US20110067441A1 - Hydrocarbon Gas Processing - Google Patents

Hydrocarbon Gas Processing Download PDF

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Publication number
US20110067441A1
US20110067441A1 US12/868,993 US86899310A US2011067441A1 US 20110067441 A1 US20110067441 A1 US 20110067441A1 US 86899310 A US86899310 A US 86899310A US 2011067441 A1 US2011067441 A1 US 2011067441A1
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US
United States
Prior art keywords
stream
vapor stream
distillation
receive
column
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
US12/868,993
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 US12/868,993 priority Critical patent/US20110067441A1/en
Priority to BR112012006279A priority patent/BR112012006279A2/pt
Priority to KR1020127009964A priority patent/KR20120072373A/ko
Priority to EP10817650A priority patent/EP2480845A1/en
Priority to AU2010308519A priority patent/AU2010308519B2/en
Priority to BR112012006219A priority patent/BR112012006219A2/pt
Priority to EA201200524A priority patent/EA021947B1/ru
Priority to PE2012000352A priority patent/PE20121420A1/es
Priority to JP2012529779A priority patent/JP5793144B2/ja
Priority to PCT/US2010/046953 priority patent/WO2011034709A1/en
Priority to EA201200521A priority patent/EA028835B1/ru
Priority to EP10817651A priority patent/EP2480846A1/en
Priority to NZ599331A priority patent/NZ599331A/en
Priority to JP2012529781A priority patent/JP5793145B2/ja
Priority to EP10825365.9A priority patent/EP2480847A4/en
Priority to NZ599333A priority patent/NZ599333A/en
Priority to SG2012014452A priority patent/SG178933A1/en
Priority to CA2773211A priority patent/CA2773211C/en
Priority to PCT/US2010/046967 priority patent/WO2011049672A1/en
Priority to CN201080041904.9A priority patent/CN102498360B/zh
Priority to CN201080041508.6A priority patent/CN102498359B/zh
Priority to KR1020127009963A priority patent/KR101619568B1/ko
Priority to AU2010295870A priority patent/AU2010295870A1/en
Priority to BR112012006277A priority patent/BR112012006277A2/pt
Priority to EA201200520A priority patent/EA024075B1/ru
Priority to MX2012002969A priority patent/MX2012002969A/es
Priority to JP2012529780A priority patent/JP5850838B2/ja
Priority to PE2012000349A priority patent/PE20121422A1/es
Priority to SG2012014445A priority patent/SG178603A1/en
Priority to PE2012000351A priority patent/PE20121421A1/es
Priority to CA2772972A priority patent/CA2772972C/en
Priority to MX2012002970A priority patent/MX351303B/es
Priority to PCT/US2010/046966 priority patent/WO2011034710A1/en
Priority to MX2012002971A priority patent/MX348674B/es
Priority to NZ599335A priority patent/NZ599335A/en
Priority to SG2012015392A priority patent/SG178989A1/en
Priority to CA2773157A priority patent/CA2773157C/en
Priority to KR1020127009836A priority patent/KR20120069729A/ko
Priority to CN201080041905.3A priority patent/CN102575898B/zh
Priority to AU2010295869A priority patent/AU2010295869B2/en
Priority to TW099131477A priority patent/TW201127471A/zh
Priority to TW099131475A priority patent/TW201111725A/zh
Priority to TW099131479A priority patent/TWI477595B/zh
Priority to SA110310707A priority patent/SA110310707B1/ar
Priority to SA110310705A priority patent/SA110310705B1/ar
Priority to SA110310706A priority patent/SA110310706B1/ar
Priority to ARP100103433A priority patent/AR078401A1/es
Priority to ARP100103435 priority patent/AR078403A1/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 US20110067441A1 publication Critical patent/US20110067441A1/en
Priority to EG2012030439A priority patent/EG26970A/xx
Priority to EG2012030437A priority patent/EG27017A/xx
Priority to CL2012000687A priority patent/CL2012000687A1/es
Priority to CL2012000706A priority patent/CL2012000706A1/es
Priority to CL2012000700A priority patent/CL2012000700A1/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
    • 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
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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
    • 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
    • F25J2200/30—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
    • 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
    • F25J2200/76—Refluxing the column with condensed overhead gas being cycled in a quasi-closed loop refrigeration 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
    • 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
    • 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
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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
    • 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
    • F25J2270/02—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, 80.8% methane, 9.4% ethane and other C 2 components, 4.7% propane and other C 3 components, 1.2% iso-butane, 2.1% normal butane, and 1.1% 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. 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 in this side draw stream without elevating its pressure, often using only the refrigeration available in the cold vapor leaving the upper rectification section and the flash expanded substantially condensed stream.
  • 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 provides the further advantage of being able to maintain in excess of 99% recovery of the C 3 and C 4 + components as the recovery of C 2 components is adjusted from high to low values.
  • the present invention makes possible essentially 100% separation of methane and lighter components from the C 2 components and heavier components at the same energy requirements compared to the prior art while increasing 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. 5,890,378;
  • FIG. 2 is a flow diagram of a prior art natural gas processing plant in accordance with U.S. Pat. No. 7,191,617;
  • FIG. 3 is a flow diagram of a prior art natural gas processing plant in accordance with assignee's co-pending application Ser. No. 12/206,230;
  • FIG. 4 is a flow diagram of a natural gas processing plant in accordance with the present invention.
