EP2630220A2 - Procédé de séparation et de récupération d'éthane et d'hydrocarbures plus lourds à partir de gnl - Google Patents

Procédé de séparation et de récupération d'éthane et d'hydrocarbures plus lourds à partir de gnl

Info

Publication number
EP2630220A2
EP2630220A2 EP11835149.3A EP11835149A EP2630220A2 EP 2630220 A2 EP2630220 A2 EP 2630220A2 EP 11835149 A EP11835149 A EP 11835149A EP 2630220 A2 EP2630220 A2 EP 2630220A2
Authority
EP
European Patent Office
Prior art keywords
stream
column
lng
lean
liquid
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Withdrawn
Application number
EP11835149.3A
Other languages
German (de)
English (en)
Other versions
EP2630220A4 (fr
Inventor
Kirtikumar Natubhai Patel
Rohit N. Patel
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.)
Individual
Original Assignee
Individual
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 Individual filed Critical Individual
Publication of EP2630220A2 publication Critical patent/EP2630220A2/fr
Publication of EP2630220A4 publication Critical patent/EP2630220A4/fr
Withdrawn legal-status Critical Current

Links

Classifications

    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10L—FUELS NOT OTHERWISE PROVIDED FOR; NATURAL GAS; SYNTHETIC NATURAL GAS OBTAINED BY PROCESSES NOT COVERED BY SUBCLASSES C10G, C10K; LIQUEFIED PETROLEUM GAS; ADDING MATERIALS TO FUELS OR FIRES TO REDUCE SMOKE OR UNDESIRABLE DEPOSITS OR TO FACILITATE SOOT REMOVAL; FIRELIGHTERS
    • C10L3/00—Gaseous fuels; Natural gas; Synthetic natural gas obtained by processes not covered by subclass C10G, C10K; Liquefied petroleum gas
    • C10L3/06—Natural gas; Synthetic natural gas obtained by processes not covered by C10G, C10K3/02 or C10K3/04
    • C10L3/10—Working-up natural gas or synthetic 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
    • F25J3/0204—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream characterised by the feed stream
    • F25J3/0209—Natural gas or substitute natural gas
    • F25J3/0214—Liquefied natural gas
    • C—CHEMISTRY; METALLURGY
    • C07—ORGANIC CHEMISTRY
    • C07C—ACYCLIC OR CARBOCYCLIC COMPOUNDS
    • C07C7/00—Purification; Separation; Use of additives
    • C07C7/09—Purification; Separation; Use of additives by fractional condensation
    • C—CHEMISTRY; METALLURGY
    • C07—ORGANIC CHEMISTRY
    • C07C—ACYCLIC OR CARBOCYCLIC COMPOUNDS
    • C07C9/00—Aliphatic saturated hydrocarbons
    • C07C9/02—Aliphatic saturated hydrocarbons with one to four carbon atoms
    • C07C9/06—Ethane
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G31/00—Refining of hydrocarbon oils, in the absence of hydrogen, by methods not otherwise provided for
    • C10G31/06—Refining of hydrocarbon oils, in the absence of hydrogen, by methods not otherwise provided for by heating, cooling, or pressure treatment
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J1/00—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J3/00—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification
    • F25J3/02—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream
    • F25J3/0228—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream characterised by the separated product stream
    • F25J3/0233—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream characterised by the separated product stream separation of CnHm with 1 carbon atom or more
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J3/00—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification
    • F25J3/02—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream
    • F25J3/0228—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream characterised by the separated product stream
    • F25J3/0238—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
    • 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
    • F25J3/0242—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 3 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
    • F25J2200/00—Processes or apparatus using separation by rectification
    • F25J2200/02—Processes or apparatus using separation by rectification in a single pressure main column system
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2200/00—Processes or apparatus using separation by rectification
    • F25J2200/70—Refluxing the column with a condensed part of the feed stream, i.e. fractionator top is stripped or self-rectified
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2200/00—Processes or apparatus using separation by rectification
    • F25J2200/72—Refluxing the column with at least a part of the totally 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
    • F25J2200/74—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
    • F25J2200/90—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
    • 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
    • F25J2205/00—Processes or apparatus using other separation and/or other processing means
    • F25J2205/50—Processes or apparatus using other separation and/or other processing means using absorption, i.e. with selective solvents or lean oil, heavier CnHm and including generally a regeneration step for the solvent or lean oil
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2210/00—Processes characterised by the type or other details of the feed stream
    • F25J2210/04—Mixing or blending of fluids with the feed stream
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2210/00—Processes characterised by the type or other details of the feed stream
    • F25J2210/62—Liquefied natural gas [LNG]; Natural gas liquids [NGL]; Liquefied petroleum gas [LPG]
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • 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
    • 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
    • F25J2230/00—Processes or apparatus involving steps for increasing the pressure of gaseous process streams
    • F25J2230/60—Processes or apparatus involving steps for increasing the pressure of gaseous process streams the fluid being hydrocarbons or a mixture of hydrocarbons
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2235/00—Processes or apparatus involving steps for increasing the pressure or for conveying of liquid process streams
    • F25J2235/60—Processes or apparatus involving steps for increasing the pressure or for conveying of liquid process streams the fluid being (a mixture of) hydrocarbons
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2245/00—Processes or apparatus involving steps for recycling of process streams
    • F25J2245/02—Recycle of a stream in general, e.g. a by-pass stream
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2280/00—Control of the process or apparatus
    • F25J2280/02—Control in general, load changes, different modes ("runs"), measurements

Definitions

  • the present invention example relates to the field of processing gasses in a liquid or fluid phase such as for LNG (Liquified Natural Gas) and NGL (Natural Gas Liquids) as known in the oil and gas industry and the recovery of C2 and C2+ (ethane +) components from the hydrocarbon fluid streams. More particularly, the present invention relates to the recovery of ethane and less volatile compounds from hydrocarbon fluid streams such as, from near atmospheric or more pressure, stored or transported cryogenic LNG liquid/fluid feed streams, with practical and economic design and operation of equipment to achieve this.
