream
lng
gas
overheads
separations
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Withdrawn
Application number
EP07869325A
Other languages
German (de)
English (en)
Inventor
Carlos M. Yengle
Sunil Dutt
Piers Hodges
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Chevron USA Inc
Original Assignee
Chevron USA Inc
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Chevron USA Inc filed Critical Chevron USA Inc
Publication of EP2097698A2 publication Critical patent/EP2097698A2/fr
Withdrawn legal-status Critical Current

Links

Classifications

    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J3/00—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification
    • F25J3/02—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream
    • F25J3/0228—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream characterised by the separated product stream
    • F25J3/0233—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream characterised by the separated product stream separation of CnHm with 1 carbon atom or more
    • 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
    • F17C13/00—Details of vessels or of the filling or discharging of vessels
    • F17C13/004—Details of vessels or of the filling or discharging of vessels for large storage vessels not under pressure
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J3/00—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification
    • F25J3/02—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream
    • F25J3/0204—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream characterised by the feed stream
    • F25J3/0209—Natural gas or substitute natural gas
    • F25J3/0214—Liquefied natural gas
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J3/00—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification
    • F25J3/02—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream
    • F25J3/0228—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream characterised by the separated product stream
    • F25J3/0238—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream characterised by the separated product stream separation of CnHm with 2 carbon atoms or more
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
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    • 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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    • 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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    • 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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    • F17C2223/00—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel
    • F17C2223/04—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel characterised by other properties of handled fluid before transfer
    • F17C2223/042—Localisation of the removal point
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    • 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
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    • 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
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    • 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
    • F17C2227/01—Propulsion of the fluid
    • F17C2227/0128—Propulsion of the fluid with pumps or compressors
    • F17C2227/0135—Pumps
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    • F17C2227/00—Transfer of fluids, i.e. method or means for transferring the fluid; Heat exchange with the fluid
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    • 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
    • F17C2227/0306—Heat exchange with the fluid by heating using the same fluid
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    • 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
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    • F17C2227/0309—Heat exchange with the fluid by heating using another fluid
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    • F17C2227/00—Transfer of fluids, i.e. method or means for transferring the fluid; Heat exchange with the fluid
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    • F17C2227/039—Localisation of heat exchange separate on the pipes
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    • F17C2250/00—Accessories; Control means; Indicating, measuring or monitoring of parameters
    • F17C2250/04—Indicating or measuring of parameters as input values
    • F17C2250/0404—Parameters indicated or measured
    • F17C2250/0447—Composition; Humidity
    • F17C2250/0456—Calorific or heating value
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    • F17C2265/00—Effects achieved by gas storage or gas handling
    • F17C2265/01—Purifying the fluid
    • F17C2265/015—Purifying the fluid by separating
    • F17C2265/017—Purifying the fluid by separating different phases of a same fluid
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    • F17C2265/00—Effects achieved by gas storage or gas handling
    • F17C2265/03—Treating the boil-off
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    • F17C2265/033—Treating the boil-off by recovery with cooling
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    • F17C2265/00—Effects achieved by gas storage or gas handling
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    • F17C2265/034—Treating the boil-off by recovery with cooling with condensing the gas phase
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    • F17C2265/037—Treating the boil-off by recovery with pressurising
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    • F25J2205/00—Processes or apparatus using other separation and/or other processing means
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    • F25J2235/00—Processes or apparatus involving steps for increasing the pressure or for conveying of liquid process streams
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    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2245/00—Processes or apparatus involving steps for recycling of process streams
    • F25J2245/90—Processes or apparatus involving steps for recycling of process streams the recycled stream being boil-off gas from storage
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2290/00—Other details not covered by groups F25J2200/00 - F25J2280/00
    • F25J2290/62—Details of storing a fluid in a tank