  • FIGS. 5 through 8 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. 5,890,378.
  • inlet gas enters the plant at 85° F. [29° C.] and 970 psia [6,688 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 45 b ), demethanizer lower side reboiler liquids at 32° F. [0° C.] (stream 40 ), and propane refrigerant.
  • 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 a enters separator 11 at 0° F.
  • the vapor (stream 32 ) from separator 11 is further cooled in heat exchanger 13 by heat exchange with cool residue gas (stream 45 a ) and demethanizer upper side reboiler liquids at ⁇ 39° F. [ ⁇ 39° C.] (stream 39 ).
  • the cooled stream 32 a enters separator 14 at ⁇ 31° F. [ ⁇ 35° C.] and 950 psia [6,550 kPa(a)] where the vapor (stream 34 ) is separated from the condensed liquid (stream 37 ).
  • the separator liquid (stream 37 ) is expanded to the tower operating pressure by expansion valve 19 , cooling stream 37 a to ⁇ 66° F. [ ⁇ 54° C.] before it is supplied to fractionation tower 20 at a second lower mid-column feed point.
  • the vapor (stream 34 ) from separator 14 is divided into two streams, 35 and 36 .
  • Stream 35 containing about 39% of the total vapor, passes through heat exchanger 15 in heat exchange relation with the cold residue gas (stream 45 ) where it is cooled to substantial condensation.
  • the resulting substantially condensed stream 35 a at ⁇ 123° F. [ ⁇ 86° C.] is then flash expanded through expansion valve 16 to slightly above the operating pressure of fractionation tower 20 . During expansion a portion of the stream is vaporized, resulting in cooling of the total stream.
  • the expanded stream 35 b leaving expansion valve 16 reaches a temperature of ⁇ 130° F. [ ⁇ 90° C.].
  • the expanded stream 35 b is warmed to ⁇ 126° F.
  • the remaining 61% of the vapor from separator 14 enters a work expansion machine 17 in which mechanical energy is extracted from this portion of the high pressure feed.
  • the machine 17 expands the vapor substantially isentropically to the tower operating pressure, with the work expansion cooling the expanded stream 36 a to a temperature of approximately ⁇ 86° F. [ ⁇ 66° 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 18 ) that can be used to re-compress the residue gas (stream 45 c ), for example.
  • the partially condensed expanded stream 36 a is thereafter supplied as feed to fractionation tower 20 at a mid-column feed point.
  • the demethanizer in tower 20 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 20 a that contains the trays and/or packing to provide the necessary contact between the vapor portions of the expanded streams 35 c and 36 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 20 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 20 a that contains the trays and/or packing to provide the necessary contact between the vapor portions of the expanded streams 35 c and 36 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 20 b that contains the trays and/or
  • the demethanizing section 20 b also includes one or more reboilers (such as reboiler 21 and the side reboilers 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 41 , of methane and lighter components.
  • Stream 36 a enters demethanizer 20 at an intermediate feed position located in the lower region of absorbing section 20 a of demethanizer 20 .
  • the liquid portion of the expanded stream 36 a comingles with liquids falling downward from absorbing section 20 a and the combined liquid continues downward into stripping section 20 b of demethanizer 20 .
  • the vapor portion of the expanded stream 36 a rises upward through absorbing section 20 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 42 ) is withdrawn from the upper region of stripping section 20 b .
  • This stream is then cooled and partially condensed (stream 42 a ) in exchanger 22 by heat exchange with expanded substantially condensed stream 35 b as described previously, cooling stream 42 from ⁇ 96° F. [ ⁇ 71° C.] to about ⁇ 128° F. [ ⁇ 89° C.] (stream 42 a ).
  • the operating pressure (441 psia [3,038 kPa(a)]) in reflux separator 23 is maintained slightly below the operating pressure of demethanizer 20 . This provides the driving force which causes distillation vapor stream 42 to flow through heat exchanger 22 and thence into the reflux separator 23 where the condensed liquid (stream 44 ) is separated from any uncondensed vapor (stream 43 ).
  • the liquid stream 44 from reflux separator 23 is pumped by pump 24 to a pressure slightly above the operating pressure of demethanizer 20 , and stream 44 a is then supplied as cold top column feed (reflux) to demethanizer 20 at ⁇ 128° F. [ ⁇ 89° C.].
  • This cold liquid reflux absorbs and condenses the C 3 components and heavier components rising in the upper rectification region of absorbing section 20 a of demethanizer 20 .
  • the liquid product stream 41 exits the bottom of the tower at 112° F. [44° C.], based on a typical specification of a methane to ethane ratio of 0.025:1 on a molar basis in the bottom product.
  • Cold demethanizer overhead stream 38 exits the top of demethanizer 20 at ⁇ 128° F. [ ⁇ 89° C.] and combines with vapor stream 43 to form cold residue gas stream 45 at ⁇ 128° F. [ ⁇ 89° C.].
  • the cold residue gas stream 45 passes countercurrently to the incoming feed gas in heat exchanger 15 where it is heated to ⁇ 37° F. [ ⁇ 38° C.] (stream 45 a ), in heat exchanger 13 where it is heated to ⁇ 5° F.
