EP1819800B1 - Procede et appareil de production d'un flux de gaz naturel liquefie - Google Patents

Procede et appareil de production d'un flux de gaz naturel liquefie Download PDF

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Publication number
EP1819800B1
EP1819800B1 EP05816189.4A EP05816189A EP1819800B1 EP 1819800 B1 EP1819800 B1 EP 1819800B1 EP 05816189 A EP05816189 A EP 05816189A EP 1819800 B1 EP1819800 B1 EP 1819800B1
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Prior art keywords
stream
substream
feed
scrub
distillation column
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German (de)
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EP1819800A1 (fr
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Marco Dick Jager
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Shell Internationale Research Maatschappij BV
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Shell Internationale Research Maatschappij BV
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    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G5/00—Recovery of liquid hydrocarbon mixtures from gases, e.g. natural gas
    • C10G5/06—Recovery of liquid hydrocarbon mixtures from gases, e.g. natural gas by cooling or compressing
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10L—FUELS NOT OTHERWISE PROVIDED FOR; NATURAL GAS; SYNTHETIC NATURAL GAS OBTAINED BY PROCESSES NOT COVERED BY SUBCLASSES C10G, C10K; LIQUEFIED PETROLEUM GAS; ADDING MATERIALS TO FUELS OR FIRES TO REDUCE SMOKE OR UNDESIRABLE DEPOSITS OR TO FACILITATE SOOT REMOVAL; FIRELIGHTERS
    • C10L3/00—Gaseous fuels; Natural gas; Synthetic natural gas obtained by processes not covered by subclass C10G, C10K; Liquefied petroleum gas
    • C10L3/06—Natural gas; Synthetic natural gas obtained by processes not covered by C10G, C10K3/02 or C10K3/04
    • 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
    • F25J1/00—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
    • F25J1/02—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures requiring the use of refrigeration, e.g. of helium or hydrogen ; Details and kind of the refrigeration system used; Integration with other units or processes; Controlling aspects of the process
    • 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
    • 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
    • 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
    • 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
    • F25J3/0247—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 4 carbon atoms or more
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
    • C10G2300/10—Feedstock materials
    • C10G2300/1025—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
    • F25J2200/00—Processes or apparatus using separation by rectification
    • F25J2200/02—Processes or apparatus using separation by rectification in a single pressure main column system
    • 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
    • F25J2200/00—Processes or apparatus using separation by rectification
    • F25J2200/70—Refluxing the column with a condensed part of the feed stream, i.e. fractionator top is stripped or self-rectified
    • 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
    • F25J2200/00—Processes or apparatus using separation by rectification
    • F25J2200/74—Refluxing the column with at least a part of the partially condensed overhead 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
    • F25J2205/00—Processes or apparatus using other separation and/or other processing means
    • F25J2205/30—Processes or apparatus using other separation and/or other processing means using a washing, e.g. "scrubbing" or bubble column for purification purposes
    • 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
    • F25J2205/00—Processes or apparatus using other separation and/or other processing means
    • F25J2205/50—Processes or apparatus using other separation and/or other processing means using absorption, i.e. with selective solvents or lean oil, heavier CnHm and including generally a regeneration step for the solvent or lean oil
    • 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
    • F25J2210/00—Processes characterised by the type or other details of the feed stream
    • F25J2210/06—Splitting of the feed stream, e.g. for treating or cooling in different ways
    • 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
    • F25J2210/00—Processes characterised by the type or other details of the feed stream
    • F25J2210/62—Liquefied natural gas [LNG]; Natural gas liquids [NGL]; Liquefied petroleum gas [LPG]
    • 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
    • F25J2220/00—Processes or apparatus involving steps for the removal of impurities
    • F25J2220/60—Separating impurities from natural gas, e.g. mercury, cyclic hydrocarbons
    • F25J2220/64—Separating heavy hydrocarbons, e.g. NGL, LPG, C4+ hydrocarbons or heavy condensates in general
    • 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
    • F25J2235/00—Processes or apparatus involving steps for increasing the pressure or for conveying of liquid process streams
    • F25J2235/60—Processes or apparatus involving steps for increasing the pressure or for conveying of liquid process streams the fluid being (a mixture of) hydrocarbons
    • 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
    • F25J2245/00—Processes or apparatus involving steps for recycling of process streams
    • F25J2245/02—Recycle of a stream in general, e.g. a by-pass stream
    • 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
    • F25J2260/00—Coupling of processes or apparatus to other units; Integrated schemes
    • F25J2260/20—Integration in an installation for liquefying or solidifying a fluid stream
    • 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
    • F25J2270/00—Refrigeration techniques used
    • F25J2270/90—External refrigeration, e.g. conventional closed-loop mechanical refrigeration unit using Freon or NH3, unspecified external refrigeration

Definitions

  • the invention relates to a method and apparatus for producing a liquefied natural gas (LNG) stream, the LNG stream primarily comprising methane (preferably > 90 mol%).