  • LNG Liquified Natural Gas
  • NGL Natural Gas Liquids
  • This invention relates to a process for separation of less volatile compounds, such as ethane and less volatile compounds from hydrocarbon mixed streams for example liquefied natural gas (LNG) or other such as petrochemical refinery streams. It is anticipated it could find utility in non-hydrocarbon related applications.
  • LNG liquefied natural gas
  • Natural gas is being more often liquefied and transported in ocean going LNG tankers to LNG receiving terminals, worldwide.
  • the LNG can then be re-vaporized and transported via pipelines carrying natural gas.
  • the LNG can have other less volatile components besides the predominantly methane (methane usually makes up more than 50% of the LNG). It is usually necessary to remove various amounts of the less volatile components either to meet compositional specifications or Heating Value contractual terms, or in order to obtain greater value from the less volatile heavier compounds. This may be carried out at production, storage, loading terminals or receiving terminals. Storage of LNG presents the problem of uncontrollable "roll overs" caused by density inversions.
  • U.S. Patent No. 6,510,706 (Stone et al.) (January 28, 2003) discloses a process for removing hydrocarbons less volatile than methane from a pressurized liquid natural gas (PLNG).
  • PLNG is heated in a heat exchanger, thereby vaporizing at least a portion of the PLNG.
  • the partially vaporized PLNG is passed to a fractionation column.
  • a liquid stream enriched with hydrocarbons (C.sub.2+ or C.sub.3+) less volatile than methane is withdrawn from a lower portion of the fractionation column and a vapor stream lean in the hydrocarbons less volatile than methane is withdrawn from an upper portion of the fractionation column.
  • the withdrawn vapor stream is passed to the heat exchanger to condense the vapor to produce PLNG lean in hydrocarbons less volatile than methane.
  • U.S. Patent No. 7,165,423 discloses a process for the extraction and recovery of ethane and heavier hydrocarbons (C2+) from LNG.
  • the process covered by this patent maximizes the utilization of the beneficial cryogenic thermal properties of the LNG to extract and recover C2+ form the LNG using a unique arrangement of heat exchange equipment, a cryogenic fractionation column and processing parameters that essentially eliminates (or greatly reduces) the need for gas compression equipment minimizing capital cost, fuel consumption and electrical power requirements.
  • This invention may be used for one or more of the following purposes: to condition LNG so that send-out gas delivered from an LNG receiving and regasification terminal meets commercial natural gas quality specifications; to condition LNG to make Lean LNG that meets fuel quality specifications and standards required by LNG powered vehicles and other LNG fueled equipment; to condition LNG to make Lean LNG so that it can be used to make CNG meeting specifications and standards for commercial CNG fuel; to recover ethane, propane and/or other hydrocarbons heavier then methane from LNG for revenue enhancement, profit or other commercial reasons.
  • U.S. Patent No. 7,631,516 (Cuellar et al.) (December 15, 2009) discloses a process and apparatus for the recovery of ethane, ethylene, propane, propylene, and heavier hydrocarbons from a liquefied natural gas (LNG) stream is disclosed.
  • the LNG feed stream is divided into two portions. The first portion is supplied to a fractionation column at an upper mid-column feed point. The second portion is directed in heat exchange relation with a warmer distillation stream rising from the fractionation stages of the column, whereby this portion of the LNG feed stream is partially vaporized and the distillation stream is totally condensed.
  • the condensed distillation stream is divided into a "lean" LNG product stream and a reflux stream, whereupon the reflux stream is supplied to the column at a top column feed position.
  • the partially vaporized portion of the LNG feed stream is separated into vapor and liquid streams which are thereafter supplied to the column at lower mid-column feed positions.
  • the quantities and temperatures of the feeds to the column are effective to maintain the column overhead temperature at a temperature whereby the major portion of the desired components is recovered in the bottom liquid product from the column.
  • U.S. Patent No. 7,216,507 (Cuellar et al.) (March 15, 2007) discloses a process and apparatus for the recovery of ethane, ethylene, propane, propylene, and heavier hydrocarbons from a liquefied natural gas (LNG) stream is disclosed.
  • the LNG feed stream is divided into two portions. The first portion is supplied to a fractionation column at an upper mid-column feed point. The second portion is directed in heat exchange relation with a warmer distillation stream rising from the fractionation stages of the column, whereby this portion of the LNG feed stream is partially heated and the distillation stream is totally condensed.
