US20110067443A1 - Hydrocarbon Gas Processing - Google Patents

Hydrocarbon Gas Processing Download PDF

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Publication number
US20110067443A1
US20110067443A1 US12/869,139 US86913910A US2011067443A1 US 20110067443 A1 US20110067443 A1 US 20110067443A1 US 86913910 A US86913910 A US 86913910A US 2011067443 A1 US2011067443 A1 US 2011067443A1
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US
United States
Prior art keywords
stream
components
receive
cooled
feed position
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.)
Abandoned
Application number
US12/869,139
Other languages
English (en)
Inventor
Tony L. Martinez
John D. Wilkinson
Joe T. Lynch
Hank M. Hudson
Kyle T. Cuellar
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.)
Honeywell UOP LLC
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
Application filed by Ortloff Engineers Ltd filed Critical Ortloff Engineers Ltd
Priority to US12/869,139 priority Critical patent/US20110067443A1/en
Priority to EP10825365.9A priority patent/EP2480847A4/en
Priority to CA2773211A priority patent/CA2773211C/en
Priority to PCT/US2010/046953 priority patent/WO2011034709A1/en
Priority to CN201080041508.6A priority patent/CN102498359B/zh
Priority to KR1020127009836A priority patent/KR20120069729A/ko
Priority to CA2772972A priority patent/CA2772972C/en
Priority to SG2012014445A priority patent/SG178603A1/en
Priority to JP2012529780A priority patent/JP5850838B2/ja
Priority to SG2012015392A priority patent/SG178989A1/en
Priority to AU2010308519A priority patent/AU2010308519B2/en
Priority to BR112012006277A priority patent/BR112012006277A2/pt
Priority to CA2773157A priority patent/CA2773157C/en
Priority to EA201200521A priority patent/EA028835B1/ru
Priority to EA201200524A priority patent/EA021947B1/ru
Priority to JP2012529779A priority patent/JP5793144B2/ja
Priority to BR112012006219A priority patent/BR112012006219A2/pt
Priority to PE2012000352A priority patent/PE20121420A1/es
Priority to NZ599331A priority patent/NZ599331A/en
Priority to AU2010295870A priority patent/AU2010295870A1/en
Priority to PCT/US2010/046966 priority patent/WO2011034710A1/en
Priority to PE2012000351A priority patent/PE20121421A1/es
Priority to PCT/US2010/046967 priority patent/WO2011049672A1/en
Priority to NZ599335A priority patent/NZ599335A/en
Priority to CN201080041905.3A priority patent/CN102575898B/zh
Priority to EA201200520A priority patent/EA024075B1/ru
Priority to JP2012529781A priority patent/JP5793145B2/ja
Priority to PE2012000349A priority patent/PE20121422A1/es
Priority to EP10817650A priority patent/EP2480845A1/en
Priority to KR1020127009963A priority patent/KR101619568B1/ko
Priority to CN201080041904.9A priority patent/CN102498360B/zh
Priority to MX2012002969A priority patent/MX2012002969A/es
Priority to MX2012002970A priority patent/MX351303B/es
Priority to KR1020127009964A priority patent/KR20120072373A/ko
Priority to EP10817651A priority patent/EP2480846A1/en
Priority to SG2012014452A priority patent/SG178933A1/en
Priority to MX2012002971A priority patent/MX348674B/es
Priority to AU2010295869A priority patent/AU2010295869B2/en
Priority to NZ599333A priority patent/NZ599333A/en
Priority to BR112012006279A priority patent/BR112012006279A2/pt
Priority to TW099131477A priority patent/TW201127471A/zh
Priority to TW099131475A priority patent/TW201111725A/zh
Priority to TW099131479A priority patent/TWI477595B/zh
Priority to SA110310705A priority patent/SA110310705B1/ar
Priority to SA110310706A priority patent/SA110310706B1/ar
Priority to SA110310707A priority patent/SA110310707B1/ar
Priority to ARP100103435 priority patent/AR078403A1/es
Priority to ARP100103433A priority patent/AR078401A1/es
Priority to ARP100103434A priority patent/AR078402A1/es
Assigned to ORTLOFF ENGINEERS, LTD. reassignment ORTLOFF ENGINEERS, LTD. ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: CUELLAR, KYLE T., MARTINEZ, TONY L., HUDSON, HANK M., LYNCH, JOE T., WILKINSON, JOHN D.
Publication of US20110067443A1 publication Critical patent/US20110067443A1/en
Priority to EG2012030439A priority patent/EG26970A/xx
Priority to EG2012030437A priority patent/EG27017A/xx
Priority to CL2012000700A priority patent/CL2012000700A1/es
Priority to CL2012000706A priority patent/CL2012000706A1/es
Priority to ZA2012/02634A priority patent/ZA201202634B/en
Priority to ZA2012/02633A priority patent/ZA201202633B/en
Priority to ZA2012/02696A priority patent/ZA201202696B/en
Priority to CO12064992A priority patent/CO6531456A2/es
Priority to CO12064988A priority patent/CO6531455A2/es
Priority to CO12065754A priority patent/CO6531461A2/es
Assigned to UOP LLC reassignment UOP LLC ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: ORTLOFF ENGINEERS, LTD.