  • LNG liquefied natural gas
  • the liquefaction process normally comprises a cryogenic zone containing one or more refrigeration cycles wherein the natural gas is cooled down in one or more stages from ambient temperature to the ambient boiling point of natural gas or somewhat lower. This boiling point is normally around minus 160 °C.
  • the refrigeration cycle(s) generally make use of a refrigerant fluid, which can be formed of either a mixture or a pure constituent.
  • the refrigerant is typically vaporised in one or more cryogenic heat exchangers, in which the natural gas is cooled.
  • the vaporized refrigerant is subsequently compressed to a higher pressure level and temperature.
  • heat from the refrigerant is rejected to a cooling medium, such as water or air, and subsequently cooled by expansion. It is very common in liquefaction processes with multiple cycles that consecutive refrigeration cycles are cooled by the first refrigeration cycle.
  • cryogenic heat exchanger In current liquefaction processes it is also common to remove certain components from the natural gas before it is cooled in the cryogenic heat exchanger(s). Amongst the components that normally are to be removed are carbon dioxide, sulphur containing compounds, water and hydrocarbons with a higher molecular weight than that of butane. The latter are referred to in this specification by the term "heavier hydrocarbons". These components must be removed from the natural gas as they could otherwise become solid at the cryogenic temperatures at which the liquefaction is carried out.
  • the raw natural gas stream is first decontaminated from water and acid gases for which numerous physical and/or chemical processes exist.
  • the resulting stream of sweetened and dried natural gas mixture is then subjected to a step of removing the heavier hydrocarbons.
  • the removal of heavier hydrocarbons is generally achieved by partial condensation of the natural gas mixture, followed by some separation between a vapour phase lean in heavier hydrocarbons and a liquid phase rich in heavier hydrocarbons. Most common is the use of a scrub column to achieve this separation.
  • a scrub column is a type of distillation column comprising a series of separation stages between a bottom end and top end, whereby a mixture enriched with heavier hydrocarbons is discharged from the bottom end in the form of a bottom stream, and a lighter mixture of natural gas is discharged from the top end in the form of an overhead stream.
  • US patent 5 685 170 describes a system and process for recovering propane, butane and heavier hydrocarbon components from natural gas thereby also generating a gas stream consisting primarily of methane and ethane.
  • the natural gas feed stream is split into several feed substreams, cooled and introduced to the scrub column at different feed points near the top and middle of the scrub column.
  • a first part of the natural gas is cooled by expansion in a Joule-Thompson valve and introduced in the scrub column at a lowered pressure.
  • Second and third parts are first cooled in a refrigeration cooler, separated into a condensate liquid stream and a vapour stream, before lowering the pressure.
  • the condensate liquid stream is fed into the scrub column at a feed point lower than the vapour stream.
  • a reboiler is provided to vaporize a fraction of the heavier hydrocarbon enriched bottom stream or liquid accumulated in the bottom end of the scrub column.
  • a reboiler also serves to control the temperature in the bottom end of the scrub column so as to ensure that the bottom end does not become too cold thereby carrying the risk of accumulation of unwanted components such as carbon dioxide in the bottom stream.
  • the known embodiment has a number of drawbacks. Firstly, the letting down of pressure of the feed substreams prior to feeding into the scrub column reduces the efficiency of a later liquefaction step, as liquefaction of natural gas at lower pressure requires more energy.
  • a drawback of a reboiler is that it adds heat to the natural gas while by the very nature of the liquefaction process the natural gas should be cooled.
  • the use of a reboiler adversely affects the overall efficiency of the liquefaction process.
  • the split ratio is defined as the mass flow rate of the first substream divided by the mass flow rate of the second substream.
  • An advantage of the invention is that neither the pressure of the feed stream, nor that of the first and second substreams, is deliberately lowered in a dedicated pressure lowering device such as a (turbo-)expander or a Joule-Thompson valve.
  • the first substream is fed into the distillation column at a pressure essentially not lower than the feed stream pressure minus a pressure drop brought about by the splitting of the feed stream, the pressure at the second feed point does not need to be let down.
  • the distillation is performed without significantly decreasing the pressure of the natural gas, which will be energetically beneficial in case that the overhead stream is to be liquefied.