Definitions

  • the present invention relates to reducing the heating value of liquefied natural gas (LNG). More particularly, the present invention relates to reducing the heating value of imported LNG by removing natural gas liquid products while condensing boil- off gas.
  • LNG liquefied natural gas
  • Natural gas is a valuable, environmentally-friendly energy source. With gradually decreasing quantities of clean easily-refined crude oil, natural gas has become accepted as an alternative energy source. Natural gas may be recovered from natural gas reservoirs or as associated gas from crude oil reservoirs. Indeed, natural gas for use in the present process may be recovered from any process which generates light hydrocarbon gases
  • Natural gas can be found all over the world. Much of the natural gas reserves found around the world are separate from oil and as new reserves arc discovered and processed, growth in the LNG industry will continue. countries with large natural gas reservoirs include Amsterdam, Australia, Brunei, Indonesia, republic, Malaysia, Nigeria, Oman, Pakistan, and Trinidad and Tobago.
  • LNG tankers can unload their cargo at dedicated marine receiving terminals which store and regasify the LNG for distribution to domestic markets.
  • Onshore terminals can include docks, LNG handling equipment, storage tanks, a vaporizer system and interconnections to regional gas transmission pipelines and electric power plants.
  • Offshore terminals typically regasify and pump the gas directly into offshore natural gas pipelines or may store natural gas in undersea salt caverns for later injection into offshore pipelines.
  • LNG is typically stored at cryogenic temperatures of about -162 0 C and a vapor pressure at or near atmospheric pressure in double walled tanks or containers.
  • the core containment for LNG is provided by the inner tank, while the outer tank is designed to provide a secondary' containment, hold insulation and provide protection from adverse affects of the environment.
  • Conventional vaporizer systems are used to warm and convert the LNG to usable gas.
  • the LNG is warmed from approximately -16O 0 C in the vaporizer system converting it from a liquid phase to usable gas so that it can be transferred to a pipeline.
  • the conventional process to capture BOG involves compressing the gas to a pressure equal to that of the LNG which is being pumped from the storage tanks.
  • the BOG is combined with a stream of LNG in a dedicated condenser vessel where it is re- condensed and absorbed into the LNG.
  • Another conventional process involves the compressing of BOG to pipeline pressure and combining it downstream of the vaporizers. This approach requires the compression of BOG to a high pressure.
  • the present invention achieves the advantage of a process and apparatus for reducing the heating value of imported LNG by removing liquid petroleum gas products with combined condensing of boil-off gas.
  • a process for reducing the heating value of LNG includes: splitting an LNG stream into a separations feed stream and a vaporization feed stream; cross heat-exchanging the separations feed stream with a combined boil- off gas and overheads stream; separating the separations feed stream into the overheads stream and a bottoms stream; and combining the combined boil-off gas and overheads stream with the vaporization feed stream.
  • a flowrale ratio between the separations feed stream and the vaporization stream is in the range of about 20:80 to 40:60.
  • the LNG stream pressure is in the range of about 75 to 125 psig.
  • the LNG stream is at a dew point temperature.
  • the separating is performed in a demethanizcr.
  • the combined boil-off gas and overheads stream is formed by combining a boil-off gas stream with the separations feed stream before the separations feed stream is separated into the overheads stream and the bottoms stream.
  • the combined boil-off gas and overheads stream is formed by combining a boil-off gas stream with the overheads stream after the separations feed stream is separated into the overheads stream and the bottoms stream.
  • the overheads stream comprises at least about 98 mol% methane.
  • an apparatus for reducing the heating value of LNG includes: a pump for pumping an LNG stream; a flow control device for splitting the LNG stream into a separations feed stream and a vaporization stream; ai least one heat exchanger for cross heat-exchanging the separations feed stream with a combined boil-ot ⁇ gas and overheads stream; and a separations column for separating the separations feed stream into the overheads stream and a bottoms stream.
  • the flow control device controls a flowrate ratio between the separations feed stream and the vaporization stream within the range of about 20:80 u> 40:60.
  • the pump maintains the LNG stream at a pressure in the range of about 75 to 125 psig.
  • the LNG stream is at a dew point temperature.
  • the separations column is a demethanizer.
  • the above apparatus further includes a manifold disposed upstream of the separations column for combining a boil-off gas with the separations feed stream.
  • the above apparatus further includes a manifold disposed downstream of the separations column for combining a boil-off gas with the overheads stream.
  • the above apparatus further includes a manifold disposed downstream from the heat exchanger for combining the combined boil-off gas and overheads stream with the vaporization stream.
  • the above apparatus further includes a compressor f ⁇ r compressing the boil-off gas stream.
  • a liquefied natural gas is maintained at a select pressure in a container (B).
  • the container is designed for a particular pressure, and the temperature of the LNG equilibrates to the bubble point temperature at the select pressure.
  • the design of the container in which LNG is stored is not critical to the invention, and includes stationary storage located either on-sh ⁇ re ⁇ r ⁇ ff- shore in an aquatic location.
  • the LNG may be stored in a mobile container, located, for example, in a ship or on a truck, barge, train or the like.