  • stream 45 b [ ⁇ 21° C.] (stream 45 b ), and in heat exchanger 10 where it is heated to 80° F. [27° C.] (stream 45 c ).
  • the residue gas is then re-compressed in two stages.
  • the first stage is compressor 18 driven by expansion machine 17 .
  • the second stage is compressor 25 driven by a supplemental power source which compresses the residue gas (stream 45 d ) to sales line pressure.
  • the residue gas product (stream 451 ) flows to the sales gas pipeline at 1015 psia [6,998 kPa(a)], sufficient to meet line requirements (usually on the order of the inlet pressure).
  • FIG. 2 represents an alternative prior art process according to U.S. Pat. No. 7,191,617.
  • the process of FIG. 2 has been applied to the same feed gas composition and conditions as described above for FIG. 1 .
  • operating conditions were selected to minimize energy consumption for a given recovery level.
  • inlet gas enters the plant as stream 31 and is cooled in heat exchanger 10 by heat exchange with cool residue gas (stream 45 b ), demethanizer lower side reboiler liquids at 33° F. [0° C.] (stream 40 ), and propane refrigerant.
  • the cooled stream 31 a enters separator 11 at 0° F. [ ⁇ 18° C.] and 955 psia [6,584 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 450 psia [3,103 kPa(a)]) of fractionation tower 20 by expansion valve 12 , cooling stream 33 a to ⁇ 27° F. [ ⁇ 33° C.] before it is supplied to fractionation tower 20 at a first lower mid-column feed point.
  • the vapor (stream 32 ) from separator 11 is further cooled in heat exchanger 13 by heat exchange with cool residue gas (stream 45 a ) and demethanizer upper side reboiler liquids at ⁇ 38° F. [ ⁇ 39° C.] (stream 39 ).
  • the cooled stream 32 a enters separator 14 at ⁇ 29° F. [ ⁇ 34° C.] and 950 psia [6,550 kPa(a)] where the vapor (stream 34 ) is separated from the condensed liquid (stream 37 ).
  • the separator liquid (stream 37 ) is expanded to the tower operating pressure by expansion valve 19 , cooling stream 37 a to ⁇ 64° F. [ ⁇ 53° C.] before it is supplied to fractionation tower 20 at a second lower mid-column feed point.
  • the vapor (stream 34 ) from separator 14 is divided into two streams, 35 and 36 .
  • Stream 35 containing about 37% of the total vapor, passes through heat exchanger 15 in heat exchange relation with the cold residue gas (stream 45 ) where it is cooled to substantial condensation.
  • the resulting substantially condensed stream 35 a at ⁇ 115° F. [ ⁇ 82° C.] is then flash expanded through expansion valve 16 to the operating pressure of fractionation tower 20 .
  • expansion valve 16 During expansion a portion of the stream is vaporized, resulting in cooling of stream 35 b to ⁇ 129° F. [ ⁇ 89° C.] before it is supplied to fractionation tower 20 at an upper mid-column feed point.
  • the remaining 63% of the vapor from separator 14 enters a work expansion machine 17 in which mechanical energy is extracted from this portion of the high pressure feed.
  • the machine 17 expands the vapor substantially isentropically to the tower operating pressure, with the work expansion cooling the expanded stream 36 a to a temperature of approximately ⁇ 84° F. [ ⁇ 65° C.].
  • the partially condensed expanded stream 36 a is thereafter supplied as feed to fractionation tower 20 at a mid-column feed point.
  • a portion of the distillation vapor (stream 42 ) is withdrawn from the upper region of the stripping section in fractionation tower 20 .
  • This stream is then cooled from ⁇ 91° F. [ ⁇ 68° C.] to ⁇ 122° F. [ ⁇ 86° C.] and partially condensed (stream 42 a ) in heat exchanger 22 by heat exchange with the cold demethanizer overhead stream 38 exiting the top of demethanizer 20 at ⁇ 127° F. [ ⁇ 88° C.].
  • the cold demethanizer overhead stream is warmed slightly to ⁇ 120° F. [ ⁇ 84° C.] (stream 38 a ) as it cools and condenses at least a portion of stream 42 .
  • the operating pressure (447 psia [3,079 kPa(a)]) in reflux separator 23 is maintained slightly below the operating pressure of demethanizer 20 .
  • This provides the driving force which causes distillation vapor stream 42 to flow through heat exchanger 22 and thence into the reflux separator 23 where the condensed liquid (stream 44 ) is separated from any uncondensed vapor (stream 43 ).
  • Stream 43 then combines with the warmed demethanizer overhead stream 38 a from heat exchanger 22 to form cold residue gas stream 45 at ⁇ 120° F. [ ⁇ 84° C.].
  • the liquid stream 44 from reflux separator 23 is pumped by pump 24 to a pressure slightly above the operating pressure of demethanizer 20 , and stream 44 a is then supplied as cold top column feed (reflux) to demethanizer 20 at ⁇ 121° F. [ ⁇ 85° C.].
  • This cold liquid reflux absorbs and condenses the C 3 components and heavier components rising in the upper rectification region of the absorbing section of demethanizer 20 .
  • the liquid product stream 41 exits the bottom of tower 20 at 114° F. [45° C.].