  • Another consequence of deliberately not letting down the pressure in the first substream is that the temperature can be kept close to the feed stream temperature; preferably no warming of the first substream is provided.
  • An advantage of this is that less additional heating power, normally provided for instance via a reboiler, needs be into the bottom end of the distillation column to avoid it becoming too cold.
  • the split ratio can be selected such that the temperature in the bottom of the distillation column is maintained at -10 degrees Celsius or higher.
  • the temperature in the bottom end of the distillation column can be controlled by providing a selectable or controllably variable split ratio and selecting or controlling the split ratio.
  • a heat exchanger is understood to include at least heat exchangers of the so-called spool-wound type.
  • the invention is applicable to any type of distillation column that is suitable for removing heavier hydrocarbon components having a molecular weight higher than that of butane from a hydrocarbon gas mixture.
  • one or more preferred embodiments of the invention require a scrub stream to be fed into the column.
  • the distillation column is by definition forms a so-called scrub column.
  • Figure 1 schematically shows a process flow scheme involving a system for removing heavier hydrocarbon components having a molecular weight higher than that of butane from a hydrocarbon gas mixture, as part of an apparatus for producing an LNG stream primarily comprising methane.
  • the hydrocarbon gas mixture will be assumed to be formed of a natural gas mixture, previously treated to remove water, CO 2 , and sulphur by means and methods well known in the art.
  • the pretreated natural gas mixture will contain lighter components including vaporous methane and ethane and including C 3 and C 4 , and heavier components C 5 + that are potentially freezable during liquefaction of methane.
  • the feed stream may be a substantially vaporous feed stream of natural gas, which may comprise > 90 vol. % vapour, preferably > 95 vol. % vapour.
  • the apparatus of Figure 1 includes a natural gas feed line that is arranged to receive and carry a feed stream of the hydrocarbon gas mixture from which the heavier hydrocarbons are to be removed.
  • the feed streamline is divided in a main branch 1, and first and second substream branches 3a and 3b, respectively.
  • a feed stream junction 2 is provided to divide the feed stream in the main branch 1 into first and second substreams that can respectively flow through first and second substream branches 3a and 3b.
  • the feed stream junction 2 is arranged to divide the feed stream in accordance with a specified split ratio, which is defined as the mass flow rate of the first substream divided by the mass flow rate of the second substream.
  • a specified split ratio which is defined as the mass flow rate of the first substream divided by the mass flow rate of the second substream.
  • the feed stream junction 2 is not a phase separator, but rather divides the main feed stream in two or more substreams.
  • Both first and second substream branches 3a,3b are in fluid communication with a scrub column 10.
  • the scrub column 10 in the present embodiment is a distillation column provided with a number of trays 11 to allow separation of lighter hydrocarbon components from heavier hydrocarbon components in a plurality of separation stages. The temperature in the scrub column typically varies, becoming cooler with each higher stage.
  • the scrub column 10 further comprises a bottom stream discharge opening 8 in a lower part of the scrub column 10 for discharging a bottom stream enriched in the heavier hydrocarbon components for instance via discharge line 17, and an overhead stream discharge opening 12 arranged in an upper part of the scrub column 10 for discharging, for instance via discharge line 16, an overhead stream enriched in lighter hydrocarbon components.
  • the overhead stream 16 is connected with a cryogenic zone (not shown) for producing LNG.
  • the first branch 3a connects the feed stream junction 2 with a first feed point 7a in the scrub column 10.
  • the substream 3a feeds below the lowest phase separating tray 11.
  • the first branch 3a is essentially free of pressure-lowering devices so that the feed stream junction 2 is fluidly connected to the first feed point 7a at essentially no pressure loss.
  • the connection is dimensioned such that the pressure loss does not exceed 5 bar, more preferably it does not exceed 2 bar under normal operating conditions.
  • the first substream 3a is not warmed.
  • the second branch 3b connects the feed stream junction 2 with a second feed point 7b in the scrub column 10.
  • the second feed point 7b is situated overhead relative to the first feed point 7a to feed the first substream at one of the trays above the lower trays.
  • the second branch 3b is provided with a heat exchanger 6 dividing the second branch 3b into a warm part 3b and a cool part 7.
  • the heat exchanger 6 is arranged to cool the second substream 3b essentially without deliberately letting off pressure.
  • the heat exchanger 6 can be any suitable type of heat exchanger, such as a so-called spool-wound heat exchanger.
  • the pressure drop in the first substream 3a between the splitting of the feed stream 1 and the first feed point 7a may be ⁇ 6 bar, preferably ⁇ 3 bar.
  • the heat exchanger 6 has at least one supply of refrigerant 4 and one removal of spent or vaporized refrigerant 5.