Abandoned legal-status Critical Current

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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
    • 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
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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
    • F25J3/00—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification
    • 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
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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
    • 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
    • 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
    • F25J5/00—Arrangements of cold exchangers or cold accumulators in separation or liquefaction plants
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
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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
    • 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
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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
    • F25J2200/00—Processes or apparatus using separation by rectification
    • F25J2200/30—Processes or apparatus using separation by rectification using a side column in a single pressure column system
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
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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
    • 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
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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
    • F25J2200/00—Processes or apparatus using separation by rectification
    • F25J2200/76—Refluxing the column with condensed overhead gas being cycled in a quasi-closed loop refrigeration cycle
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
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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
    • F25J2200/00—Processes or apparatus using separation by rectification
    • F25J2200/78—Refluxing the column with a liquid stream originating from an upstream or downstream fractionator column
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
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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
    • F25J2200/00—Processes or apparatus using separation by rectification
    • F25J2200/90—Details relating to column internals, e.g. structured packing, gas or liquid distribution
    • 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
    • F25J2200/90—Details relating to column internals, e.g. structured packing, gas or liquid distribution
    • F25J2200/92—Details relating to the feed point
    • 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
    • F25J2200/90—Details relating to column internals, e.g. structured packing, gas or liquid distribution
    • F25J2200/94—Details relating to the withdrawal point
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
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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
    • F25J2205/00—Processes or apparatus using other separation and/or other processing means
    • F25J2205/02—Processes or apparatus using other separation and/or other processing means using simple phase separation in a vessel or drum
    • F25J2205/04—Processes or apparatus using other separation and/or other processing means using simple phase separation in a vessel or drum in the feed line, i.e. upstream of the fractionation step
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
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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
    • 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
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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
    • F25J2210/00—Processes characterised by the type or other details of the feed stream
    • F25J2210/60—Natural gas or synthetic natural gas [SNG]
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
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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
    • F25J2215/00—Processes characterised by the type or other details of the product stream
    • F25J2215/60—Methane
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
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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
    • F25J2230/00—Processes or apparatus involving steps for increasing the pressure of gaseous process streams
    • F25J2230/08—Cold compressor, i.e. suction of the gas at cryogenic temperature and generally without afterstage-cooler
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
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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
    • 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
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    • F25J2240/00—Processes or apparatus involving steps for expanding of process streams
    • F25J2240/02—Expansion of a process fluid in a work-extracting turbine (i.e. isentropic expansion), e.g. of the feed stream
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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
    • F25J2240/00—Processes or apparatus involving steps for expanding of process streams
    • F25J2240/40—Expansion without extracting work, i.e. isenthalpic throttling, e.g. JT valve, regulating valve or venturi, or isentropic nozzle, e.g. Laval
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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
    • F25J2270/00—Refrigeration techniques used
    • F25J2270/02—Internal refrigeration with liquid vaporising loop
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
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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
    • F25J2270/00—Refrigeration techniques used
    • F25J2270/12—External refrigeration with liquid vaporising loop
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
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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
    • F25J2290/00—Other details not covered by groups F25J2200/00 - F25J2280/00
    • F25J2290/12—Particular process parameters like pressure, temperature, ratios
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
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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
    • F25J2290/00—Other details not covered by groups F25J2200/00 - F25J2280/00
    • F25J2290/40—Vertical layout or arrangement of cold equipments within in the cold box, e.g. columns, condensers, heat exchangers etc.

Definitions

  • This invention relates to a process and an apparatus for the separation of a gas containing hydrocarbons.
  • Ethylene, ethane, propylene, propane, and/or heavier hydrocarbons can be recovered from a variety of gases, such as natural gas, refinery gas, and synthetic gas streams obtained from other hydrocarbon materials such as coal, crude oil, naphtha, oil shale, tar sands, and lignite.
  • Natural gas usually has a major proportion of methane and ethane, i.e., methane and ethane together comprise at least 50 mole percent of the gas.
  • the gas also contains relatively lesser amounts of heavier hydrocarbons such as propane, butanes, pentanes, and the like, as well as hydrogen, nitrogen, carbon dioxide, and other gases.
  • the present invention is generally concerned with the recovery of ethylene, ethane, propylene, propane, and heavier hydrocarbons from such gas streams.
  • a typical analysis of a gas stream to be processed in accordance with this invention would be, in approximate mole percent, 88.1% methane, 6.0% ethane and other C 2 components, 2.5% propane and other C 3 components, 0.2% iso-butane, 0.2% normal butane, and 0.5% pentanes plus, with the balance made up of nitrogen and carbon dioxide. Sulfur containing gases are also sometimes present.