  • the condensed distillation stream is divided into a "lean" LNG product stream and a reflux stream, whereupon the reflux stream is supplied to the column at a top column feed position.
  • the partially heated portion of the LNG feed stream is heated further to partially or totally vaporize it and thereafter supplied to the column at a lower mid-column feed position.
  • the quantities and temperatures of the feeds to the column are effective to maintain the column overhead temperature at a temperature whereby the major portion of the desired components is recovered in the bottom liquid product from the column.
  • U.S. Patent No. 7,010,937 discloses a process for liquefying natural gas in conjunction with producing a liquid stream containing predominantly hydrocarbons heavier than methane is disclosed.
  • the natural gas stream to be liquefied is partially cooled, expanded to an intermediate pressure, and supplied to a distillation column.
  • the bottom product from this distillation column preferentially contains the majority of any hydrocarbons heavier than methane that would otherwise reduce the purity of the liquefied natural gas.
  • the residual gas stream from the distillation column is compressed to a higher intermediate pressure, cooled under pressure to condense it, and then expanded to low pressure to form the liquefied natural gas stream.
  • U.S. Patent Publication No. 20080098770 discloses a liquefied natural gas (LNG) facility employing an intermediate pressure distillation column for recovery of ethane and heavier components from the processed natural gas stream in a way that increases operational stability and minimizes capital and operating costs.
  • LNG liquefied natural gas
  • U.S. Patent Publication No. 20090221864 (September 3, 2009) discloses that LNG is processed in contemplated plants and methods such that refrigeration content of the LNG feed is used to provide reflux duty to the demethanizer and to further condense a vapor phase of the demethanizer overhead product.
  • the demethanizer provides a bottom product to a deethanizer, wherein a demethanizer side draw provides refrigeration to the deethanizer overhead product to thus form an ethane product and deethanizer reflux.
  • the present invention describes a process for separating and recovering ethane and heavier hydrocarbons from LNG.
  • the steps include providing an undivided feedstock stream containing Rich LNG wherein the Rich LNG is in liquid form from a storage tank or other source, the Rich LNG comprising CI and C2+ hydrocarbons, the Rich LNG having an ambient storage temperature and pressure.
  • the next step involves pressurizing the feedstock Rich LNG from storage pressure up to a desired pressure followed by pumping the feedstock Rich LNG into the cool side of a heat exchanger, the heat exchanger having a cool side and a hot side.
  • the desired pressure is typically dictated by any downstream process steps involving the heat exchanger, and/or is dictated by critical pressure properties of the desired gas and liquid mixture in the column.
  • the feedstock Rich LNG is heated within the heat exchanger while maintaining the feedstock Rich LNG below its bubble point to avoid vaporization while in the heat exchanger.
  • the step of maintaining the feedstock Rich LNG below its bubble point to avoid vaporization while in the heat exchanger is achieved by regulating the pressure in the heat exchanger to maintain the Rich LNG in its liquid phase with no vaporization.
  • the undivided feedstock Rich LNG feed stream is directed from the heat exchanger to a processing column, the column comprising one or more stream entry ports along the height of the column to permit directing the stream into the column at one or more desired entry locations along the height of the column.
  • the process then involves generating in the column a desired mixture comprising an overhead gas stream comprising lighter hydrocarbon products and a desired bottoms liquid stream comprising heavier hydrocarbon products.
  • the overhead gas stream is directed from the column to the hot side of the heat exchanger.
  • the next step involves cooling and condensing the overhead gas stream against the cold Rich LNG feedstock stream to form, in whole or in substantial part, a liquid comprising Lean LNG product stream, any remaining incidental uncondensed overhead gas stream remaining as a gas.
  • the condensed product stream is then directed from the hot side of the heat exchanger to a receiving vessel.
  • the liquid Lean LNG product is pumped from the receiving vessel to a desired location.
  • the bottoms liquid stream is directed from the column to one or more reboiler arrangements wherein heating of the bottoms liquid stream in the reboiler takes place. At least a portion of the heated bottoms stream are preferably returned to the column, the column being further outfitted with one or more heated bottoms stream entry ports along the height of the column to permit directing the heated bottoms stream into the column at one or more desired heated bottoms stream product entry locations along the height of the column.
  • the column bottoms stream is discharged directly from the column or from the reboiler and the bottoms stream is transferred to a desired location. Any gas in the receiving vessel is transferred to a desired location.
  • this process may further comprise the steps of: directing the feedstock Rich LNG from the heat exchanger through a valve and into a degasser; directing the liquid stream from the degasser into the processing column, the column being further outfitted with one or more degasser liquid stream entry ports along the height of the column to permit directing the degasser liquid stream into the column at one or more desired degasser liquid product entry locations along the height of the column; and directing any gas stream in the degasser to the column, the column being further outfitted with one or more degasser gas stream entry ports along the height of the column to permit directing the degasser gas stream into the column at one or more desired degasser gas product entry locations along the height of the column.
  • a portion of the column bottoms stream may be directed to the degasser to warm the feedstock and alter the composition of the total feed to the column.
  • the process may include the additional steps of recovering heat from the column bottoms stream.
  • the NGL product comprises a desired high or low percentage of ethane.
