WO2005114076A1 - Liquefaction de gaz naturel - Google Patents

Liquefaction de gaz naturel Download PDF

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Publication number
WO2005114076A1
WO2005114076A1 PCT/US2004/012792 US2004012792W WO2005114076A1 WO 2005114076 A1 WO2005114076 A1 WO 2005114076A1 US 2004012792 W US2004012792 W US 2004012792W WO 2005114076 A1 WO2005114076 A1 WO 2005114076A1
Authority
WO
WIPO (PCT)
Prior art keywords
stream
receive
residue gas
gas fraction
heat exchange
Prior art date
Application number
PCT/US2004/012792
Other languages
English (en)
Inventor
John D. Wilkinson
Hank M. Hudson
Kyle T. Cuellar
Original Assignee
Ortloff Engineers, Ltd
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
Priority to EP04822020A priority Critical patent/EP1740897A4/fr
Priority to NZ549861A priority patent/NZ549861A/en
Application filed by Ortloff Engineers, Ltd filed Critical Ortloff Engineers, Ltd
Priority to AU2004319953A priority patent/AU2004319953B2/en
Priority to JP2007510667A priority patent/JP4551446B2/ja
Priority to KR1020067022354A priority patent/KR101118830B1/ko
Priority to CNB2004800428521A priority patent/CN100473927C/zh
Priority to MXPA06011644A priority patent/MXPA06011644A/es
Priority to BRPI0418780A priority patent/BRPI0418780B1/pt
Priority to EA200601989A priority patent/EA010538B1/ru
Priority to CA2562323A priority patent/CA2562323C/fr
Priority to PCT/US2004/012792 priority patent/WO2005114076A1/fr
Priority to ARP040103911A priority patent/AR046607A1/es
Priority to PE2004001092A priority patent/PE20051002A1/es
Priority to SA05260083A priority patent/SA05260083B1/ar
Priority to MYPI20051722A priority patent/MY137287A/en
Publication of WO2005114076A1 publication Critical patent/WO2005114076A1/fr
Priority to ZA2006/07240A priority patent/ZA200607240B/en
Priority to EGNA2006000858 priority patent/EG25056A/xx
Priority to NO20065055A priority patent/NO20065055L/no
Priority to HK07106105.2A priority patent/HK1101424A1/xx

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    • 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
    • F25J1/0211—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 using a multi-component refrigerant [MCR] fluid in a closed vapor compression cycle
    • F25J1/0214—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 using a multi-component refrigerant [MCR] fluid in a closed vapor compression cycle as a dual level refrigeration cascade with at least one MCR cycle
    • 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
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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
    • F25J1/00—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
    • F25J1/0002—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures characterised by the fluid to be liquefied
    • F25J1/0022—Hydrocarbons, e.g. natural gas
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    • F25J1/0047—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures characterised by the kind of cold generation within the liquefaction unit for compensating heat leaks and liquid production using an "external" refrigerant stream in a closed vapor compression cycle
    • F25J1/0052—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures characterised by the kind of cold generation within the liquefaction unit for compensating heat leaks and liquid production using an "external" refrigerant stream in a closed vapor compression cycle by vaporising a liquid refrigerant stream
    • F25J1/0057—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures characterised by the kind of cold generation within the liquefaction unit for compensating heat leaks and liquid production using an "external" refrigerant stream in a closed vapor compression cycle by vaporising a liquid refrigerant stream after expansion of the liquid refrigerant stream with extraction of work
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
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    • 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
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    • 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
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    • F25J2270/60—Closed external refrigeration cycle with single component refrigerant [SCR], e.g. C1-, C2- or C3-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
    • F25J2270/00—Refrigeration techniques used
    • F25J2270/66—Closed external refrigeration cycle with multi component refrigerant [MCR], e.g. mixture of hydrocarbons

Definitions

  • This invention relates to a process for processing natural gas or other methane-rich gas streams to produce a liquefied natural gas (LNG) stream that has a high methane purity and a liquid stream containing predominantly hydrocarbons heavier than methane.