  • a feed gas stream under pressure is cooled by heat exchange with other streams of the process and/or external sources of refrigeration such as a propane compression-refrigeration system.
  • liquids may be condensed and collected in one or more separators as high-pressure liquids containing some of the desired C 2 + components.
  • the high-pressure liquids may be expanded to a lower pressure and fractionated. The vaporization occurring during expansion of the liquids results in further cooling of the stream. Under some conditions, pre-cooling the high pressure liquids prior to the expansion may be desirable in order to further lower the temperature resulting from the expansion.
  • the expanded stream comprising a mixture of liquid and vapor, is fractionated in a distillation (demethanizer or deethanizer) column.
  • the expansion cooled stream(s) is (are) distilled to separate residual methane, nitrogen, and other volatile gases as overhead vapor from the desired C 2 components, C 3 components, and heavier hydrocarbon components as bottom liquid product, or to separate residual methane, C 2 components, nitrogen, and other volatile gases as overhead vapor from the desired C 3 components and heavier hydrocarbon components as bottom liquid product.
  • the vapor remaining from the partial condensation can be split into two streams.
  • One portion of the vapor is passed through a work expansion machine or engine, or an expansion valve, to a lower pressure at which additional liquids are condensed as a result of further cooling of the stream.
  • the pressure after expansion is essentially the same as the pressure at which the distillation column is operated.
  • the combined vapor-liquid phases resulting from the expansion are supplied as feed to the column.
  • the remaining portion of the vapor is cooled to substantial condensation by heat exchange with other process streams, e.g., the cold fractionation tower overhead.
  • Some or all of the high-pressure liquid may be combined with this vapor portion prior to cooling.
  • the resulting cooled stream is then expanded through an appropriate expansion device, such as an expansion valve, to the pressure at which the demethanizer is operated. During expansion, a portion of the liquid will vaporize, resulting in cooling of the total stream.
  • the flash expanded stream is then supplied as top feed to the demethanizer.
  • the vapor portion of the flash expanded stream and the demethanizer overhead vapor combine in an upper separator section in the fractionation tower as residual methane product gas.
  • the cooled and expanded stream may be supplied to a separator to provide vapor and liquid streams.
  • the vapor is combined with the tower overhead and the liquid is supplied to the column as a top column feed.
  • the residue gas leaving the process will contain substantially all of the methane in the feed gas with essentially none of the heavier hydrocarbon components, and the bottoms fraction leaving the demethanizer will contain substantially all of the heavier hydrocarbon components with essentially no methane or more volatile components.
  • this ideal situation is not obtained because the conventional demethanizer is operated largely as a stripping column.
  • the methane product of the process therefore, typically comprises vapors leaving the top fractionation stage of the column, together with vapors not subjected to any rectification step.
  • the preferred processes for hydrocarbon separation use an upper absorber section to provide additional rectification of the rising vapors.
  • the source of the reflux stream for the upper rectification section is typically a recycled stream of residue gas supplied under pressure.
  • the recycled residue gas stream is usually cooled to substantial condensation by heat exchange with other process streams, e.g., the cold fractionation tower overhead.
  • the resulting substantially condensed stream is then expanded through an appropriate expansion device, such as an expansion valve, to the pressure at which the demethanizer is operated. During expansion, a portion of the liquid will usually vaporize, resulting in cooling of the total stream.
  • the flash expanded stream is then supplied as top feed to the demethanizer.
  • the vapor portion of the expanded stream and the demethanizer overhead vapor combine in an upper separator section in the fractionation tower as residual methane product gas.
  • the cooled and expanded stream may be supplied to a separator to provide vapor and liquid streams, so that thereafter the vapor is combined with the tower overhead and the liquid is supplied to the column as a top column feed.
  • Typical process schemes of this type are disclosed in U.S. Pat. Nos. 4,889,545; 5,568,737; and 5,881,569; assignee's co-pending application Ser. No. 12/717,394; and in Mowrey, E.
  • the present invention also employs an upper rectification section (or a separate rectification column if plant size or other factors favor using separate rectification and stripping columns).
  • the reflux stream for this rectification section is provided by using a side draw of the vapors rising in a lower portion of the tower combined with a portion of the column overhead vapor. Because of the relatively high concentration of C 2 components in the vapors lower in the tower, a significant quantity of liquid can be condensed from this combined vapor stream with only a modest elevation in pressure, often using only the refrigeration available in the remaining portion of the cold overhead vapor leaving the upper rectification section of the column.
  • This condensed liquid which is predominantly liquid methane, can then be used to absorb C 2 components, C 3 components, C 4 components, and heavier hydrocarbon components from the vapors rising through the upper rectification section and thereby capture these valuable components in the bottom liquid product from the demethanizer.
  • the present invention makes possible essentially 100% separation of methane and lighter components from the C 2 components and heavier components at lower energy requirements compared to the prior art while maintaining the recovery levels.