  • the Lean LNG stream may be directed to a storage facility or to further processing to vaporize the Lean LNG.
  • At least some of the Lean LNG stream is directed to the column, the column being further outfitted with one or more Lean LNG stream entry ports along the height of the column to permit directing the Lean LNG stream into the column at one or more desired Lean LNG product entry locations along the height of the column.
  • the process may also comprise the additional steps of: directing at least some of the Lean LNG stream into one or more additional heat exchangers; heating the Lean LNG within the one or more heat exchangers while maintaining the Lean LNG below its bubble point to avoid vaporization while in the heat exchanger; directing the Lean LNG from the heat exchanger through a valve and into a degasser or other vessel; directing the liquid stream from the degasser or other vessel to a desired location; and directing any gas stream in the degasser or other vessel to a desired location.
  • the liquid stream may be directed from the degasser or other vessel into another heat exchanger arranged in series relationship and these additional steps be completed.
  • the Lean LNG stream is directed to a Rich
  • LNG feedstock storage containing a level of Rich LNG feedstock, the storage further comprising one or more jet or sparger systems located along the height of the storage to permit introduction of the Lean LNG stream into the storage either above and/or within the level of stored Rich LNG feedstock.
  • the Lean LNG stream is directed to any stored source of LNG, wherein it is sparged into the stored source of LNG at a desired location.
  • any gas phase in the receiving vessel is transferred to a compressor wherein the gas phase is compressed and then the compressed gas is directed to a desired location.
  • the compressed gas may be directed into a heat exchanger wherein the compressed gas is condensed to form a full or partial condensate Lean LNG, the condensate then being directed to a desired location.
  • the condensate Lean LNG stream may be directed to a storage facility.
  • at least some of the condensate Lean LNG stream is directed to the column, and introduced into the column via the one or more Lean LNG stream entry ports to permit directing the Lean LNG stream into the column at one or more desired locations along the height of the column.
  • the heat exchanger may be cooled by an external refrigeration stream or by by a second LNG stream.
  • a second cold LNG stream is introduced directly into the degasser to mix with the feedstock Rich LNG.
  • the second cold LNG stream may be introduced directly into the column, the column being further outfitted with one or more LNG stream entry ports along the height of the column to permit directing the LNG stream into the column at one or more desired LNG stream product entry locations along the height of the column.
  • the step of cooling and condensing the overhead gas stream against the cold Rich LNG feedstock stream does not form any incidental gas.
  • the discharged bottoms stream comprises an NGL
  • the Rich LNG feedstock comprises between 1% mole C2 to that exceeding 40 to 50 mole % C2.
  • the processing column employed comprises about 10 theoretical trays.
  • the column has flexible configurations and preferably is configured and integrated in a multitude of operability and functional configurations selected from the group consisting of distillation columns, extractive distillation columns, reboiled absorption columns, absorption columns, lean oil absorber columns, fractionation columns, stripping columns, refluxed stripping columns, and reboiled stripping columns.
  • substantially no tail gas (gas from condensed overhead stream) is formed even where there is as low as 1% C2 in the feedstock.
  • FIG. 1A is a flow diagram of a HYSYS Simulation of a LNG processing plant in accordance with the present invention.
  • FIG. IB is the detail area IB shown in FIG. 1A.
  • FIG. 2A is another flow diagram of a HYSYS Simulation of a LNG processing plant in accordance with the present invention adding additional processing options to those described in connection with FIG. 1A.
  • FIG. 2B is enlarged view of detail area 2B shown in FIG. 2A.
  • the present invention is generally concerned with the practical recovery or separation of less volatile components from a mix of other components as for example in this instance methane rich stream is separated from a stream of less volatile components than methane as may consist in LNG and such streams.
  • the type of heat exchanger can be any of the heat exchanger systems known in the art.
  • the reference to a heat exchanger can include an individual heat exchanger or a multitude of individual heat exchangers.
  • One manner in which to maintain the mixture in its liquid state is to maintain the mixture substantially or discernibly below bubble point.
  • a provision is provided to degas the liquid stream if necessary prior to feeding the warmed rich LNG to the processing column as a safety feature or a particular operational feature, prior to feeding the liquid stream at a top or high position in the processing column.
  • the present invention avoids the usual or particular prior art instructions or necessity of pre-vaporizing in part or such and/or of splitting the feed stream prior to or after the LNG heat exchanger and/or having to have any part of or the whole feed stream pre-vaporized prior to feeding the processing column.
  • the invention provides method/process/system/operations/means for practical and/or simplicity of design with resultant economy of equipment and/or utilities and/or operations.
  • This invention makes the design practicable and/or economic whereas some prior art designs or systems or methods or process(es) require additional utilities or equipment or as demonstrated have equipment design tending towards infinite or indeterminate heat exchange surface areas required of LNG exchanger design or have impractical temperature crosses in the LNG exchanger.
  • the invention provides method/process/system/operations/means for design and operation in particularly eliminating compression/recompression of the Lean LNG methane rich vapor product of the processing column by re-converting/condensing it fully back to liquid.
  • the processing column may be employed in various modes of operation.