  • LNG liquefied natural gas
  • Natural gas is typically recovered from wells drilled into underground reservoirs. It usually has a major proportion of methane, i.e., methane comprises at least 50 mole percent of the gas. Depending on the particular underground reservoir, the natural gas also contains relatively lesser amounts of heavier hydrocarbons such as
  • the present invention is generally concerned with the liquefaction of natural gas while producing as a co-product a liquid stream consisting primarily of hydrocarbons heavier than methane, such as natural gas liquids (NGL) composed of ethane, propane, butanes, and heavier hydrocarbon components, liquefied petroleum gas (LPG) composed of propane, butanes, and heavier hydrocarbon components, or condensate composed of butanes and heavier hydrocarbon components.
  • NNL natural gas liquids
  • LPG liquefied petroleum gas
  • Producing the co-product liquid stream has two important benefits: the LNG produced has a high methane purity, and the co-product liquid is a valuable product that may be used for many other purposes.
  • a typical analysis of a natural gas stream to be processed in accordance with this invention would be, in approximate mole percent, 84.2% methane, 7.9% ethane and other C components, 4.9% propane and other C components, 1.0% iso-butane, 1.1% normal butane, 0.8% pentanes plus, with the balance made up of nitrogen and carbon dioxide. Sulfur containing gases are also sometimes present.
  • “Cascade refrigeration” employs heat exchange of the natural gas with several refrigerants having successively lower boiling points, such as propane, ethane, and methane. As an alternative, this heat exchange can be accomplished using a single refrigerant by evaporating the refrigerant at several different pressure levels.
  • “Multi-component refrigeration” employs heat exchange of the natural gas with one or more refrigerant fluids composed of several refrigerant components in lieu of multiple single-component refrigerants. Expansion of the natural gas can be accomplished both isenthalpically (using Joule-Thomson expansion, for instance) and isentropically (using a work-expansion turbine, for instance).
  • FIG. 1 is a flow diagram of a natural gas liquefaction plant adapted for co-production of LPG in accordance with the present invention
  • FIGS. 2 and 3 are diagrams of alternative fractionation systems which may be employed in the process of the present invention.
  • FIG. 4 is a pressure-enthalpy phase diagram for methane used to illustrate the advantages of the present invention over prior art processes.
  • FIGS. 5, 6, 7, 8, 9, and 10 are flow diagrams of alternative natural gas liquefaction plants adapted for co-production of a liquid stream in accordance with the present invention.
  • the molar flow rates given in the tables may be interpreted as either pound moles per hour or kilogram moles per hour.
  • the energy consumptions reported as horsepower (HP) and/or thousand British Thermal Units per hour (MBTU/Hr) correspond to the stated molar flow rates in pound moles per hour.
  • the energy consumptions reported as kilowatts (kW) correspond to the stated molar flow rates in kilogram moles per hour.
  • the production rates reported as pounds per hour (Lb/Hr) correspond to the stated molar flow rates in pound moles per hour.
  • the production rates reported as kilograms per hour (kg/Hr) correspond to the stated molar flow rates in kilogram moles per hour.
  • FIG. 1 we begin with an illustration of a process in accordance with the present invention where it is desired to produce an LPG co-product containing the majority of the propane and heavier components in the natural gas feed stream.
  • inlet gas enters the plant at 90°F
  • inlet gas contains a concentration of carbon dioxide and/or sulfur compounds which would prevent the product streams from meeting specifications, these compounds are removed by appropriate pretreatment of the feed gas (not illustrated).
  • the feed stream is usually dehydrated to prevent hydrate (ice) formation under cryogenic conditions. Solid desiccant has typically been used for this purpose.
  • the feed stream 31 is cooled in heat exchanger 10 by heat exchange with refrigerant streams and flashed separator liquids at -14°F [-26°C] (stream 40a).
  • heat exchanger 10 is representative of either a multitude of individual heat exchangers or a single multi-pass heat exchanger, or any combination thereof.
  • the decision as to whether to use more than one heat exchanger for the indicated cooling services will depend on a number of factors including, but not limited to, inlet gas flow rate, heat exchanger size, stream temperatures, etc.