  • the present invention although applicable at lower pressures and warmer temperatures, is particularly advantageous when processing feed gases in the range of 400 to 1500 psia [2,758 to 10,342 kPa(a)] or higher under conditions requiring NGL recovery column overhead temperatures of ⁇ 50° F. [ ⁇ 46° C.] or colder.
  • FIG. 1 is a flow diagram of a prior art natural gas processing plant in accordance with U.S. Pat. No. 4,889,545;
  • FIG. 2 is a flow diagram of a natural gas processing plant in accordance with the present invention.
  • FIGS. 3 through 6 are flow diagrams illustrating alternative means of application of the present invention to a natural gas stream.
  • FIG. 1 is a process flow diagram showing the design of a processing plant to recover C 2 + components from natural gas using prior art according to U.S. Pat. No. 4,889,545.
  • inlet gas enters the plant at 120° F. [49° C.] and 1040 psia [7,171 kPa(a)] as stream 31 .
  • the sulfur 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 cool residue gas (stream 43 a ), liquid product at 72° F. [22° C.] (stream 42 a ), demethanizer reboiler liquids at 52° F. [11° C.] (stream 41 ), and demethanizer side reboiler liquids at ⁇ 20° F. [ ⁇ 29° C.] (stream 40 ).
  • stream 43 a cool residue gas
  • stream 42 a liquid product at 72° F. [22° C.]
  • demethanizer reboiler liquids at 52° F. [11° C.]
  • demethanizer side reboiler liquids at ⁇ 20° F. [ ⁇ 29° C.]
  • the cooled stream 31 a enters separator 11 at ⁇ 18° F. [ ⁇ 28° C.] and 1025 psia [7,067 kPa(a)] where the vapor (stream 32 ) is separated from the condensed liquid (stream 33 ).
  • the separator liquid (stream 33 ) is expanded to the operating pressure (approximately 392 psia [2,701 kPa(a)]) of fractionation tower 17 by expansion valve 16 , cooling stream 33 a to ⁇ 53° F. [ ⁇ 47° C.] before it is supplied to fractionation tower 17 at a lower mid-column feed point.
  • the vapor (stream 32 ) from separator 11 is divided into two streams, 36 and 37 .
  • Stream 36 containing about 38% of the total vapor, passes through heat exchanger 12 in heat exchange relation with the cold residue gas (stream 43 ) where it is cooled to substantial condensation.
  • the resulting substantially condensed stream 36 a at ⁇ 142° F. [ ⁇ 96° C.] is then flash expanded through expansion valve 13 to slightly above the operating pressure of fractionation tower 17 . During expansion a portion of the stream is vaporized, resulting in cooling of the total stream.
  • the expanded stream 36 b leaving expansion valve 13 reaches a temperature of ⁇ 144° F. [ ⁇ 98° C.].
  • the expanded stream 36 b is warmed to ⁇ 139° F.
  • the remaining 62% of the vapor from separator 11 enters a work expansion machine 14 in which mechanical energy is extracted from this portion of the high pressure feed.
  • the machine 14 expands the vapor substantially isentropically to the tower operating pressure, with the work expansion cooling the expanded stream 37 a to a temperature of approximately ⁇ 94° F. [ ⁇ 70° 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 15 ) that can be used to re-compress the residue gas (stream 43 b ), for example.
  • the partially condensed expanded stream 37 a is thereafter supplied as feed to fractionation tower 17 at a mid-column feed point.
  • the demethanizer in tower 17 is a conventional distillation column containing a plurality of vertically spaced trays, one or more packed beds, or some combination of trays and packing.
  • the demethanizer tower consists of two sections: an upper absorbing (rectification) section 17 a that contains the trays and/or packing to provide the necessary contact between the vapor portions of the expanded streams 36 c and 37 a rising upward and cold liquid falling downward to condense and absorb the C 2 components, C 3 components, and heavier components; and a lower, stripping section 17 b that contains the trays and/or packing to provide the necessary contact between the liquids falling downward and the vapors rising upward.
  • an upper absorbing (rectification) section 17 a that contains the trays and/or packing to provide the necessary contact between the vapor portions of the expanded streams 36 c and 37 a rising upward and cold liquid falling downward to condense and absorb the C 2 components, C 3 components, and heavier components
  • a lower, stripping section 17 b that contains the trays and/or
  • the demethanizing section 17 b also includes one or more reboilers (such as the reboiler and side reboiler described previously) which heat and vaporize a portion of the liquids flowing down the column to provide the stripping vapors which flow up the column to strip the liquid product, stream 42 , of methane and lighter components.
  • Stream 37 a enters demethanizer 17 at an intermediate feed position located in the lower region of absorbing section 17 a of demethanizer 17 .
  • the liquid portion of the expanded stream 37 a commingles with liquids falling downward from absorbing section 17 a and the combined liquid continues downward into stripping section 17 b of demethanizer 17 .
  • the vapor portion of the expanded stream 37 a rises upward through absorbing section 17 a and is contacted with cold liquid falling downward to condense and absorb the C 2 components, C 3 components, and heavier components.