  • the cold residue gas stream 45 passes countercurrently to the incoming feed gas in heat exchanger 15 where it is heated to ⁇ 36° F. [ ⁇ 38° C.] (stream 45 a ), in heat exchanger 13 where it is heated to ⁇ 5° F. [ ⁇ 20° C.] (stream 45 b ), and in heat exchanger 10 where it is heated to 80° F. [27° C.] (stream 45 c ) as it provides cooling as previously described.
  • the residue gas is then re-compressed in two stages, compressor 18 driven by expansion machine 17 and compressor 25 driven by a supplemental power source. After stream 45 e is cooled to 120° F. [49° C.] in discharge cooler 26 , the residue gas product (stream 45 f ) flows to the sales gas pipeline at 1015 psia [6,998 kPa(a)].
  • FIG. 3 represents an alternative prior art process according to co-pending application Ser. No. 12/206,230.
  • the process of FIG. 3 has been applied to the same feed gas composition and conditions as described above for FIGS. 1 and 2 .
  • operating conditions were selected to minimize energy consumption for a given recovery level.
  • inlet gas enters the plant as stream 31 and is cooled in heat exchanger 10 by heat exchange with cool residue gas (stream 45 b ), demethanizer lower side reboiler liquids at 36° F. [2° C.] (stream 40 ), and propane refrigerant.
  • the cooled stream 31 a enters separator 11 at 1° F. [ ⁇ 17° C.] and 955 psia [6,584 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 452 psia [3,116 kPa(a)]) of fractionation tower 20 by expansion valve 12 , cooling stream 33 a to ⁇ 25° F. [ ⁇ 32° C.] before it is supplied to fractionation tower 20 at a first lower mid-column feed point.
  • the vapor (stream 32 ) from separator 11 is further cooled in heat exchanger 13 by heat exchange with cool residue gas (stream 45 a ) and demethanizer upper side reboiler liquids at ⁇ 37° F. [ ⁇ 38° C.] (stream 39 ).
  • the cooled stream 32 a enters separator 14 at ⁇ 31° F. [ ⁇ 35° C.] and 950 psia [6,550 kPa(a)] where the vapor (stream 34 ) is separated from the condensed liquid (stream 37 ).
  • the separator liquid (stream 37 ) is expanded to the tower operating pressure by expansion valve 19 , cooling stream 37 a to ⁇ 65° F. [ ⁇ 54° C.] before it is supplied to fractionation tower 20 at a second lower mid-column feed point.
  • the vapor (stream 34 ) from separator 14 is divided into two streams, 35 and 36 .
  • Stream 35 containing about 38% of the total vapor, passes through heat exchanger 15 in heat exchange relation with the cold residue gas (stream 45 ) where it is cooled to substantial condensation.
  • the resulting substantially condensed stream 35 a at ⁇ 119° F. [ ⁇ 84° C.] is then flash expanded through expansion valve 16 to the operating pressure of fractionation tower 20 .
  • expansion valve 16 During expansion a portion of the stream is vaporized, resulting in cooling of stream 35 b to ⁇ 129° F. [ ⁇ 90° C.] before it is supplied to fractionation tower 20 at an upper mid-column feed point.
  • the remaining 62% of the vapor from separator 14 enters a work expansion machine 17 in which mechanical energy is extracted from this portion of the high pressure feed.
  • the machine 17 expands the vapor substantially isentropically to the tower operating pressure, with the work expansion cooling the expanded stream 36 a to a temperature of approximately ⁇ 85° F. [ ⁇ 65° C.].
  • the partially condensed expanded stream 36 a is thereafter supplied as feed to fractionation tower 20 at a mid-column feed point.
  • a portion of the distillation vapor (stream 42 ) is withdrawn from an intermediate region of the absorbing section in fractionation column 20 , above the feed position of expanded stream 36 a in the lower region of the absorbing section.
  • This distillation vapor stream 42 is then cooled from ⁇ 101° F. [ ⁇ 74° C.] to ⁇ 124° F. [ ⁇ 86° C.] and partially condensed (stream 42 a ) in heat exchanger 22 by heat exchange with the cold demethanizer overhead stream 38 exiting the top of demethanizer 20 at ⁇ 128° F. [ ⁇ 89° C.].
  • the cold demethanizer overhead stream is warmed slightly to ⁇ 124° F. [ ⁇ 86° C.] (stream 38 a ) as it cools and condenses at least a portion of stream 42 .
  • the operating pressure (448 psia [3,090 kPa(a)]) in reflux separator 23 is maintained slightly below the operating pressure of demethanizer 20 .
  • This provides the driving force which causes distillation vapor stream 42 to flow through heat exchanger 22 and thence into the reflux separator 23 where the condensed liquid (stream 44 ) is separated from any uncondensed vapor (stream 43 ).
  • Stream 43 then combines with the warmed demethanizer overhead stream 38 a from heat exchanger 22 to form cold residue gas stream 45 at ⁇ 124° F. [ ⁇ 86° C.].
  • the liquid stream 44 from reflux separator 23 is pumped by pump 24 to a pressure slightly above the operating pressure of demethanizer 20 , and stream 44 a is then supplied as cold top column feed (reflux) to demethanizer 20 at ⁇ 123° F. [ ⁇ 86° C.].