  • the cooled stream 31 enters separator 11 at 23°F [-5°C] and 1278 psia [8,812 kPa(a)] where the vapor (stream 32) is separated from the condensed liquid (stream 33).
  • the vapor (stream 32) from separator 11 is divided into two streams, 34 and 36, with stream 34 containing about 42% of the total vapor. Some circumstances may favor combining stream 34 with some portion of the condensed liquid (stream 39) to form stream 35, but in this simulation there is no flow in stream 39.
  • Combined stream 35 passes through heat exchanger 13 in heat exchange relation with refrigerant stream 71 e, resulting in cooling and substantial condensation of stream 35a.
  • the substantially condensed stream 35a at -90°F [-68°C] is then flash expanded through an appropriate
  • NY02:408682.3 -7- expansion device such as expansion valve 14, to slightly above the operating pressure (approximately 450 psia [3,103 kPa(a)]) of fractionation tower 19.
  • the expanded stream 35b leaving expansion valve 14 reaches a temperature of -123°F [-86°C].
  • the expanded stream 35b is warmed to -78°F [-61°C] and further vaporized in heat exchanger 21 as it provides cooling and partial condensation of vapor distillation stream 37 rising from the fractionation stages of fractionation tower 19.
  • the warmed stream 35c is then supplied at an upper mid-point feed position in deethanizing section 19b of fractionation tower 19.
  • the remaining 58% of the vapor from separator 11 enters a work expansion machine 15 in which mechanical energy is extracted from this portion of the high pressure feed.
  • the machine 15 expands the vapor substantially isentropically from a pressure of about 1278 psia [8,812 kPa(a)] to the tower operating pressure, with the work expansion cooling the expanded stream 36a to a temperature of approximately -57°F [-49°C].
  • the typical commercially available expanders are capable of recovering on the order of 80-85% of the work theoretically available in an ideal isentropic expansion.
  • the work recovered is often used to drive a centrifugal compressor (such as item 16) that can be used to re-compress the tower overhead gas (stream 49), for example.
  • the expanded and partially condensed stream 36a is supplied as feed to distillation column 19 at a lower mid-column feed point.
  • Stream 40, the remaining portion of the separator liquid (stream 33) is flash expanded to slightly above the operating pressure of deethanizer 19 by expansion valve 12, cooling stream 40 to -14°F
  • the deethanizer in fractionation tower 19 is a conventional distillation column containing a plurality of vertically spaced trays, one or more packed beds, or some combination of trays and packing. As is often the case in natural gas processing plants, the fractionation tower may consist of two sections.
  • the upper section 19a is a separator wherein the top feed is divided into its respective vapor and liquid portions, and wherein the vapor rising from the lower distillation or deethanizing section 19b is combined with the vapor portion (if any) of the top feed to form the deethanizer overhead vapor (stream 37) which exits the top of the tower.
  • the lower, deethanizing section 19b contains the trays and/or packing and provides the necessary contact between the liquids falling downward and the vapors rising upward.
  • the deethanizing section also includes one or more reboilers (such as reboiler 20) which heat and vaporize a portion of the liquids flowing down the column to provide the stripping vapors which flow up the column.
  • the liquid product stream 41 exits the bottom of the tower at 213°F [101°C], based on a typical specification of an ethane to propane ratio of 0.020: 1 on a molar basis in the bottom product.
  • the overhead distillation stream 37 leaves deethanizer 19 at -73°F [-59°C] and is cooled and partially condensed in reflux condenser 21 as described earlier.
  • the partially condensed stream 37a enters reflux drum 22 at -94°F [-70°C] where the condensed liquid (stream 44) is separated from the uncondensed vapor (stream 43).
  • reflux condenser 21 may be located inside the tower above column 19 as shown in FIG. 2. This eliminates the need for reflux drum 22 and reflux pump 23 because the distillation stream is then both cooled and separated in the tower above the fractionation stages of the column.