  • the present process can be employed with LNG stored over the full range of possible storage pressures, including pressure from ambient pressure to a pressure of 1500 psig and above.
  • the LNG is stored at a pressure of about 5 psig or less.
  • LNG at (1) is unloaded from an LNG carrier with on board pumps (A).
  • the pressurized LNG at (2) is then transferred to the LNG container (B).
  • LNG (3) is transferred from the container (B) and pressurized with a pump (C).
  • the pressurized LNG (4) output from the pump (C) is transferred to a heat exchanger (D), heated by cross-exchange to a temperature close enough not to produce any vapors (dew point temperature), and output as (5).
  • the pressure of the LNG at (4) is preferably in the range of about 75 to 125 psig and the temperature change between (4) and (5) (across the heat exchanger (D)) is in the range of about +25 to about +30 0 C.
  • the heat exchanger (D) is a gas direct-contact type condenser such as a plate and fin exchanger in order to maximize heat transfer.
  • the heated pressurized LNG (5) is split into a separations feed stream (1 1) and a vaporization feed stream (6).
  • the split in flow may be achieved by using a flow control device such a valve (not shown).
  • the flowrate ratio is preferably in the range of about 20:80 to ab ⁇ ul 40:60 (20% to 40% for stream (1 1 ) and 80% to 60% for stream (6)).
  • the separations feed stream (1 1) is further heated in a heat exchanger (H), which is the sanie type of heat exchanger as the heat exchanger (D), and output as a preheated LNG stream (12).
  • the temperature change between (1 1) and (12) (across the heat exchanger (H)) is in the range of about +1 to about +5 U C.
  • the present invention is also directed, at least in part, to a method for recovering BOG which is generated during LNG storage and handling, prior to the LNG vaporization process.
  • LNG is maintained at a temperature below, and generally well below, ambient temperature
  • a small amount of LNG will vaporize during storage and handling as heat is absorbed through container walls.
  • the vaporized BOG must be handled.
  • boil-off gas (21 ) evolved in the LNG container (B) is pressurized with a compressor (K) and output as (22).
  • the compressor (K) is either a centrifugal or reciprocating type compressor.
  • the compressed boil-off gas (22) is then combined with the preheated LNG stream (12) via a manifold (not shown), and the combined stream (13) is transferred to a flash tank (I).
  • the combined stream (13) is then flashed into a vapor stream (17) and a liquid stream (14).
  • the flash tank (I) is a commonly used type low pressure surge drum or phase separator drum.
  • the liquid stream (14) is then transferred to a demethanizer column (J) and separated into an overheads stream (16) and an NGL bottoms stream (15).
  • the NGL bottoms stream (15) is sent to additional processes.
  • the demethanizer column (J) is a reboiled absorber that uses a bottom heat source, such as a bottoms reboiler.
  • a bottom heat source such as a bottoms reboiler.
  • suitable bottom heat sources include a kettle reboiler, a thcrmosyphon reboiler, a plate-fin exchanger, an internal reboiler, a side reboiler, and combinations thereof.
  • the demethanizer column (J) typically includes a stripping section and an absorption section within the same tower.
  • the rising vapors in a reboiler reflux stream are at least partially condensed by intimate contact with falling liquids from the liquid stream (14), thereby producing the overheads stream (16).
  • the overheads stream (16) has a methane concentration of at least about 98 mol%.
  • the condensed liquids descend down the demethanizer column (J) and are removed as the NGL bottoms stream (15
  • the overheads stream (16) is combined with the vapor stream (17) via a manifold (not shown) and output as a combined boil-off gas and overheads stream (18).
  • the combined boil-off gas and overheads stream (18) is then transferred to the heat exchanger (H), cooled and partially condensed by cross exchanging with the LNG feed portion to the demethanizer (J), and output as (19).
  • the temperature change between (18) and (19) (across the heat exchanger (H)) is in the range of about -3 to about -18 0 C.
  • the cooled overheads stream (19) is further cooled and condensed by cross exchanging with the LNG feed portion in the heat exchanger (D). and output as (20).
  • the temperature change between (19) and (20) (across the heat exchanger (D)) is in the range of about -3 to about -10 0 C.
  • the cooled overheads stream (20) is then transferred to a flash tank (L) and flashed into a vapor stream (23) and a liquids stream (24).
  • the vapor stream (23) is recycled back to the container (B), while the liquids stream (24) is transferred to a pump (M) and pressurized.
  • the vaporization feed stream (6) is combined, via a manifold (not shown), with a pressurized liquid stream (25) output from the pump (M), as (7).
  • the LNG (7) is then transferred to a flash tank (E) and Hashes into a vapor stream (26) and an LNG stream (8).
  • the LNG stream (8) is further pressurized with a pump (F) and output as (9).
  • the LNG stream (9) is then vaporized in a vaporizer (G) and output as a gas (10).
  • the vaporization pressure will be set by the pipeline delivery pressure at (10), increased by some relatively small pressure differential to account for pressure losses across the vaporizer (G).
  • the LNG is vaporized when the pressurized LNG (9) is passed across the vaporizer (G).
  • Illustrative vaporizers include shell and tube heat exchangers, open rack vaporizers and the like.
  • the vaporized LNG (10) is at pipeline delivery pressure, and available for sending to a pipeline delivery system or to another customer of natural gas.
  • the pipeline delivery pressure to which the natural gas is compressed is greater than 1000 psig.
  • a pressure in the region of 1300 psig is illustrative.
  • the following tables are examples of a rich LNG case (Table 1 ) and a lean LNG case (Table 2).
  • the methane concentration for the rich LNG case is in the range of about 85 to 89 mol%.
  • the methane concentration for the lean LNG case is in the range ofabout90to95mol%.