  • the feed streams are stripped of their methane and lighter components.
  • the resulting liquid product (stream 42 ) exits the bottom of tower 17 at 67° F. [19° C.] (based on a typical specification of a methane to ethane ratio of 0.015:1 on a volume basis in the bottom product) and is pumped to heat exchanger 10 by pump 20 to be heated to 116° F. [47° C.] as it provides cooling to the feed gas as described earlier.
  • Cold demethanizer overhead stream 39 exits the top of demethanizer 17 at ⁇ 146° F. [ ⁇ 99° C.] and is divided into cold residue gas stream 43 and recycle stream 44 .
  • Recycle stream 44 is compressed to 492 psia [3,390 kPa(a)] by compressor 21 before entering heat exchanger 22 .
  • the compressed recycle stream 44 a is cooled from ⁇ 121° F. [ ⁇ 85° C.] to ⁇ 140° F. [ ⁇ 96° C.] and substantially condensed by heat exchange with expanded substantially condensed stream 36 b as described previously.
  • the substantially condensed stream 44 b is then expanded through an appropriate expansion device, such as expansion valve 23 , to the demethanizer operating pressure, resulting in cooling of the total stream to ⁇ 150° F. [ ⁇ 101° C.].
  • the expanded stream 44 c is then supplied to fractionation tower 17 as the top column feed.
  • the vapor portion of stream 44 c combines with the vapors rising from the top fractionation stage of the column to form demethanizer overhead stream 39 .
  • the cold residue gas stream 43 passes countercurrently to the incoming feed gas in heat exchanger 12 where it is heated to ⁇ 26° F. [ ⁇ 32° C.] (stream 43 a ) and in heat exchanger 10 where it is heated to 98° F. [37° C.] (stream 43 b ).
  • the residue gas is then re-compressed in two stages.
  • the first stage is compressor 15 driven by expansion machine 14 .
  • the second stage is compressor 24 driven by a supplemental power source which compresses the residue gas (stream 43 d ) to sales line pressure. After cooling to 120° F.
  • the residue gas product (stream 43 e ) flows to the sales gas pipeline at 1040 psia [7,171 kPa(a)], sufficient to meet line requirements (usually on the order of the inlet pressure).
  • FIG. 2 illustrates a flow diagram of a process in accordance with the present invention.
  • the feed gas composition and conditions considered in the process presented in FIG. 2 are the same as those in FIG. 1 . Accordingly, the FIG. 2 process can be compared with that of the FIG. 1 process to illustrate the advantages of the present invention.
  • inlet gas enters the plant at 120° F. [49° C.] and 1040 psia [7,171 kPa(a)] as stream 31 and is cooled in heat exchanger 10 by heat exchange with cool residue gas (stream 43 a ), liquid product at 74° F. [24° C.] (stream 42 a ), demethanizer reboiler liquids at 54° F. [12° C.] (stream 41 ), and demethanizer side reboiler liquids at ⁇ 19° F. [ ⁇ 28° C.] (stream 40 ).
  • the cooled stream 31 a enters separator 11 at ⁇ 24° F.
  • the vapor (stream 32 ) from separator 11 is divided into two streams, 34 and 37 .
  • Stream 34 containing about 28% of the total vapor, passes through heat exchanger 12 in heat exchange relation with the cold residue gas (stream 43 ) where it is cooled to substantial condensation.
  • the resulting substantially condensed stream 36 a at ⁇ 140° F. [ ⁇ 96° C.] is then flash expanded through expansion valve 13 to the operating pressure of fractionation tower 17 . During expansion a portion of the stream is vaporized, resulting in cooling of the total stream.
  • the expanded stream 36 b leaving expansion valve 13 reaches a temperature of ⁇ 144° F. [ ⁇ 98° C.] before it is supplied at an upper mid-column feed point, in absorbing section 17 a of fractionation tower 17 .
  • the remaining 72% of the vapor from separator 11 enters a work expansion machine 14 in which mechanical energy is extracted from this portion of the high pressure feed.
  • the machine 14 expands the vapor substantially isentropically to the tower operating pressure, with the work expansion cooling the expanded stream 37 a to a temperature of approximately ⁇ 97° F. [ ⁇ 72° C.].
  • the partially condensed expanded stream 37 a is thereafter supplied as feed to fractionation tower 17 at a mid-column feed point (located below the feed point of stream 36 b ).
  • the demethanizer in tower 17 is a conventional distillation column containing a plurality of vertically spaced trays, one or more packed beds, or some combination of trays and packing.
  • the demethanizer tower consists of two sections: an upper absorbing (rectification) section 17 a that contains the trays and/or packing to provide the necessary contact between the vapor portion of the expanded streams 36 b and 37 a rising upward and cold liquid falling downward to condense and absorb the C 2 components, C 3 components, and heavier components from the vapors rising upward; and a lower, stripping section 17 b that contains the trays and/or packing to provide the necessary contact between the liquids falling downward and the vapors rising upward.