  • a dephlegmator such as dephlegmator 21 in FIG. 3
  • reflux condenser 21 in FIG. 1 eliminates the reflux drum and reflux pump and also provides concurrent fractionation stages to replace those in the upper section of the deethanizer column.
  • the dephlegmator If the dephlegmator is positioned in a plant at grade level, it is connected to a vapor/liquid separator and the liquid collected in the separator is pumped to the top of the distillation column.
  • the decision as to whether to include the reflux condenser inside the column or to use a dephlegmator usually depends on plant size and heat exchanger surface requirements.
  • stream 48 a portion (stream 48) is then withdrawn to serve as fuel gas for the plant.
  • the amount of fuel gas that must be withdrawn is largely determined by the fuel required for the engines and/or turbines driving the gas compressors in the plant, such as refrigerant compressors 64, 66, and 68 in this example.
  • the remainder of the warmed vapor (stream 49) is compressed by compressor 16 driven by expansion machines 15, 61, and 63. After cooling to 100°F [38°C] in discharge cooler
  • stream 49b is further cooled to -83 °F [-64°C] in heat exchanger 24 by cross exchange with the cold vapor, stream 43.
  • Stream 49c then enters heat exchanger 60 and is further cooled by refrigerant stream 71d to -255°F [-160°C] to condense and subcool it, whereupon it enters a work expansion machine 61 in which mechanical energy is extracted from the stream.
  • the machine 61 expands liquid stream 49d substantially isentropically from a pressure of about 593 psia [4,085 kPa(a)] to the LNG storage pressure (15.5 psia [107 kPa(a)]), slightly above atmospheric pressure.
  • the work expansion cools the expanded stream 49e to a temperature of approximately -256°F [-160°C], whereupon it is then directed to the LNG storage tank 62 which holds the LNG product (stream 50).
  • All of the cooling for streams 35 and 49c is provided by a closed cycle refrigeration loop.
  • the working fluid for this cycle is a mixture of hydrocarbons and nitrogen, with the composition of the mixture adjusted as needed to provide the required refrigerant temperature while condensing at a reasonable pressure using the available cooling medium.
  • condensing with cooling water has been assumed, so a refrigerant mixture composed of nitrogen, methane, ethane, propane, and heavier hydrocarbons is used in the simulation of the FIG. 1 process.
  • the composition of the stream in approximate mole percent, is 8.7% nitrogen, 31.7% methane, 47.0% ethane, and 8.6% propane, with the balance made up of heavier hydrocarbons.
  • the refrigerant stream 71 leaves discharge cooler 69 at 100°F [38°C] and
  • NY02:4Q8682.3 -11- refrigerant streams are commercial-quality propane refrigerant at three different temperature and pressure levels.
  • the partially condensed refrigerant stream 71a then enters heat exchanger 13 for further cooling to -90°F [-68°C] by partially warmed expanded refrigerant stream 71 e, further condensing the refrigerant (stream 71b).
  • the refrigerant is condensed and then subcooled to -255°F [-160°C] in heat exchanger 60 by expanded refrigerant stream 71 d.
  • the subcooled liquid stream 71c enters a work expansion machine 63 in which mechanical energy is extracted from the stream as it is expanded substantially isentropically from a pressure of about 586 psia [4,040 kPa(a)] to about 34 psia [234 kPa(a)].
  • a portion of the stream is vaporized, resulting in cooling of the total stream to -264°F [-164°C] (stream 71 d).
  • the expanded stream 71d then reenters heat exchangers 60, 13, and 10 where it provides cooling to stream 49c, stream 35, and the refrigerant (streams 71, 71a, and 71b) as it is vaporized and superheated.
  • the superheated refrigerant vapor (stream 71g) leaves heat exchanger 10 at 90°F [32°C] and is compressed in three stages to 617 psia [4,254 kPa(a)].
  • Each of the three compression stages (refrigerant compressors 64, 66, and 68) is driven by a supplemental power source and is followed by a cooler (discharge coolers 65, 67, and 69) to remove the heat of compression.
  • the compressed stream 71 from discharge cooler 69 returns to heat exchanger 10 to complete the cycle.