  • the heat exchanger 6 may be a dedicated heat exchanger or an integrated heat exchanger that also provides cooling for other duties.
  • the heat exchanger 6 uses an external refrigerant, making the heat exchanger 6 a dedicated heat exchanger.
  • a third feed point 7c is advantageously provided in the scrub column 10.
  • the third feed point 7c is situated near the top of the scrub column 10 overhead relative to the second feed point 7b.
  • An optional scrub stream line 18 connects the third feed point 7c with a scrub stream source.
  • the scrub stream source serves to supply another liquid or multi-phase stream capable of scrubbing heavier hydrocarbons and promote downward transport of those in the scrub column 10.
  • the scrub stream can contain one or more of the group consisting of further cooled natural gas, condensate from an overhead condenser, LNG, chilled LPG, chilled condensate, mixtures hereof or any other stream with the appropriate properties to promote the removal of heavier hydrocarbons from the natural gas.
  • a feed stream of the pre-treated hydrocarbon gas mixture is provided via line 1 at a feed stream pressure and a feed stream temperature.
  • the feed stream pressure generally lies between 20 and 80 bar, and more typically between 40 and 65 bar.
  • the feed stream temperature is generally between 0 and 50 degrees Celsius, typically between 15 and 25 degrees Celsius, more typically between 15 and 20 degrees Celsius.
  • the feed stream is split into first and second substreams 3a,3b in feed stream junction 2, preferably in the form of minor and major substreams.
  • the minor substream 3a is fed into the scrub column 10 via the first feed point 7a, at a pressure that is not lower than the feed stream pressure minus a pressure drop brought about by the splitting of the feed stream 1 in the feed stream junction 2. In practice, it means that the pressure in the minor substream 3a is not deliberately let down.
  • the second substream 3b is cooled in the heat exchanger 6 to a lower temperature than the feed temperature.
  • the major substream 3b is cooled to a temperature not lower than -50 degrees Celsius, preferably not lower than - 20 degrees Celsius.
  • the major substream 3b is cooled to a temperature of -10 degrees Celsius or lower.
  • the cooled major substream is fed, via the second feed point 7b and the cold part 7 of the second sub branch 3b, into the scrub column 10 at a location overhead of where the minor substream 3a is fed into the scrub column 10.
  • the optional scrub stream in scrub line 18 has a temperature lower or equal to that of the second substream entering via the second feed point 7b.
  • the split ratio is preferably chosen smaller than 1/5 in order to assure that the temperature in the scrub column is sufficiently low to achieve an efficient separation of heavier hydrocarbon components from the mixture. More preferably the split ratio is chosen smaller than 1/10.
  • the split ratio is preferably chosen higher than 1/100, in order to achieve a beneficial effect in lowering the demand for external heat required to maintain the temperature in the bottom of the scrub column higher than -10 degrees Celsius.
  • the split ratio is chosen higher than 1/50, so that the need for a reboiler can be removed entirely.
  • no reboiler is present, as a result of which no reboiling takes place between the overhead stream discharge opening 12 and the third feed point 7c.
  • the scrub stream 18 is fed to the scrub column 10 via the third feed point 7c overhead of the second feed point 7b.
  • the temperature of the scrub stream 18 is typically lower than that of the cooled minor substream and usually between -70 and -10 degrees Celsius. This further helps in maintaining the desired temperature gradient inside the scrub column 10.
  • the top product 16 is drawn from the scrub column 10 via overhead stream discharge opening 12, which is the natural gas from which the heavier hydrocarbons have been removed to a sufficient extent.
  • Stream 17 is the bottom product enriched in heavier hydrocarbons that is discharged via discharge opening 8.
  • the top product 16 is a natural gas vapour stream lean in heavier hydrocarbons, meeting the requirements to avoid formation of solids during further cooling of the natural gas vapour stream ultimately into liquefaction in a cryogenic zone (not shown).
  • the bottom product 17 may find any application, one of which is further processing it to form liquefied petroleum gas (LPG).
  • FIGS 2 to 5 schematically depict alternative process flow schemes involving alternative apparatuses.
  • parts already described above with reference to Figure 1 will carry identical reference numerals and will not be again described here. Also their function and operation will be in accordance with the description above.
  • FIGS 2 to 5 show embodiments wherein the scrub stream 18 is at least in part drawn from the feed stream 1.
  • a main difference with the embodiment of Fig. 1 is reflected by the presence of a second feed stream junction 20 provided in the second branch 7 upstream of the second feed point 7b and downstream of the heat exchanger 6.
  • the second branch 7 continues downstream of the feed stream junction 20 and a third branch 22 is formed to carry a third substream of the feed stream 1.