  • an upper absorbing (rectification) section 17 a that contains the trays and/or packing to provide the necessary contact between the vapor portion of the expanded streams 36 b and 37 a rising upward and cold liquid falling downward to condense and absorb the C 2 components, C 3 components, and heavier components from the vapors rising upward
  • the demethanizing section 17 b also includes one or more reboilers (such as the reboiler and side reboiler described previously) which heat and vaporize a portion of the liquids flowing down the column to provide the stripping vapors which flow up the column to strip the liquid product, stream 42 , of methane and lighter components.
  • Stream 37 a enters demethanizer 17 at an intermediate feed position located in the lower region of absorbing section 17 a of demethanizer 17 .
  • the liquid portion of the expanded stream 37 a commingles with liquids falling downward from absorbing section 17 a and the combined liquid continues downward into stripping section 17 b of demethanizer 17 .
  • the vapor portion of the expanded stream 37 a rises upward through absorbing section 17 a and is contacted with cold liquid falling downward to condense and absorb the C 2 components, C 3 components, and heavier components.
  • a portion of the distillation vapor (stream 45 ) is withdrawn from the upper region of absorbing section 17 a in fractionation column 17 , above the feed position of expanded stream 36 b in the middle region of absorbing section 17 a .
  • the distillation vapor stream 45 at ⁇ 142° F. [ ⁇ 96° C.] is combined with a first portion (stream 44 ) of overhead vapor stream 39 at ⁇ 144° F. [ ⁇ 98° C.] to form combined vapor stream 46 at ⁇ 144° F. [ ⁇ 98° C.].
  • the combined vapor stream 46 is compressed to 686 psia [4,728 kPa(a)] by reflux compressor 21 , then cooled from ⁇ 84° F. [ ⁇ 65° C.] to ⁇ 140° F. [ ⁇ 96° C.] and substantially condensed (stream 46 b ) in heat exchanger 12 by heat exchange with cold residue gas stream 43 , the remaining second portion of demethanizer overhead stream 39 exiting the top of demethanizer 17 .
  • the substantially condensed stream 46 b is flash expanded to the operating pressure of demethanizer 17 by expansion valve 23 . A portion of the stream is vaporized, further cooling stream 46 c to ⁇ 149° F. [ ⁇ 101° C.] before it is supplied as cold top column feed (reflux) to demethanizer 17 .
  • This cold liquid reflux absorbs and condenses the C 2 components, C 3 components, and heavier components rising in the upper rectification region of absorbing section 17 a of demethanizer 17 .
  • the feed streams are stripped of their methane and lighter components.
  • the resulting liquid product (stream 42 ) exits the bottom of tower 17 at 69° F. [21° C.] (based on a typical specification of a methane to ethane ratio of 0.015:1 on a volume basis in the bottom product) and is pumped to heat exchanger 10 by pump 20 to be heated to 116° F. [47° C.] as it provides cooling to the feed gas as described earlier.
  • the cold residue gas stream 43 passes countercurrently to the incoming feed gas and compressed combined vapor stream in heat exchanger 12 where it is heated to ⁇ 37° F.
  • stream 43 a [ ⁇ 39° C.] (stream 43 a ), and countercurrently to the incoming feed gas in heat exchanger 10 where it is heated to 97° F. [36° C.] (stream 43 b ) as it provides cooling as previously described.
  • the residue gas is then re-compressed in two stages, compressor 15 driven by expansion machine 14 and compressor 24 driven by a supplemental power source.
  • stream 43 d is cooled to 120° F. [49° C.] in discharge cooler 25
  • the residue gas product (stream 43 e ) flows to the sales gas pipeline at 1040 psia [7,171 kPa(a)], sufficient to meet line requirements (usually on the order of the inlet pressure).
  • the present invention uses the expanded substantially condensed feed stream 36 b supplied to absorbing section 17 a of demethanizer 17 to provide bulk recovery of the C 2 components, C 3 components, and heavier hydrocarbon components contained in expanded feed 37 a and the vapors rising from stripping section 17 b , and the supplemental rectification provided by reflux stream 46 c to reduce the amount of C 2 components, C 3 components, and C 4 + components contained in the inlet feed gas that is lost to the residue gas.
  • the present invention reduces the rectification required in absorbing section 17 a over that of the prior art FIG.
  • the absorbing (rectification) section of the demethanizer it is generally advantageous to design the absorbing (rectification) section of the demethanizer to contain multiple theoretical separation stages.
  • the benefits of the present invention can be achieved with as few as two theoretical stages.
  • all or a part of the expanded reflux stream (stream 46 c ) leaving expansion valve 23 and all or a part of the expanded substantially condensed stream 36 b from expansion valve 13 can be combined (such as in the piping joining the expansion valves to the demethanizer) and if thoroughly intermingled, the vapors and liquids will mix together and separate in accordance with the relative volatilities of the various components of the total combined streams.
  • Such commingling of the two streams, combined with contacting at least a portion of expanded stream 37 a shall be considered for the purposes of this invention as constituting an absorbing section.