  • the efficiency of LNG production processes is typically compared using the "specific power consumption” required, which is the ratio of the total refrigeration compression power to the total liquid production rate.
  • Specific power consumption is the ratio of the total refrigeration compression power to the total liquid production rate.
  • the first factor can be understood by examining the thermodynamics of the liquefaction process when applied to a high pressure gas stream such as that considered in this example. Since the primary constituent of this stream is methane, the thermodynamic properties of methane can be used for the purposes of comparing the liquefaction cycle employed in the prior art processes versus the cycle used in the present invention.
  • FIG. 4 contains a pressure-enthalpy phase diagram for methane. In most of the prior art liquefaction cycles, all cooling of the gas stream is accomplished while the stream is at high pressure (path A-B), whereupon the stream is then expanded (path B-C) to the pressure of the LNG storage vessel (slightly above atmospheric pressure).
  • This expansion step may employ a work expansion machine, which is typically capable of recovering on the order of 75-80% of the work theoretically available in an ideal isenfropic expansion.
  • a work expansion machine typically capable of recovering on the order of 75-80% of the work theoretically available in an ideal isenfropic expansion.
  • fully isenfropic expansion is displayed in FIG. 4 for path B-C. Even so, the enthalpy reduction provided by this work expansion is quite small, because the lines of constant entropy are nearly vertical in the liquid region of the phase diagram.
  • the hydrocarbon removal step in most of the prior art processes is performed at high pressure, typically using a scrub column that employs a cold hydrocarbon liquid as the absorbent stream to remove the heavier hydrocarbons from the incoming gas stream.
  • Operating the scrub column at high pressure is not very efficient, as it results in the co-absorption of a significant fraction of the methane and ethane from the gas stream, which must subsequently be stripped from the absorbent liquid and cooled to become part of the LNG product.
  • the hydrocarbon removal step is conducted at the intermediate pressure where the vapor-liquid equilibrium is much more favorable, resulting in very efficient recovery of the desired heavier hydrocarbons in the co-product liquid stream.
  • the present invention can be adapted to recover an NGL stream containing a significant fraction of the C 2 components present in the feed gas, or to recover a condensate stream containing only the C 4 and heavier components present in the feed gas, rather than producing an LPG co-product as described earlier.
  • FIG. 1 represents the preferred embodiment of the present invention for the processing conditions indicated.
  • FIGS. 5 through 10 depict alternative embodiments of the present invention that may be considered for a particular application.
  • the cooled feed stream 31a leaving heat exchanger 10 may not contain any liquid (because it is above its dewpoint, or because it is above its cricondenbar), so that separator 11 shown in FIGS. 1 and 6 through 10 is not required, and the cooled feed stream can flow directly to an appropriate expansion device, such as work expansion machine 15.
  • an embodiment of the present invention such as that shown in FIG. 5 may be employed.
  • Condensed liquid stream 33 flows through heat exchanger 18 and is subcooled, then divided into two portions.
  • the first portion (stream 40) flows through expansion valve 12 where it undergoes expansion for flash vaporization as the pressure is reduced to about the pressure of distillation column 19.
  • the cold stream 40a from expansion valve 12 then flows through heat exchanger 18 where it is partially warmed as it is used to subcool stream 33 as described
  • stream 39 is (1) combined with portion 34 of the vapor stream from separator 11, or (2) combined with substantially condensed stream 35a, or (3) expanded in expansion valve 17 and thereafter either supplied to fractionation column 19 at an upper mid-point feed location or combined with expanded stream 35b.
  • portions of stream 39 may follow any or all of the flow paths heretofore described and depicted in FIG. 5.
  • stream 49a leaving the compressor may flow directly to heat exchanger 24 as shown in FIG. 7, or
  • a supplemental heater 58 may be needed to warm the fuel gas before it is consumed, using a utility sfream or another process stream to supply the necessary heat, as shown in FIGS. 8 through 10. Choices such as these must generally be evaluated for each application, as factors such as gas composition, plant size, desired co-product stream recovery level, and available equipment must all be considered. [0036] In accordance with the present invention, the cooling of the inlet gas stream and the feed stream to the LNG production section may be accomplished in many ways. In the processes of FIGS. 1 and 5 through 10, inlet gas stream 31 is cooled and condensed by external refrigerant streams and flashed separator liquids.