  • the third branch 22 is provided with a second heat exchanger 26, the down-stream side thereof being connected to scrub stream line 18.
  • the second heat exchanger 26 is arranged to further cool the third substream 22 to a temperature lower than that of the second substream, essentially without deliberately letting off pressure. Under normal operating condition, the pressure drop in the third substream 22 is less than 6 bar, preferably less than 3 bar. As shown in Fig. 2 at least one supply of refrigerant 24 is provided to feed to the second heat exchanger 26, wherein the removal of spent or vaporized refrigerant 25 can form the supply of refrigerant 4 to feed the first mentioned heat exchanger 6.
  • first and second heat exchangers are each provided independently with at least one supply and removal of refrigerants.
  • the second heat exchanger 26 may be a dedicated heat exchanger or an integrated heat exchanger that also provides cooling for other duties.
  • FIG. 3 an alternative to Figure 2 is schematically shown wherein the second feed stream junction 20 is provided in the second branch 3b upstream of the first heat exchanger 6.
  • the second heat exchanger 26 is provided in a parallel relationship with the first heat exchanger 6 instead of the serial arrangement of Fig. 2 .
  • the second branch 3b continues downstream of the second feed stream junction 20 and third branch 22 is formed to carry the third substream of the feed stream 1.
  • the down-stream side of the second heat exchanger is connected to scrub stream line 18.
  • First and second heat exchangers 6,26 each have individually at least one supply of refrigerant 4,24 and removal 5,25 of spent refrigerant.
  • the first and second heat exchangers 6,26 can be combined in one housing, whereby the refrigerant can be operative at one pressure level.
  • FIG. 4 there is schematically shown an example based on parallel cooling of the second and third substreams, whereby the first and second heat exchangers are integrated into one housing each represented by a flow path.
  • Figure 5 shows an example of an integrated heat exchanger embodying serial cooling of the embodiment of Figure 2 .
  • the second feed stream junction 20 is located outside the heat exchanger housing whereby the second and third branches can be led out and into the heat exchanger housing.
  • the feed stream junction 20 can be located inside the heat exchanger housing.
  • the scrub stream source which is connected to the scrub column 10 via the third feed point 7c overhead of the second feed point 7b, comprises the second feed stream junction 20 and the second heat exchanger 26.
  • the apparatuses of Figures 2 to 5 work similar to that of Figure 1 .
  • the scrub stream in line 18 is obtained by drawing a fraction from the second substream 3b to form a third substream.
  • the residue carries on as the second substream 3b.
  • the third substream is cooled in the second heat exchanger 26 downstream the second feed stream junction 20, to a temperature that is lower than that of the second substream as it has been cooled by the first heat exchanger 6.
  • an overhead condenser is provided in discharge line 16, in the form of an overhead heat exchanger 14.
  • the heat exchanger 14 has at least one supply of refrigerant 30 and one removal of spent or vaporized refrigerant 31.
  • the heat exchanger 14 may be a dedicated heat exchanger or an integrated heat exchanger that also provides cooling for other duties.
  • Discharge line 16 fluidly connects a downstream outlet of heat exchanger 14 to a separator 27. Separator 27 has a condensate outlet 35 discharging into line 15 and a vapour outlet 33 discharging into line 13.
  • Line 15 can be directly connected to the scrub column 10 via third feed point 7c and line 18.
  • an optional reflux pump 19 is provided between line 15 and line 18.
  • the overhead condenser 14 and separator 27 may also be integrated into one housing or into one piece of equipment wherein the functions are combined.
  • Fig. 6 works as follows.
  • the top product overhead stream that is being discharged from the scrub column 10 through line 16 is led to the overhead condenser 14 where it is partially condensed using a refrigerant.
  • the partially condensed forms a mixed phase stream of vapour and condensate, which is led to the separator 27.
  • the vapour that is discharged from the separator 27 via line 13 is the natural gas from which heavier hydrocarbons have been sufficiently removed and which is to be liquefied to obtain LNG.
  • the condensate in the form of condensed liquid is drawn from the mixed phase stream to obtain the scrub stream 18, or to add to another scrub stream, that is supplied to the scrub column 10.
  • the reflux pump 19 may be employed to bring the liquid to a desired pressure level.
  • An advantage of the embodiment of Fig. 6 is that it allows freedom in choosing the temperature of the second substream 3b because the tray number (corresponding to a height in the distillation column 10) at which the second substream 3b is fed into the distillation column 10 can be chosen.
  • the temperature of the second substream in line 7 can be chosen to optimise the refrigeration cycle.