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  • Engineering & Computer Science (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Physics & Mathematics (AREA)
  • Thermal Sciences (AREA)
  • Chemical & Material Sciences (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • General Chemical & Material Sciences (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Filling Or Discharging Of Gas Storage Vessels (AREA)

Abstract

La présente invention concerne un procédé et un appareil qui permettent de réduire le pouvoir calorifique de gaz naturel liquéfié (GNL) importé par une élimination des produits liquides du gaz naturel et une condensation simultanée du gaz évaporé. Le GNL est pompé dans un contenant de stockage puis chauffé par échange thermique croisé jusqu'à la température du point de rosée. Une partie de ce GNL chauffé est envoyée à l'extérieur pour être vaporisée alors que la partie restante est encore chauffée par échange croisé avec les vapeurs de produit de tête du déméthaniseur puis envoyée en tant que charge au déméthaniseur, le GNL est ensuite récupéré au niveau inférieur du déméthaniseur et les vapeurs de produit de tête sont mélangées avec le gaz évaporé sortant du contenant de stockage de GNL. Ces vapeurs mélangées sont condensées par échange croisé avec la partie de charge du GNL puis sont pompées à la pression du réseau de canalisations et envoyées à la canalisation de gaz par les vaporiseurs.
EP07869325A 2006-12-21 2007-12-14 Procédé et appareil de réduction du pouvoir calorifique du gaz naturel liquéfié Withdrawn EP2097698A2 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US11/614,694 US20080148771A1 (en) 2006-12-21 2006-12-21 Process and apparatus for reducing the heating value of liquefied natural gas
PCT/US2007/087682 WO2008079753A2 (fr) 2006-12-21 2007-12-14 Procédé et appareil de réduction du pouvoir calorifique du gaz naturel liquéfié

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EP2097698A2 true EP2097698A2 (fr) 2009-09-09

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US (1) US20080148771A1 (fr)
EP (1) EP2097698A2 (fr)
CN (1) CN101652618B (fr)
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Also Published As

Publication number Publication date
WO2008079753A3 (fr) 2008-10-23
CN101652618A (zh) 2010-02-17
CN101652618B (zh) 2014-06-25
WO2008079753A2 (fr) 2008-07-03
WO2008079753A9 (fr) 2008-09-04
US20080148771A1 (en) 2008-06-26

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