  • This cold liquid reflux absorbs and condenses the C 2 components, C 3 components, and heavier components rising in the upper rectification region of the absorbing section of demethanizer 20 .
  • the liquid product stream 41 exits the bottom of tower 20 at 113° F. [45° C.].
  • the cold residue gas stream 45 passes countercurrently to the incoming feed gas in heat exchanger 15 where it is heated to ⁇ 38° F. [ ⁇ 39° C.] (stream 45 a ), in heat exchanger 13 where it is heated to ⁇ 4° F. [ ⁇ 20° C.] (stream 45 b ), and in heat exchanger 10 where it is heated to 80° F. [27° C.] (stream 45 c ) as it provides cooling as previously described.
  • the residue gas is then re-compressed in two stages, compressor 18 driven by expansion machine 17 and compressor 25 driven by a supplemental power source. After stream 45 e is cooled to 120° F. [49° C.] in discharge cooler 26 , the residue gas product (stream 45 f ) flows to the sales gas pipeline at 1015 psia [6,998 kPa(a)].
  • FIG. 3 process improves the ethane recovery from 85.05% (for FIG. 1 ) and 85.08% (for FIG. 2 ) to 87.33%.
  • the propane recovery for the FIG. 3 process (99.36%) is lower than that of the FIG. 1 process (99.57%) but higher than that of the FIG. 2 process (99.20%).
  • the butanes+recovery is essentially the same for all three of these prior art processes.
  • Comparison of Tables I, II, and III further shows that the FIG. 3 process using slightly less power than both prior art processes (more than 2% less than the FIG. 1 process and 0.4% less than the FIG. 2 process).
  • FIG. 4 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. 4 are the same as those in FIGS. 1 , 2 , and 3 . Accordingly, the FIG. 4 process can be compared with that of the FIGS. 1 , 2 , and 3 processes to illustrate the advantages of the present invention.
  • inlet gas enters the plant at 85° F. [29° C.] and 970 psia [6,688 kPa(a)] as stream 31 and is cooled in heat exchanger 10 by heat exchange with cool residue gas (stream 45 b ), demethanizer lower side reboiler liquids at 32° F. [0° C.] (stream 40 ), and propane refrigerant.
  • the cooled stream 31 a enters separator 11 at 1° F. [ ⁇ 17° C.] and 955 psia [6,584 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 452 psia [3,116 kPa(a)]) of fractionation tower 20 by expansion valve 12 , cooling stream 33 a to ⁇ 25° F. [ ⁇ 32° C.] before it is supplied to fractionation tower 20 at a first lower mid-column feed point (located below the feed point of stream 36 a described later in paragraph [0058]).
  • the vapor (stream 32 ) from separator 11 is further cooled in heat exchanger 13 by heat exchange with cool residue gas (stream 45 a ) and demethanizer upper side reboiler liquids at ⁇ 38° F. [ ⁇ 39° C.] (stream 39 ).
  • the cooled stream 32 a enters separator 14 at ⁇ 31° F. [ ⁇ 35° C.] and 950 psia [6,550 kPa(a)] where the vapor (stream 34 ) is separated from the condensed liquid (stream 37 ).
  • the separator liquid (stream 37 ) is expanded to the tower operating pressure by expansion valve 19 , cooling stream 37 a to ⁇ 66° F. [ ⁇ 54° C.] before it is supplied to fractionation tower 20 at a second lower mid-column feed point (also located below the feed point of stream 36 a ).
  • the vapor (stream 34 ) from separator 14 is divided into two streams, 35 and 36 .
  • Stream 35 containing about 38% of the total vapor, passes through heat exchanger 15 in heat exchange relation with the cold residue gas (stream 45 ) where it is cooled to substantial condensation.
  • the resulting substantially condensed stream 35 a at ⁇ 122° F. [ ⁇ 86° C.] is then flash expanded through expansion valve 16 to slightly above the operating pressure of fractionation tower 20 . During expansion a portion of the stream is vaporized, resulting in cooling of the total stream. In the process illustrated in FIG. 4 , the expanded stream 35 b leaving expansion valve 16 reaches a temperature of ⁇ 130° F. [ ⁇ 90° C.].
  • the expanded stream 35 b is warmed slightly to ⁇ 129° F. [ ⁇ 89° C.] and further vaporized in heat exchanger 22 as it provides a portion of the cooling of distillation vapor stream 42 .
  • the warmed stream 35 c is then supplied at an upper mid-column feed point, in absorbing section 20 a of fractionation tower 20 .
  • the remaining 62% of the vapor from separator 14 enters a work expansion machine 17 in which mechanical energy is extracted from this portion of the high pressure feed.
  • the machine 17 expands the vapor substantially isentropically to the tower operating pressure, with the work expansion cooling the expanded stream 36 a to a temperature of approximately ⁇ 86° F. [ ⁇ 65° C.].
  • the partially condensed expanded stream 36 a is thereafter supplied as feed to fractionation tower 20 at a mid-column feed point (located below the feed point of stream 35 c ).
  • the demethanizer in tower 20 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 20 a that contains the trays and/or packing to provide the necessary contact between the vapor portions of the expanded streams 35 c and 36 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 20 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 20 a that contains the trays and/or packing to provide the necessary contact between the vapor portions of the expanded streams 35 c and 36 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 20 b also includes one or more reboilers (such as reboiler 21 and the side reboilers 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 41 , of methane and lighter components.