  • the temperature profile in the bottom part of the scrub column 10 and the temperature of the bottom product discharged via outlet 8 and line 17 can be optimally controlled by selecting or controlling the split ratio.
  • An advantage of the embodiments of Figures 2 to 5 is that these avoid the use of the reboiler in the form of overhead separator 27 and/or the reflux pump 19.
  • the third substream forms a major fraction of the second substream or more than half of the original second substream as split in feed stream junction 2.
  • the third substream is typically cooled to a temperature lower than -10 degrees Celsius and not lower than -100 degrees Celsius.
  • the third substream is cooled to a temperature lower than -30 degrees Celsius.
  • the third substream is cooled to a temperature not lower than -60 degrees Celsius. This third substream is then entered into the scrub column 10 at the third feed point 7c.
  • FIG. 7 still another embodiment of the invention is schematically depicted.
  • the second feed point 7b is provided in the vicinity of the top of the scrub column 10 where normally would be the scrub stream inlet.
  • the heat exchanger in the second branch is here depicted by a plurality of heat exchangers 6 and 6' operating in series of each other. It will be understood that the heat exchanger can be provided in the form of a single piece of equipment.
  • the second substream in second branch 3b is fed into line 7, it is cooled to a temperature low enough to form a liquid/vapour mixture.
  • the temperature is typically lower than -10 degrees Celsius and not lower than -60 degrees Celsius.
  • the second substream is cooled to a temperature lower than -30 degrees Celsius.
  • the third substream is cooled to a temperature not lower than -60 degrees Celsius.
  • An advantage of the embodiments of Figures 2 to 5 and of the embodiment of Figure 7 over the embodiment of Figure 6 is that the flow rate through the second heat exchanger 26 or the second part 6' of the heat exchanger is lower than the flow rate through overhead condenser 14, because part of the natural gas is sent to the scrub column without passing the second heat exchanger 26 or the second part 6'.
  • Figure 8 represents a comparative example wherein the feed stream in feed streamline 1 is not split into substreams, but optionally cooled in heat exchanger 6 prior to feeding into the scrub column 10 via feed point 7d.
  • Feed point 7d can be in or near the bottom of the scrub column, or somewhat higher than feed point 7a.
  • Mass and energy balance calculations were performed in relation to the process flow schemes shown in Figures 6 , 7, and 8 , for a typical feed gas and typical ambient conditions.
  • a relative power (including end-flash power over production) of 13.1 kW/tpd is calculated to result in a content of C 5 + in the stream in line 13 of 0.03 mol.%.
  • the split ratio was set to 8% so that the major part of the feed stream was led through the heat exchangers 6 and 6'.
  • the temperature of the second substream in line 7 was lowered to about -20 degrees Celsius.
  • the calculated relative power (including end-flash power over production) is 13.1 kW/tpd, whereby the content of C 5 + in the stream in line 16 is 0.06 mol.%.
  • the splitting of the feed stream gives the option of getting rid of the components for generating a reflux stream, such as the overhead separator 27 and/or the reflux pump 19, at the cost of only a slightly worse separation.
  • a reflux stream such as the overhead separator 27 and/or the reflux pump 19
  • an improved control over the temperature gradient in the scrub column 10 is achieved, and the material flow in the bottom of the scrub column 10 is strongly reduced so that it can be made slimmer.

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Claims (17)

  1. Procédé de production d'un flux de gaz naturel liquéfié, dans lequel avant la liquéfaction, des composants d'hydrocarbures plus lourds ayant un poids moléculaire plus élevé que celui du butane sont éliminés d'un flux de gaz naturel à liquéfier, le procédé comprenant au moins les étapes de :
    - fourniture d'un flux d'alimentation à l'état de vapeur (1) de gaz naturel à une pression de flux d'alimentation et à une température de flux d'alimentation ;
    - introduction du flux d'alimentation (1) dans une colonne de distillation (10) ayant deux étages de séparation (11) ou plus ;
    - extraction d'un flux de fond (17) à partir d'une partie inférieure de la colonne de distillation (10) et d'un flux de tête (16) à partir d'une partie supérieure de la colonne de distillation (10), le flux de tête (16) contenant une quantité relative inférieure des composants d'hydrocarbures plus lourds que le flux de fond (17) ; et
    - liquéfaction d'au moins une partie du flux de tête (16), permettant ainsi d'obtenir un flux de gaz naturel liquéfié ;
    dans lequel l'étape d'introduction du flux d'alimentation (1) dans la colonne de distillation (10) comprend les sous-étapes de :
    - division du flux d'alimentation (1) en des premier (3a) et deuxième (3b) sous-flux à un rapport de division sélectionné ;
    - introduction du premier sous-flux (3a) dans la colonne de distillation (10) par l'intermédiaire d'un premier point d'alimentation (7a) au fond de la colonne de distillation (10) en-dessous de l'étage de séparation le plus bas (11) de celle-ci, à une pression non inférieure à la pression du flux d'alimentation moins une chute de pression provoquée par ladite division du flux d'alimentation (1), dans lequel le premier sous-flux (3a) n'est pas chauffé entre la division du flux d'alimentation (1) et l'introduction du premier sous-flux (3a) au niveau du premier point d'alimentation (7a) dans la colonne de distillation (10) ;
    - refroidissement du deuxième sous-flux (3b) dans un échangeur de chaleur (6) à une température inférieure à la température d'alimentation ;
    - introduction du deuxième sous-flux refroidi (7) dans la colonne de distillation (10) au niveau d'un deuxième point d'alimentation (7b) au-dessus du premier point d'alimentation (7a) ;
    dans lequel la pression ni du premier sous-flux (3a) ni du deuxième sous-flux (3b) est abaissée dans un dispositif d'abaissement de pression dédié.