  • the cold process streams could also be used to supply some of the cooling to the high pressure refrigerant (stream 71a).
  • any stream at a temperature colder than the stream(s) being cooled may be utilized.
  • a side draw of vapor from fractionation tower 19 could be withdrawn and used for cooling.
  • the use and distribution of tower liquids and/or vapors for process heat exchange, and the particular arrangement of heat exchangers for inlet gas and feed gas cooling, must be evaluated for each
  • boiling single-component refrigerant has been assumed for the high level external refrigeration and vaporizing multi-component refrigerant has been assumed for the low level external refrigeration, with the single-component refrigerant used to pre-cool the multi-component refrigerant stream.
  • both the high level cooling and the low level cooling could be accomplished using single-component refrigerants with successively lower boiling points (i.e., "cascade refrigeration"), or one single-component refrigerant at successively lower evaporation pressures.
  • both the high level cooling and the low level cooling could be accomplished using multi-component refrigerant streams with their respective compositions adjusted to provide the necessary cooling temperatures.
  • NY02:408682.3 -20- external refrigeration described above may be employed in combination to achieve the desired feed stream temperature(s).
  • stream 49d in FIG. 1, stream 49e in FIG. 6, stream 49c in FIG. 7, stream 49b in FIGS. 8 and 9, and stream 49a in FIG. 10) reduces or eliminates the quantity of flash vapor that may be generated during expansion of the stream to the operating pressure of LNG storage tank 62. This generally reduces the specific power consumption for producing the LNG by eliminating the need for flash gas compression. However, some circumstances may favor reducing the capital cost of the facility by reducing the size of heat exchanger 60 and using flash gas compression or other means to dispose of any flash gas that may be generated.
  • isenthalpic flash expansion may be used in lieu of work expansion for the subcooled high pressure refrigerant stream leaving heat exchanger 60 (stream 71c in FIGS. 1 and 6 Y02:408682.3 -21- through 10), with the resultant increase in the power consumption for compression of the refrigerant.

Abstract

La présente invention concerne un procédé pour liquéfier du gaz naturel et pour produire conjointement un courant liquide contenant majoritairement des hydrocarbures plus lourds que le méthane. Selon ce procédé, le courant de gaz naturel à liquéfier est partiellement refroidi, détendu à une pression intermédiaire, puis transféré à une colonne de distillation. Le produit de fond de cette colonne de distillation contient de préférence la majorité de tous les hydrocarbures plus lourds que le méthane qui, sinon, réduiraient la pureté du gaz naturel liquéfié. Le courant de gaz résiduel provenant de la colonne de distillation est comprimé à une pression intermédiaire plus élevée, refroidi sous pression afin d'être condensé, puis détendu à basse pression afin de former le courant de gaz naturel liquéfié.
PCT/US2004/012792 2004-04-26 2004-04-26 Liquefaction de gaz naturel WO2005114076A1 (fr)

Priority Applications (19)

Application Number Priority Date Filing Date Title
PCT/US2004/012792 WO2005114076A1 (fr) 2004-04-26 2004-04-26 Liquefaction de gaz naturel
CA2562323A CA2562323C (fr) 2004-04-26 2004-04-26 Liquefaction de gaz naturel
AU2004319953A AU2004319953B2 (en) 2004-04-26 2004-04-26 Natural gas liquefaction
NZ549861A NZ549861A (en) 2004-04-26 2004-04-26 A process for liquefying natural gas and producing predominantly hydrocarbons heavier than methane
KR1020067022354A KR101118830B1 (ko) 2004-04-26 2004-04-26 천연 가스 액화
CNB2004800428521A CN100473927C (zh) 2004-04-26 2004-04-26 天然气液化的方法及其设备
MXPA06011644A MXPA06011644A (es) 2004-04-26 2004-04-26 Licuefaccion de gas natural.