  • FIGS. 3 through 6 display other embodiments of the present invention.
  • FIGS. 2 through 4 depict fractionation towers constructed in a single vessel.
  • FIGS. 5 and 6 depict fractionation towers constructed in two vessels, absorber (rectifier) column 17 (a contacting and separating device) and stripper (distillation) column 19 .
  • the overhead vapor stream 48 from stripper column 19 flows to the lower section of absorber column 17 (via stream 49 ) to be contacted by reflux stream 46 c and expanded substantially condensed stream 36 b .
  • Pump 18 is used to route the liquids (stream 47 ) from the bottom of absorber column 17 to the top of stripper column 19 so that the two towers effectively function as one distillation system.
  • the decision whether to construct the fractionation tower as a single vessel (such as demethanizer 17 in FIGS. 2 through 4 ) or multiple vessels will depend on a number of factors such as plant size, the distance to fabrication facilities, etc.
  • the compressed combined vapor stream 46 a is substantially condensed and the resulting condensate used to absorb valuable C 2 components, C 3 components, and heavier components from the vapors rising through absorbing section 17 a of demethanizer 17 or through absorber column 17 .
  • the present invention is not limited to this embodiment. It may be advantageous, for instance, to treat only a portion of these vapors in this manner, or to use only a portion of the condensate as an absorbent, in cases where other design considerations indicate portions of the vapors or the condensate should bypass absorbing section 17 a of demethanizer 17 or absorber column 17 . Some circumstances may favor partial condensation, rather than substantial condensation, of compressed combined vapor stream 46 a in heat exchanger 12 .
  • distillation vapor stream 45 be a total vapor side draw from fractionation column 17 or absorber column 17 rather than a partial vapor side draw. It should also be noted that, depending on the composition of the feed gas stream, it may be advantageous to use external refrigeration to provide partial cooling of compressed combined vapor stream 46 a in heat exchanger 12 .
  • Feed gas conditions, plant size, available equipment, or other factors may indicate that elimination of work expansion machine 14 , or replacement with an alternate expansion device (such as an expansion valve), is feasible.
  • an alternate expansion device such as an expansion valve
  • alternative expansion means may be employed where appropriate. For example, conditions may warrant work expansion of the substantially condensed portion of the feed stream (stream 36 a ) or the substantially condensed reflux stream (stream 46 b ) leaving heat exchanger 12 .
  • the cooled feed stream 31 a leaving heat exchanger 10 in FIGS. 2 through 6 may not contain any liquid (because it is above its dewpoint, or because it is above its cricondenbar). In such cases, separator 11 shown in FIGS. 2 through 6 is not required.
  • the high pressure liquid (stream 33 in FIGS. 2 through 6 ) need not be expanded and fed to a mid-column feed point on the distillation column. Instead, all or a portion of it may be combined with the portion of the separator vapor (stream 34 ) flowing to heat exchanger 12 . (This is shown by the dashed stream 35 in FIGS. 2 through 6 .) Any remaining portion of the liquid may be expanded through an appropriate expansion device, such as an expansion valve or expansion machine, and fed to a mid-column feed point on the distillation column (stream 38 a in FIGS. 2 through 6 ). Stream 38 may also be used for inlet gas cooling or other heat exchange service before or after the expansion step prior to flowing to the demethanizer.
  • the use of external refrigeration to supplement the cooling available to the inlet gas from other process streams may be employed, particularly in the case of a rich inlet gas.
  • the use and distribution of separator liquids and demethanizer side draw liquids for process heat exchange, and the particular arrangement of heat exchangers for inlet gas cooling must be evaluated for each particular application, as well as the choice of process streams for specific heat exchange services.
  • the splitting of the vapor feed may be accomplished in several ways. In the processes of FIGS. 2 , 3 , and 5 , the splitting of vapor occurs following cooling and separation of any liquids which may have been formed. The high pressure gas may be split, however, prior to any cooling of the inlet gas as shown in FIGS. 4 and 6 . In some embodiments, vapor splitting may be effected in a separator.
  • the relative amount of feed found in each branch of the split vapor feed will depend on several factors, including gas pressure, feed gas composition, the amount of heat which can economically be extracted from the feed, and the quantity of horsepower available. More feed to the top of the column may increase recovery while decreasing power recovered from the expander thereby increasing the recompression horsepower requirements. Increasing feed lower in the column reduces the horsepower consumption but may also reduce product recovery.
  • the relative locations of the mid-column feeds may vary depending on inlet composition or other factors such as desired recovery levels and amount of liquid formed during inlet gas cooling.
  • two or more of the feed streams, or portions thereof may be combined depending on the relative temperatures and quantities of individual streams, and the combined stream then fed to a mid-column feed position.
  • the present invention provides improved recovery of C 2 components, C 3 components, and heavier hydrocarbon components or of C 3 components and heavier hydrocarbon components per amount of utility consumption required to operate the process.