  • the processing column can function as any type of column, such as for example and not by way of limitation, as a distillation column, extractive distillation column, reboiled absorption column, absorption column, lean oil absorber column, fractionation column, stripping column, refluxed stripping column, reboiled stripping column, and the like.
  • Highlights of the present invention include: unique arrangement of the pre- column, at/within-column, and post-column major parts of the process; flexible variability of the RLNG source pressure (via pump 22 or other motive power system) - this pressure control is important for the rest of the process; the heat exchanger 30 operation; regulating internal pressure of the RLNG-cold side of exchanger via a back-pressure controller (33); the feed composition/enthalpy variability options with item degasser 40; the column operability functions - variability with multiple optional combinations of column source streams and their locations on the column, the variability of column pressure and its effect on its operations (via back pressure controller (16)); the overall combination of items downstream of stream 8 and 9 to provide variability of the pressure on the exchanger condensing hot side; and optional process embodiment to re-produce LLNG
  • a flexibility integrated methodology and system for extracting less volatile components from a fluid stream working in high percentage or low percentage extracting modes is disclosed, such as, showing the extracting/rejecting of ethane in this inventive process (of extracting NGL from LNG) while not requiring vaporization of Rich LNG (RLNG) prior to separation in to LNG/NGL in a column(s) and essentially on a large part eliminating the requirements of compressing (optional) any gas to produce Lean LNG (LLNG) while taking the feed RLNG extracting its NGLs in the processing system and reproducing Lean LNG of spec from Rich LNG.
  • RLNG Rich LNG
  • FIGS. 1A, IB, 2A and 2B there is shown a flow diagram of a
  • D. gasser vessel 40 (optionally can be an inline degasser) [0060]
  • an LNG (or RICH LNG) stream 1 is pumped via pump 22 from a storage location 20 (e.g., tank 20 having LNG level 20A) through suitable conduit through a valve 24, where it becomes labeled stream 1A.
  • a storage location 20 e.g., tank 20 having LNG level 20A
  • suitable conduit is used throughout the flow diagram to connect together the various components as shown to permit (as described) fluid communication between components for transporting the various product streams therein.
  • Stream 1A is directed into the cool side of a heat exchanger 30 via heat exchanger inlet 31, and is discharged out of the heat exchanger 30 as stream 2 via heat exchanger outlet 32.
  • the heat exchanger 30 has a hot side that is in turn receiving one or more warm process stream(s), particularly the overhead stream 7 from a processing column 50.
  • the warmed LNG stream 2 in its liquid state, is passed through a valve 33 where it becomes stream 3 or 3A.
  • the valve 33 can be used to, e.g., regulate the pressure of stream 3 and 3A, for example, to lower the pressure of stream 3 after stream 3 exits the heat exchanger 30 prior to entering the processing column 50.
  • the warmed LNG stream 3 still in liquid state, is then passed into a degassing vessel 40 via degasser inlet 43, though no vaporization is anticipated under the normal modes of operation of the invention.
  • the degassed liquid stream 4 is discharged, via degasser lower outlet 44 for discharging stream 4, from the vessel 40 and is fed to the processing column 50 at desired location(s) (using an optional pump 48, as may be desired).
  • the degassed gas stream 5 is discharged, via degasser upper outlet 45, from the vessel 40 and is fed to the processing column 50 at desired location(s) via inlet(s) 55 (and in connection with suitable valve(s) 17D).
  • the warmed LNG stream 3A still in liquid state, is then passed directly to the processing column 50 and introduced into the column at any desired location via one or more suitable inlet ports (not shown).
  • the processing column 50 is outfitted with one or more processing column inlet(s) 54 for receiving stream 4 at various locations along the height of the column 50 (in connection with suitable valve(s) 17E).
  • the column 50 is also outfitted with one or more processing column inlet(s) 55 for receiving stream 5 at various locations along the height of the column 50.
  • the more and less volatile components are separated and the lighter components ("overhead", stream 7) predominantly are discharged out of the column 50 from the upper section (via processing column outlet 57) and the less volatile components ("bottoms", stream 6) are discharged from a lower section (via processing column outlet 56).
  • the column bottoms may be directed to storage or end use locations or be circulated to be mixed with the warmed feed stream or alternatively connected to another portion of the column (which can be piped to be able to provide inlet to the column at various stages or locations in the column for flexibility) that would optimize the NGL extraction with C2 extraction or Rejection mode operations or to obtain specified NGL requirements.
  • the bottoms (stream 6) from processing column 50 are discharged (via discharge port 56) to a pump (not shown) which may circulate some of the bottoms back to the column 50 or the degassing vessel 40.
  • the bottoms (stream 6) may be directed into any type of column bottoms reboiler arrangement 60 via reboiler inlet 66.
  • the reboiler has an energy stream 60A for heat in the reboiler 60.
  • the NGLs from stream 6 may be discharged from the reboiler 60 as NGL stream 6A via reboiler outlet 66A.
  • NGL stream 6A may be recycled to degasser 40 (through suitable valve 17C) and introduced therein via degasser inlet 46.
  • NGL stream 6A may also be recycled (as stream 6A-1) to the processing column 50 and introduced therein via various processing column inlet(s) 56A for receiving stream 6A-1 at various locations along the height of the column 50 in coordination with suitable valve(s) 17F.