BRPI0418780A BRPI0418780B1 (pt) 2004-04-26 2004-04-26 processos para liquefazer uma corrente de gás natural contendo metano e componentes hidrocarbonetos mais pesados e aparelhos para a realização dos processos
EA200601989A EA010538B1 (ru) 2004-04-26 2004-04-26 Сжижение природного газа
EP04822020A EP1740897A4 (fr) 2004-04-26 2004-04-26 Liquefaction de gaz naturel
JP2007510667A JP4551446B2 (ja) 2004-04-26 2004-04-26 天然ガスの液化
ARP040103911A AR046607A1 (es) 2004-04-26 2004-10-27 Proceso y aparato para licuar una corriente de gas natural
PE2004001092A PE20051002A1 (es) 2004-04-26 2004-11-09 Licuefaccion de gas natural
SA05260083A SA05260083B1 (ar) 2004-04-26 2005-04-09 إسالة غاز طبيعي
MYPI20051722A MY137287A (en) 2004-04-26 2005-04-19 Natural gas liquefaction
ZA2006/07240A ZA200607240B (en) 2004-04-26 2006-08-30 Natural gas liquefaction
EGNA2006000858 EG25056A (en) 2004-04-26 2006-09-13 Natural gas liquefaction process.
NO20065055A NO20065055L (no) 2004-04-26 2006-11-02 Flytendegjorelse av naturgass
HK07106105.2A HK1101424A1 (en) 2004-04-26 2007-06-07 Method and apparatus used for liquidizing natural gas

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US9217603B2 (en) 2007-09-13 2015-12-22 Battelle Energy Alliance, Llc Heat exchanger and related methods
US9254448B2 (en) 2007-09-13 2016-02-09 Battelle Energy Alliance, Llc Sublimation systems and associated methods
US9574713B2 (en) 2007-09-13 2017-02-21 Battelle Energy Alliance, Llc Vaporization chambers and associated methods
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US10655911B2 (en) 2012-06-20 2020-05-19 Battelle Energy Alliance, Llc Natural gas liquefaction employing independent refrigerant path
WO2016053668A1 (fr) 2014-09-30 2016-04-07 Dow Global Technologies Llc Procédé pour augmenter le rendement d'éthylène et de propylène d'une installation de production de propylène
US10808999B2 (en) 2014-09-30 2020-10-20 Dow Global Technologies Llc Process for increasing ethylene and propylene yield from a propylene plant
CN105444527A (zh) * 2015-12-02 2016-03-30 中国石油大学(北京) 一种天然气处理装置及方法
WO2019095031A1 (fr) * 2017-11-14 2019-05-23 1304338 Alberta Ltd. Procédé de récupération et de traitement de méthane et de condensats à partir de systèmes de gaz torché
US11946355B2 (en) 2017-11-14 2024-04-02 1304338 Alberta Ltd. Method to recover and process methane and condensates from flare gas systems

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HK1101424A1 (en) 2007-10-18
KR101118830B1 (ko) 2012-03-22
SA05260083B1 (ar) 2009-02-07
EP1740897A1 (fr) 2007-01-10
CA2562323A1 (fr) 2005-12-01
PE20051002A1 (es) 2005-11-26
AU2004319953B2 (en) 2010-11-18
JP2007534923A (ja) 2007-11-29
EG25056A (en) 2011-07-20
EA010538B1 (ru) 2008-10-30
BRPI0418780A (pt) 2007-10-09
CN100473927C (zh) 2009-04-01
AU2004319953A1 (en) 2005-12-01
EP1740897A4 (fr) 2013-01-30
ZA200607240B (en) 2008-03-26
MY137287A (en) 2009-01-30
BRPI0418780B1 (pt) 2015-12-29
EA200601989A1 (ru) 2007-02-27
CA2562323C (fr) 2011-01-04
KR20070012814A (ko) 2007-01-29
NO20065055L (no) 2007-01-12
AR046607A1 (es) 2005-12-14
JP4551446B2 (ja) 2010-09-29
MXPA06011644A (es) 2007-01-23
CN1946979A (zh) 2007-04-11

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