  • Stream 36 a enters demethanizer 20 at an intermediate feed position located in the lower region of absorbing section 20 a of demethanizer 20 .
  • the liquid portion of the expanded stream 36 a comingles with liquids falling downward from absorbing section 20 a and the combined liquid continues downward into stripping section 20 b of demethanizer 20 .
  • the vapor portion of the expanded stream 36 a rises upward through absorbing section 20 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 42 ) is withdrawn from an intermediate region of absorbing section 20 a in fractionation column 20 , above the feed position of expanded stream 36 a in the lower region of absorbing section 20 a .
  • This distillation vapor stream 42 is then cooled from ⁇ 103° F. [ ⁇ 75° C.] to ⁇ 128° F. [ ⁇ 89° C.] and partially condensed (stream 42 a ) in heat exchanger 22 by heat exchange with the cold demethanizer overhead stream 38 exiting the top of demethanizer 20 at ⁇ 129° F. [ ⁇ 89° C.] and with the expanded substantially condensed stream 35 b as described previously.
  • the cold demethanizer overhead stream is warmed slightly to ⁇ 127° F. [ ⁇ 88° C.] (stream 38 a ) as it provides a portion of the cooling of distillation vapor stream 42 .
  • the operating pressure (448 psia [3,090 kPa(a)]) in reflux separator 23 is maintained slightly below the operating pressure of demethanizer 20 .
  • This provides the driving force which causes distillation vapor stream 42 to flow through heat exchanger 22 and thence into the reflux separator 23 where the condensed liquid (stream 44 ) is separated from any uncondensed vapor (stream 43 ).
  • Stream 43 then combines with the warmed demethanizer overhead stream 38 a from heat exchanger 22 to form cold residue gas stream 45 at ⁇ 127° F. [ ⁇ 88° C.].
  • the liquid stream 44 from reflux separator 23 is pumped by pump 24 to a pressure slightly above the operating pressure of demethanizer 20 , and stream 44 a is then supplied as cold top column feed (reflux) to demethanizer 20 at ⁇ 127° F. [ ⁇ 88° C.].
  • 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 20 a of demethanizer 20 .
  • the feed streams are stripped of their methane and lighter components.
  • the resulting liquid product (stream 41 ) exits the bottom of tower 20 at 113° F. [45° C.] (based on a typical specification of a methane to ethane ratio of 0.025:1 on a molar basis in the bottom product).
  • the cold residue gas stream 45 passes countercurrently to the incoming feed gas in heat exchanger 15 where it is heated to ⁇ 40° F. [ ⁇ 40° C.] (stream 45 a ), in heat exchanger 13 where it is heated to ⁇ 4° F. [ ⁇ 20° C.] (stream 45 b ), and in heat exchanger 10 where it is heated to 80° F.
  • stream 45 c [27° C.] (stream 45 c ) as it provides cooling as previously described.
  • the residue gas is then re-compressed in two stages, compressor 18 driven by expansion machine 17 and compressor 25 driven by a supplemental power source.
  • stream 45 e is cooled to 120° F. [49° C.] in discharge cooler 26
  • the residue gas product flows to the sales gas pipeline at 1015 psia [6,998 kPa(a)].
  • Tables I, II, III, and IV show that, compared to the prior art, the present invention matches or exceeds the propane and butanes+recoveries of all the prior art processes while significantly improving the ethane recovery.
  • the ethane recovery for the present invention (87.56%) is higher than the FIG. 1 process (85.05%), the FIG. 2 process (85.08%), and the FIG. 3 process (87.33%).
  • Comparison of Tables I, II, III, and IV further shows that the improvement in yields was achieved without using more power than the prior art, and in some cases using significantly less power.
  • the present invention represents an improvement of 5%, 3%, and 0.3%, respectively, over the prior art of the FIG.
  • FIG. 3 processes the power required for the present invention is essentially the same as that for the prior art FIG. 3 process, the present invention improves both the ethane recovery and the propane recovery by 0.2% compared to the FIG. 3 process without using more power.
  • the present invention uses the expanded substantially condensed feed stream 35 c supplied to absorbing section 20 a of demethanizer 20 to provide bulk recovery of the C 2 components, C 3 components, and heavier hydrocarbon components contained in expanded feed 36 a and the vapors rising from stripping section 20 b , and the supplemental rectification provided by reflux stream 44 a 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 improves the rectification in absorbing section 20 a over that of the prior art processes by making more effective use of the refrigeration available in process streams 38 and 35 b to improve the recoveries and the recovery efficiency.
  • the expanded substantially condensed stream 35 b (which is predominantly liquid methane) is a better refrigerant medium than demethanizer overhead vapor stream 38 (which is primarily methane vapor), so using stream 35 b to provide a portion of the cooling of distillation vapor stream 42 in heat exchanger 22 allows more methane to be condensed and used as reflux in the present invention.
  • 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 pumped condensed liquid (stream 44 a ) from reflux separator 23 and all or a part of the warmed expanded substantially condensed stream 35 c from heat exchanger 22 can be combined (such as in the piping joining the pump and heat exchanger 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 comingling of the two streams, combined with contacting at least a portion of expanded stream 36 a shall be considered for the purposes of this invention as constituting an absorbing section.