  • the end product NGLs from stream 6 may also be discharged from the reboiler 60 as NGL stream 6 via reboiler outlet 66B where they can be directed to a desired end use/storage location (not shown), or where they could be directed to a splitting junction / valve 85 via inlet 86.
  • the splitter/valve 85 could direct stream 6 out the outlet 87 (as stream 6A) or out the outlet 88 (as stream 6) to a desired location (not shown).
  • the liquid NGLs could also be boiled within the reboiler and directed, via reboiler outlet 66C as stream 6C, to the processing column 50 and introduced therein via various processing column inlet(s) 56C for receiving stream 6C at various locations along the height of the column 50 in coordination with suitable valve(s) 17H.
  • the lighter components (“overhead", stream 7) predominantly leave the column 50 from the upper section (via processing column outlet 57 for discharging stream 7) and are then directed through valve 16 (used to regulate pressure) where stream 7 becomes labeled as stream 8.
  • stream 7 could be directed through a compressor (not shown) whereafter stream 7 would be labeled stream 8.
  • the overhead stream 7, 8 is directed into the hot side of the heat exchanger 30 via heat exchanger inlet 38 where the stream 8 is cooled and condensed against the Rich LNG stream in the LNG exchanger 30.
  • the overhead methane rich vapor stream (7, 8) from the column 50 is diverted to the LNG exchanger 30 where it is condensed in cross exchange of heat with the cold Rich LNG feed (1A) and is anticipated to condense up to 100% into Lean LNG liquid (stream 9) which is then directed out of the exchanger 30 via exchanger outlet 39.
  • the Lean LNG (stream 9) (which is a Cl-rich mixture of liquid and gas)) is directed into and stored in a surge drum or receiving vessel 70 (via vessel inlet 71).
  • the Lean LNG stream may be moved from the vessel 70 (as liquid stream 10) via vessel outlet 72 by way of a pump 74 at a required/desired pressure (stream 10A).
  • Stream 10A (Lean LNG) can then be further directed to storage or other desired location (e.g., storage tank, pressurized pipeline, not shown).
  • storage or other desired location e.g., storage tank, pressurized pipeline, not shown.
  • Stream 10A (Lean LNG) may also be routed through a splitter or junction / valve 75 (via inlet 76). Stream 10A may be directed through valve 75 (via outlet 77) as stream 10E to a desired location or storage facility for the Lean LNG product. For example, and referring to FIG. IB (which illustrates detail area IB from FIG. 1A), stream 10E (Lean LNG) may be directed to one or more further heat exchanger processing unit(s) 1C.
  • the stream 10E would enter heat exchanger 100 and depart as stream 10F through a valve 200 or other pressure maintenance system (for maintaining the desired pressure in the heat exchanger 100 to maintain the Lean LNG in liquid form as it is heated in the heat exchanger much like with the operation of exchanger 30 described herein) where stream 10F becomes stream 10G.
  • the heat exchanger 100 also receives desired heat transfer stream 99 A (which can be an independent hot stream or a hot side stream from another part of the process) which then transfers thermal energy and departs exchanger 100 as stream 99B (which can be directed to other locations as desired).
  • stream 10G is fed into a degasser or other receiving vessel 300 where the liquid phase can then be directed out as Lean LNG stream 10H and any gas can be directed out as gas stream 25A.
  • Side stream 99C can pass through the vessel 300 (to, e.g., transfer thermal energy) and exit the vessel as side stream 99D.
  • Gas stream 25A can then pass through a valve 700 where it becomes gas stream 25B and can then be directed to a desired location, such as, by joining it with gas product stream 12A to create gas product stream 12B.
  • Liquid stream 10H can be then directed to a desired location, such as, an inlet stream 10H for another heat exchanger processing unit.
  • a second heat exchanger processing unit could be tied into the first heat exchanger processing unit 1C in series fashion.
  • the liquid product stream 10H (from unit 1C) would enter another heat exchanger 400 and depart as stream 10J through a backpressure/level control valve 500 or other pressure maintenance system (for maintaining the desired pressure in the heat exchanger 400 to maintain the Lean LNG in liquid form as it is heated in the heat exchanger much like with the operation of exchanger 30 described herein) where stream 10J becomes stream 10K.
  • the heat exchanger 400 also receives desired heat transfer stream 99E (which can be an independent stream or a side stream from another part of the process) which then transfers thermal energy and departs exchanger 400 as stream 99F (which can be directed to other locations as desired).
  • stream 10K is fed into another degasser or other receiving vessel 600 where the liquid Lean LNG phase can then be directed out as Lean LNG stream 10L and any gas can be directed out as stream 25C.
  • Side stream 99G can pass through the vessel 600 (to, e.g., transfer thermal energy) and exit the vessel as side stream 99H.
  • Gas stream 25C can then pass through a valve 800 where it becomes gas stream 25D and can then be directed to a desired location, such as, by joining it with gas product stream 12B to create gas product stream 12C.
  • Liquid stream 10L can be then directed to a desired location, such as, an inlet stream 10L for yet another heat exchanger processing unit (not shown).
  • any desired number of heat exchanger processing units may be arranged in series relationship.
  • Lean LNG stream 10E may be directed to one or more heat exchanger processing units that are themselves arranged in parallel fashion.