  • An improvement in utility consumption required for operating the demethanizer or deethanizer process may appear in the form of reduced power requirements for compression or re-compression, reduced power requirements for external refrigeration, reduced energy requirements for tower reboilers, or a combination thereof.

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Priority Applications (59)

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US12/869,139 US20110067443A1 (en) 2009-09-21 2010-08-26 Hydrocarbon Gas Processing
EP10825365.9A EP2480847A4 (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
CA2773211A CA2773211C (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
PCT/US2010/046953 WO2011034709A1 (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
CN201080041508.6A CN102498359B (zh) 2009-09-21 2010-08-27 碳氢化合物气体处理
KR1020127009836A KR20120069729A (ko) 2009-09-21 2010-08-27 탄화수소 가스 처리공정
CA2772972A CA2772972C (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
SG2012014445A SG178603A1 (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
JP2012529780A JP5850838B2 (ja) 2009-09-21 2010-08-27 炭化水素ガス処理
SG2012015392A SG178989A1 (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
AU2010308519A AU2010308519B2 (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
BR112012006277A BR112012006277A2 (pt) 2009-09-21 2010-08-27 processamento de hidrocarbonetos gasosos
CA2773157A CA2773157C (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
EA201200521A EA028835B1 (ru) 2009-09-21 2010-08-27 Переработка углеводородного газа
EA201200524A EA021947B1 (ru) 2009-09-21 2010-08-27 Переработка углеводородного газа
JP2012529779A JP5793144B2 (ja) 2009-09-21 2010-08-27 炭化水素ガス処理
BR112012006219A BR112012006219A2 (pt) 2009-09-21 2010-08-27 processamento de hicrocarbonetos gasosos.
PE2012000352A PE20121420A1 (es) 2009-09-21 2010-08-27 Procesamiento de gases de hidrocarburos
NZ599331A NZ599331A (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
AU2010295870A AU2010295870A1 (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
PCT/US2010/046966 WO2011034710A1 (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
PE2012000351A PE20121421A1 (es) 2009-09-21 2010-08-27 Procesamiento de gases de hidrocarburos
PCT/US2010/046967 WO2011049672A1 (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
NZ599335A NZ599335A (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
CN201080041905.3A CN102575898B (zh) 2009-09-21 2010-08-27 碳氢化合物气体处理
EA201200520A EA024075B1 (ru) 2009-09-21 2010-08-27 Переработка углеводородного газа
JP2012529781A JP5793145B2 (ja) 2009-09-21 2010-08-27 炭化水素ガス処理
PE2012000349A PE20121422A1 (es) 2009-09-21 2010-08-27 Procesamiento de gases de hidrocarburos
EP10817650A EP2480845A1 (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
KR1020127009963A KR101619568B1 (ko) 2009-09-21 2010-08-27 탄화수소 가스 처리공정
CN201080041904.9A CN102498360B (zh) 2009-09-21 2010-08-27 碳氢化合物气体处理
MX2012002969A MX2012002969A (es) 2009-09-21 2010-08-27 Procesamiento de gases de hidrocarburos.
MX2012002970A MX351303B (es) 2009-09-21 2010-08-27 Procesamiento de gases de hidrocarburos.
KR1020127009964A KR20120072373A (ko) 2009-09-21 2010-08-27 탄화수소 가스 처리공정
EP10817651A EP2480846A1 (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
SG2012014452A SG178933A1 (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
MX2012002971A MX348674B (es) 2009-09-21 2010-08-27 Procesamiento de gases de hidrocarburos.
AU2010295869A AU2010295869B2 (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
NZ599333A NZ599333A (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
BR112012006279A BR112012006279A2 (pt) 2009-09-21 2010-08-27 processamento de gás de hidrocarboneto
TW099131477A TW201127471A (en) 2009-09-21 2010-09-16 Hydrocarbon gas processing
TW099131475A TW201111725A (en) 2009-09-21 2010-09-16 Hydrocarbon gas processing
TW099131479A TWI477595B (zh) 2009-09-21 2010-09-16 碳氫化合物氣體處理
SA110310705A SA110310705B1 (ar) 2009-09-21 2010-09-20 معالجة غاز هيدروكربونى
SA110310706A SA110310706B1 (ar) 2009-09-21 2010-09-20 معالجة غازهيدروكربونى
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ARP100103435 AR078403A1 (es) 2010-05-19 2010-09-21 Procesamiento de gases de hidrocarburos
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CL2012000700A CL2012000700A1 (es) 2009-09-21 2012-03-21 Proceso y aparato para separar una corriente de gas que contiene metano, c2, c3 e hidrocarburos más pesados en una fracción de gas residual volatil y una fraccion relativamente menos volatil.
CL2012000706A CL2012000706A1 (es) 2009-09-21 2012-03-21 Proceso para separar una corriente de gas que contiene metano, c2, c3 e hidrocarburos más pesados en una fracción de gas residual volatil y una fraccion relativamente menos volatil.
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