  • FIGS. 5 through 8 display other embodiments of the present invention.
  • FIGS. 4 through 6 depict fractionation towers constructed in a single vessel.
  • FIGS. 7 and 8 depict fractionation towers constructed in two vessels, absorber (rectifier) column 27 (a contacting and separating device) and stripper (distillation) column 20 .
  • a portion of the distillation vapor (stream 54 ) is withdrawn from the lower section of absorber column 27 and routed to reflux condenser 22 to generate reflux for absorber column 27 .
  • the overhead vapor stream 50 from stripper column 20 flows to the lower section of absorber column 27 (via stream 51 ) to be contacted by reflux stream 52 and warmed expanded substantially condensed stream 35 c .
  • Pump 28 is used to route the liquids (stream 47 ) from the bottom of absorber column 27 to the top of stripper column 20 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 20 in FIGS. 4 through 6 ) or multiple vessels will depend on a number of factors such as plant size, the distance to fabrication facilities, etc.
  • distillation vapor stream 42 in FIGS. 5 and 6 may favor withdrawing the distillation vapor stream 42 in FIGS. 5 and 6 from the upper region of stripping section 20 b in demethanizer 20 (stream 55 ).
  • a portion (stream 55 ) of overhead vapor stream 50 from stripper column 20 may be directed to heat exchanger 22 (optionally combined with distillation vapor stream 54 withdrawn from the lower section of absorber column 27 ), with the remaining portion (stream 51 ) flowing to the lower section of absorber column 27 .
  • the distillation vapor stream 42 or the combined distillation vapor stream 42 is partially 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 20 a of demethanizer 20 or through absorber column 27 .
  • 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 20 a of demethanizer 20 or absorber column 27 .
  • distillation vapor stream 42 may favor total condensation, rather than partial condensation, of distillation vapor stream 42 or combined distillation vapor stream 42 in heat exchanger 22 .
  • Other circumstances may favor that distillation vapor stream 42 be a total vapor side draw from fractionation column 20 or absorber column 27 rather than a partial vapor side draw.
  • it may be advantageous to use external refrigeration to provide partial cooling of distillation vapor stream 42 or combined distillation vapor stream 42 in heat exchanger 22 .
  • Feed gas conditions, plant size, available equipment, or other factors may indicate that elimination of work expansion machine 17 , 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 35 a ).
  • separator 11 in FIG. 4 may not be justified. In such cases, the feed gas cooling accomplished in heat exchangers 10 and 13 in FIG. 4 may be accomplished without an intervening separator as shown in FIGS. 5 through 8 .
  • the decision of whether or not to cool and separate the feed gas in multiple steps will depend on the richness of the feed gas, plant size, available equipment, etc.
  • the cooled feed stream 31 a leaving heat exchanger 10 in FIGS. 4 through 8 and/or the cooled stream 32 a leaving heat exchanger 13 in FIG. 4 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. 4 through 8 and/or separator 14 shown in FIG. 4 are not required.
  • the high pressure liquid (stream 37 in FIG. 4 and stream 33 in FIGS. 5 through 8 ) need not be expanded and fed to a lower 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 35 in FIG. 4 and stream 34 in FIGS. 5 through 8 ) flowing to heat exchanger 15 . (This is shown by the dashed stream 46 in FIGS. 5 through 8 .) 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 lower mid-column feed point on the distillation column (stream 37 a in FIGS. 5 through 8 ). Stream 33 in FIG. 4 and stream 37 in FIGS. 4 through 8 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.
  • Some circumstances may favor using a portion of the cold distillation liquid leaving absorbing section 20 a or absorber column 27 for heat exchange, such as dashed stream 49 in FIGS. 5 through 8 .
  • a portion of the liquid from absorbing section 20 a or absorber column 27 can be used for process heat exchange without reducing the ethane recovery in demethanizer 20 or stripper column 20 , more duty can sometimes be obtained from these liquids than with liquids from stripping section 20 b or stripper column 20 . This is because the liquids in absorbing section 20 a of demethanizer 20 (or absorber column 27 ) are available at a colder temperature level than those in stripping section 20 b (or stripper column 20 ).
  • stream 53 in FIGS. 5 through 8 it may be advantageous to split the liquid stream from reflux pump 24 (stream 44 a ) into at least two streams.
  • a portion (stream 53 ) can then be supplied to the stripping section of fractionation tower 20 ( FIGS. 5 and 6 ) or the top of stripper column 20 ( FIGS. 7 and 8 ) to increase the liquid flow in that part of the distillation system and improve the rectification, thereby reducing the concentration of C 2 + components in stream 42 .
  • the remaining portion (stream 52 ) is supplied to the top of absorbing section 20 a ( FIGS. 5 and 6 ) or absorber column 27 ( FIGS. 7 and 8 ).
  • the splitting of the vapor feed may be accomplished in several ways.
  • 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 or after the cooling of the gas and prior to any separation stages.
  • 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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US12/868,993 US20110067441A1 (en) 2009-09-21 2010-08-26 Hydrocarbon Gas Processing
BR112012006279A BR112012006279A2 (pt) 2009-09-21 2010-08-27 processamento de gás de hidrocarboneto
KR1020127009964A KR20120072373A (ko) 2009-09-21 2010-08-27 탄화수소 가스 처리공정
EP10817650A EP2480845A1 (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
AU2010308519A AU2010308519B2 (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
BR112012006219A BR112012006219A2 (pt) 2009-09-21 2010-08-27 processamento de hicrocarbonetos gasosos.