  • the various streams exiting the heat exchangers and degassers could also be directed to other equipment combining/separating/collecting liquid LLNG and gas after the degassers, etc.
  • the LLNG is maintained in liquid form as it traverses through the exchanger(s) (where it is heated), and then after passing through the backpressure/level control valve, it may then vaporize where the liquid/vapour mixture is directed into the next degasser or a vessel or a collection of equipment, such as a pipe header, etc.
  • the heat source for the heat exchangers can be air, as in air exchangers, or sea water, as in sea water exchangers, or other heat sources known in the art.
  • stream 10A may be directed out of valve 75 (via outlet 78) as stream 10B to be recycled and introduced into the processing column 50 via processing column inlet(s) 58 for receiving stream 10B at various locations along the height of the column 50 in connection with valve(s) 17G.
  • the processing column 50 receives, when required in its operating mode, a cold Lean LNG (stream 10B) at a point in the column calculated for a particular combination of pressures and fluid compositions to enhance its C2 Recovery or its C2 Rejection mode of operation.
  • Lean LNG stream 10A could be diverted out of valve 75 via outlet 79 (as stream IOC, 10D, with assistance of pump 74A as may be necessary) back to storage tank 20 to permit the Lean LNG product of this invention to be recycled to storage as part of a "roll over" control method.
  • a part of the Lean LNG product 10A (as streams IOC, 10D) as a further and part product of the Lean LNG flash of product of the Lean LNG product of this invention which can be recycled to storage as part of a "roll over" control method.
  • a processed or cooled LNG product 10A, IOC within or above a stored quantity of LNG (such as is stored in tank 20) as part of a "roll over" control method via one or more jets or spargers (20B, 20C) within the tank 20.
  • the sparged LNG product 10A, IOC can be introduced within (20B) or above (20C) a stored quantity of LNG (e.g., in tank 20 having LNG level 20A and one or more jets/spargers 20B, 20C).
  • sparging a processed LNG product 10A, IOC, 10D comprising of vapor and/or liquid flash of this disclosed process, within or above a stored quantity of LNG in tank 20.
  • tail gas stream 11 may be directed from receiving vessel 70, via outlet 73 into a compressor 80 (via compressor inlet 81) whereafter the compressed gas stream 12 emerges from compressor via outlet 82 and may be directed to a desired location.
  • the compressor has an energy stream 80A for driving the compressor 80.
  • stream 12 may be directed into a heat exchanger CDX 90 via inlet 91 to cool stream 12.
  • the Lean LNG cooler gas stream 12B (emerging from exchanger outlet 92) may be directed (as stream 12C) to be merged along with stream 10A and delivered to a desired location, or may be directed (as stream 12D) to be merged with stream 10B for recycling to the processing column 50.
  • the heat exchanger 90 may utilize an external refrigeration option 14, such as via coolant lines 14A, 14B to provide coolant.
  • stream 12 may be directed through valve 900 where it becomes gas product stream 12A where it is directed to a desired location, along with potential other gas product streams 12B, 12C as described above.
  • a cold LNG stream 13 (or other desired cold stream, such as, a lean oil extraction / absorption stream) may be introduced into the heat exchanger 90 (via inlet 94) and directed out of the heat exchanger (via outlet 93) as stream 15.
  • Stream 15 may be diverted (as stream 15A) into the degasser 40 (via inlet 47) in connection with suitable valve 17B.
  • Stream 15 may also be directed (as stream 15B) (in connection with suitable valve 17A) into processing column 50 via processing column inlet(s) 59 for receiving stream 15B at various locations along the height of the column 50 (in association with valve(s) not shown).
  • Stream 13 can be a stream, e.g. but not limited to, CI -rich or a C2-rich or a C3-rich or a C4-rich or a rich LNG or a Lean LNG which can act as the cooling colder stream used to condense any vapors in stream 12 in the heat exchanger 90 to give a partially or fully condensed stream 12B.
  • Stream 13 in another instances or embodiments, but not limited to, can be a what is termed a "Lean Oil” absorber stream that can be used to cool stream 12 in the Heat exchanger 90 or in another instance, bypass the exchanger 90 as stream 15, which in turn can be another feed stream to the processing column as stream 15A or stream 15B to affect extraction of less volatile components from the VLNG/RLNG or be used to control separation behavior of products and operation of the processing column 50.
  • An external refrigeration option 14 is provided in which may comprise any other material stream of choice which is a refrigerating/cooling stream (14A, 14B) that cools the stream 12 in the exchanger 90 producing a condensed fully liquid or partially liquid stream 12B.
  • the invention has been designed to handle C2 compositions of LNG of from about +/- 1% stored at about atmospheric and more particularly approximately 10 PSIG and -260°F to a C2+ content range that extends even beyond 32+% (shown) and (not shown) beyond even 52% Mol of C2 stored at 10 PSIG and -232°F.
  • Tables 1A through 6 A are provided giving more detailed data description of the parameters for the design and operation of the process plant. It will be apparent to one skilled in the art having the benefit of the present disclosure, that the present invention could be practiced by following the present disclosure of the diagrams/ Figures and the accompanying data Tables. The current disclosure is indicative of reasonable assumptions typically made by those skilled in the art, including rounding of the data, ambient conditions and heat losses not accounted and not shown but contemplated where required.