  2. Procédé selon la revendication 1, dans lequel le flux d'alimentation à l'état de vapeur (1) comprend > 90 % en volume de vapeur.
  3. Procédé selon la revendication 1 ou 2, dans lequel la chute de pression dans le premier sous-flux (3a) entre la division du flux d'alimentation (1) et le premier point d'alimentation (7a) est < 6 bar.
  4. Procédé selon une ou plusieurs des revendications précédentes, dans lequel le rapport de division sélectionné est maintenu inférieur à 1/5, dans lequel le rapport de division est défini comme le débit massique du premier sous-flux (3a) divisé par le débit massique du deuxième sous-flux (3b).
  5. Procédé selon la revendication 4, dans lequel le rapport de division sélectionné est maintenu supérieur à 1/100.
  6. Procédé selon une ou plusieurs des revendications précédentes, dans lequel le deuxième sous-flux (3b) est refroidi dans l'échangeur de chaleur (6) à l'encontre d'un réfrigérant externe.
  7. Procédé selon une ou plusieurs des revendications précédentes, dans lequel la colonne de distillation (10) se présente sous la forme d'une colonne de lavage dans lequel un flux de lavage (18) est introduit dans la colonne de lavage par l'intermédiaire d'un troisième point d'alimentation (7c) au-dessus du deuxième point d'alimentation (7b), à une température qui est inférieure à celle du deuxième sous-flux refroidi (7).
  8. Procédé selon la revendication 7, dans lequel le flux de lavage (18) est sensiblement liquide.
  9. Procédé selon la revendication 7 ou 8, dans lequel le flux de lavage (18) est obtenu par :
    - l'extraction d'une fraction à partir du deuxième sous-flux (3b) pour former un troisième sous-flux (22), dans lequel le résidu continue comme le deuxième sous-flux (3b) ;
    - le refroidissement du troisième sous-flux (22) dans un second échangeur de chaleur (26) pour former le flux de lavage (18).
  10. Procédé selon la revendication 7 ou 8, dans lequel le flux de lavage est obtenu par :
    - la condensation partielle du flux de tête (16) pour former un flux de phase mixte de vapeur et de condensat, en extrayant le condensat du flux de phase mixte pour obtenir le flux de lavage (18).
  11. Procédé selon la revendication 10, dans lequel la partie du flux de tête (16) qui est utilisée comme le flux de lavage (18) n'est pas étendue entre la colonne de lavage et le troisième point d'alimentation (7c).
  12. Procédé selon une ou plusieurs des revendications précédentes 7 à 11, dans lequel la température du flux de lavage (18) est suffisamment faible pour former un condensat d'hydrocarbures plus lourds.