EA201200524A EA021947B1 (ru) 2009-09-21 2010-08-27 Переработка углеводородного газа
PE2012000352A PE20121420A1 (es) 2009-09-21 2010-08-27 Procesamiento de gases de hidrocarburos
JP2012529779A JP5793144B2 (ja) 2009-09-21 2010-08-27 炭化水素ガス処理
PCT/US2010/046953 WO2011034709A1 (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
EA201200521A EA028835B1 (ru) 2009-09-21 2010-08-27 Переработка углеводородного газа
EP10817651A EP2480846A1 (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
NZ599331A NZ599331A (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
JP2012529781A JP5793145B2 (ja) 2009-09-21 2010-08-27 炭化水素ガス処理
EP10825365.9A EP2480847A4 (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
NZ599333A NZ599333A (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
SG2012014452A SG178933A1 (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
CA2773211A CA2773211C (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
PCT/US2010/046967 WO2011049672A1 (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
CN201080041904.9A CN102498360B (zh) 2009-09-21 2010-08-27 碳氢化合物气体处理
CN201080041508.6A CN102498359B (zh) 2009-09-21 2010-08-27 碳氢化合物气体处理
KR1020127009963A KR101619568B1 (ko) 2009-09-21 2010-08-27 탄화수소 가스 처리공정
AU2010295870A AU2010295870A1 (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
BR112012006277A BR112012006277A2 (pt) 2009-09-21 2010-08-27 processamento de hidrocarbonetos gasosos
EA201200520A EA024075B1 (ru) 2009-09-21 2010-08-27 Переработка углеводородного газа
MX2012002969A MX2012002969A (es) 2009-09-21 2010-08-27 Procesamiento de gases de hidrocarburos.
JP2012529780A JP5850838B2 (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
SG2012014445A SG178603A1 (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
PE2012000351A PE20121421A1 (es) 2009-09-21 2010-08-27 Procesamiento de gases de hidrocarburos
CA2772972A CA2772972C (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
MX2012002970A MX351303B (es) 2009-09-21 2010-08-27 Procesamiento de gases de hidrocarburos.
PCT/US2010/046966 WO2011034710A1 (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
MX2012002971A MX348674B (es) 2009-09-21 2010-08-27 Procesamiento de gases de hidrocarburos.
NZ599335A NZ599335A (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
SG2012015392A SG178989A1 (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
CA2773157A CA2773157C (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
KR1020127009836A KR20120069729A (ko) 2009-09-21 2010-08-27 탄화수소 가스 처리공정
CN201080041905.3A CN102575898B (zh) 2009-09-21 2010-08-27 碳氢化合物气体处理
AU2010295869A AU2010295869B2 (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
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
SA110310707A SA110310707B1 (ar) 2009-09-21 2010-09-20 معالجة غاز هيدروكربونى
SA110310705A SA110310705B1 (ar) 2009-09-21 2010-09-20 معالجة غاز هيدروكربونى
SA110310706A SA110310706B1 (ar) 2009-09-21 2010-09-20 معالجة غازهيدروكربونى
ARP100103433A AR078401A1 (es) 2009-09-21 2010-09-21 Procesamiento de gases de hidrocarburos
ARP100103435 AR078403A1 (es) 2010-05-19 2010-09-21 Procesamiento de gases de hidrocarburos
ARP100103434A AR078402A1 (es) 2009-09-21 2010-09-21 Procesamiento de gases de hidrocarburos
EG2012030439A EG26970A (en) 2009-09-21 2012-03-11 Hydrocarbon gas processing
EG2012030437A EG27017A (en) 2009-09-21 2012-03-12 Hydrocarbon gas processing
CL2012000687A CL2012000687A1 (es) 2009-09-21 2012-03-19 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.
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.
ZA2012/02634A ZA201202634B (en) 2009-09-21 2012-04-12 Hydrocarbon gas processing
ZA2012/02633A ZA201202633B (en) 2009-09-21 2012-04-12 Hydrocarbon gas processing
ZA2012/02696A ZA201202696B (en) 2009-09-21 2012-04-13 Hydrocarbon gas processing
CO12064992A CO6531456A2 (es) 2009-09-21 2012-04-19 Procesamiento de gases de hidrocarburos
CO12064988A CO6531455A2 (es) 2009-09-21 2012-04-19 Procesamiento de gases de hidrocarburos
CO12065754A CO6531461A2 (es) 2009-09-21 2012-04-20 Procesamiento de gases de hidrocarburos

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US12/869,139 Abandoned US20110067443A1 (en) 2009-09-21 2010-08-26 Hydrocarbon Gas Processing
US15/259,891 Abandoned US20160377341A1 (en) 2009-09-21 2016-09-08 Hydrocarbon gas processing featuring a compressed reflux stream formed by combining a portion of column residue gas with a distillation vapor stream withdrawn from the side of the column

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US12/869,139 Abandoned US20110067443A1 (en) 2009-09-21 2010-08-26 Hydrocarbon Gas Processing
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