  13. Appareil pour produire un flux de gaz naturel liquéfié, dans lequel avant la liquéfaction, des composants d'hydrocarbures plus lourds ayant un poids moléculaire supérieur à celui du butane peuvent être éliminés d'un flux de gaz naturel à liquéfier, l'appareil comprenant au moins :
    - une ligne de flux d'alimentation (1) pour transporter un flux d'alimentation à l'état de vapeur (1) de gaz naturel à une pression d'alimentation et à une température d'alimentation ;
    - une colonne de distillation (10) ayant deux étages de séparation (11) ou plus pour séparer les composants d'hydrocarbures plus lourds du gaz naturel, une ouverture d'évacuation de flux de fond (8) disposée dans une partie inférieure de la colonne de distillation (10) pour évacuer un flux de fond (17), et une ouverture d'évacuation de flux de tête (12) disposée dans une partie supérieure de la colonne de distillation (10) pour évacuer un flux de tête (16) contenant une quantité relative inférieure des composants d'hydrocarbures plus lourds que le flux de fond (17) ; et
    - une zone cryogénique dans laquelle au moins une partie du flux de tête (16) peut être liquéfiée, permettant ainsi d'obtenir un flux de gaz naturel liquéfié ;
    dans lequel la ligne de flux d'alimentation (1) comprend une jonction de flux d'alimentation (2) reliant de manière fluidique une ramification principale à des première et seconde ramifications pour diviser le flux d'alimentation en des premier et deuxième sous-flux (3a, 3b) à un rapport de division sélectionné, dans lequel le premier sous-flux (3a) relie la jonction de flux d'alimentation (2) à un premier point d'alimentation (7a) au fond de la colonne de distillation (10) à une pression non inférieure au flux d'alimentation moins une chute de pression provoquée par la division du flux d'alimentation (1), et dans lequel le deuxième sous-flux (3b) relie la jonction de flux d'alimentation (2) à un deuxième point d'alimentation (7b) dans la colonne de distillation (10), le deuxième point d'alimentation (7b) étant au-dessus par rapport au premier point d'alimentation (7a), dans lequel le deuxième flux d'alimentation (3b) est pourvu d'un échangeur de chaleur (6) conçu pour refroidir le deuxième sous-flux (3b) ;
    dans lequel le premier point d'alimentation (7a) est situé en-dessous de l'étage de séparation le plus bas (11) de la colonne de distillation (10) ;
    dans lequel le premier sous-flux (3a) n'est pas pourvu d'un échangeur de chaleur pour chauffer le premier sous-flux (3a) ; et
    dans lequel aucun dispositif d'abaissement de pression dédié n'est présent pour abaisser la pression du premier sous-flux (3a) et du deuxième sous-flux (3b).
  14. Appareil selon la revendication 13, dans lequel la colonne de distillation (10) se présente sous la forme d'une colonne de lavage, l'appareil comprenant en outre une source de flux de lavage reliée à la colonne de lavage par l'intermédiaire d'un troisième point d'alimentation (7c) dans la colonne de lavage au-dessus du deuxième point d'alimentation (7b).
  15. Appareil selon la revendication 14, dans lequel la source de flux de lavage comprend une seconde jonction (20) disposée dans le deuxième sous-flux (3b) en amont du deuxième point d'alimentation pour alimenter un troisième sous-flux (22) à partir du deuxième sous-flux (3b), dans lequel le troisième sous-flux (22) est pourvu d'un second échangeur de chaleur (26).
  16. Appareil selon la revendication 14 ou 15, dans lequel la source de flux de lavage comprend un condenseur (14) conçu pour recevoir le flux de tête (16) en aval de la colonne de lavage en coopération avec un séparateur (27) ayant une sortie de condensat (33) et une sortie de vapeur (35), dans lequel la sortie de condensat (33) est reliée à la colonne de lavage par l'intermédiaire du troisième point d'alimentation (7c).
  17. Appareil selon une ou plusieurs des revendications précédentes 14 à 16, dans lequel aucun extenseur n'est présent entre l'ouverture d'évacuation de flux de tête (12) et le troisième point d'alimentation (7c).
EP05816189.4A 2004-12-08 2005-12-07 Procede et appareil de production d'un flux de gaz naturel liquefie Not-in-force EP1819800B1 (fr)

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EP05816189.4A EP1819800B1 (fr) 2004-12-08 2005-12-07 Procede et appareil de production d'un flux de gaz naturel liquefie
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CN101072848A (zh) 2007-11-14
AU2009202409A1 (en) 2009-07-09
AU2009202409B2 (en) 2010-11-11
KR101260693B1 (ko) 2013-05-10
EG25612A (en) 2012-03-21
US20080115532A1 (en) 2008-05-22
RU2402592C2 (ru) 2010-10-27
AU2005313333B2 (en) 2009-04-23
KR20070091323A (ko) 2007-09-10
PE20060989A1 (es) 2006-11-06
BRPI0518464B1 (pt) 2015-10-06
BRPI0518464A2 (pt) 2008-11-18
RU2007125703A (ru) 2009-01-20
JP2008523186A (ja) 2008-07-03
JP5138381B2 (ja) 2013-02-06
MY146497A (en) 2012-08-15
CN101072848B (zh) 2012-10-03
EP1819800A1 (fr) 2007-08-22
AU2005313333A1 (en) 2006-06-15
WO2006061400A1 (fr) 2006-06-15

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