  • TABLE 1A shows the processing of LNG with 1% C2 in an Ethane Recovery mode, resulting in a recovery of 81% of C2 and 94% of C3, with the rest of the component recoveries reflected in Tables 1 and 1A.
  • stream 2 is maintained as a liquid with minimal reflux (stream 10B, with ⁇ than 1% C2 - as same as C2 in Lean LNG) and 0 bottoms recycle (stream 6A).
  • tail stream 11 which can be tied into a gasification system and pipeline much more economically at a higher pressure with just some addition of heat and compression to even higher pressure if desired.
  • the vapour fraction is zero thereby indicating that there is no vaporization of the LNG stream.
  • Stream 5 reflects a "default" stream/pipe for vapor to leave if any gas degasses - so always a Vapour Fraction of "1" - a simulation stream vapor and liquid from any vessel.
  • TABLE 2A shows the processing of LNG with 22% C2 in an Ethane Recover ⁇ ' mode, resulting in a recovery of 94% of C2 and 99% of C3, with the rest of the component recoveries reflected in Tables 2 and 2A.
  • steam 2 is maintained as liquid with minimal reflux (stream 10B, with > than 2% C2 - as same as C2 in Lean LNG) and 0 bottoms recycle (stream 6A).
  • stream 10B stream 10B
  • stream 6A No compression/recompression is required for stream 11 - which can be tied into a gasification system and pipeline much more economically at a higher pressure with just some addition of heat and compression to even higher pressure if desired.
  • TABLE 3A shows the processing of LNG with 32% C2 in an Ethane Recover ⁇ ' mode, resulting in a recovery of 96% of C2 and 99% of C3, with the rest of the component recoveries reflected in Tables 3 and 3A.
  • stream 2 is maintained as a liquid with minimal reflux (stream 10B, with > than 3% C2 - as same as C2 in Lean LNG) and 0 bottoms recycle (stream 6A).
  • stream 6A No compression/recompression required for stream 11 - which can be tied into a gasification system and pipeline much more economically at a higher pressure with just some addition of heat and compression to even higher pressure if desired.
  • TABLE 4A shows the processing of LNG with 32% C2 in an Ethane Controlled Rejection mode, resulting in a recovery of 65% of C2 and 89% of C3, with the rest of the component recoveries reflected Tables 4 and 4A.
  • stream 2 is maintained as a liquid with minimal reflux (stream 10B, with > than 25% C2 - as same as C2 in Lean LNG) and a particular bottoms recycle (stream 6A).
  • TABLE 5A shows the processing of LNG with 8.9% C2 in the same operating mode as TABLE 4/4A. It fails (as seen in TABLE 5/5A) and cannot perform unless the inventive design changes in the operating mode are made as in TABLE 6/6A.
  • TABLE 5A shows that for one of various pressure and temperature for stream 2, when permitted or allowed to vaporize in stream 2 TABLE 5A, the system fails and when maintained as a liquid as in stream 2 of TABLE 6A, the system along with all the other parameters performs.
  • TABLE 5A demonstrates that control of column pressure drives the feasibility of the process as well.
  • TABLE 5A demonstrates the effect of changing the column pressure slightly from 605 psig to 555 psig. The failure translates down to the exchanger which goes into a "temperature cross" or an impractical or uneconomic exchanger design.
  • Stream 2 is liquid until let down in pressure at the valve down to stream 3 ( exchanger pressure Stream 2 was 693 psig and valve let it down as stream 3 to 560 psig - partly vaporizing).
  • TABLE 6A shows It shows the processing of LNG with 8.9% C2 in an Ethane Controlled Rejection mode.
  • stream 2 is maintained as a liquid with some reflux (stream 10B, with > than 2% C2 - as same as C2 in Lean LNG) and 0 bottoms recycle (stream 6A).
  • stream 10B is maintained as a liquid with some reflux
  • stream 6A is maintained as a liquid with some reflux
  • stream 6A No compression/recompression is required for stream 11 - which can be tied into a gasification system and pipeline much more economically at a higher pressure with just some addition of heat and compression to even higher pressure if desired.
  • FIG. 2A is another flow diagram of a HYSYS Simulation of a LNG processing plant in accordance with the present invention. It illustrates the employment of additional processing options to those outlined in connection with FIG. 1A and Tables 1-6. Specifically, FIG. 2A adds processing options related to introduction of a cold LNG or other cold desired stream into stream 12 as described above.
  • FIG. 2B provides an enlarged view of detailed area 2B of FIG. 2A (but has relevance also to the teachings of FIG. 1A).
  • FIG. 2B illustrates a detail of the processing column area and exemplary optional connections thereon for receiving various streams.
  • the current process parameters adopted for this disclosure are traditional British units. Though not shown for this disclosure the use of SI units is anticipated and contemplated where required.
  • the Tables reflect all Stream Flows, Temperatures, Vapor Fractions, Compositions (shown in Mole Fractions), and further including volumetric flows of the two key components, C2 and C3, which are used to evaluate Recovery Performances. The typical parameters of measurement are indicated within the Tables.
  • the present invention permits flexibility in optimizing the processing column operation in its modes of operation.
  • Ethane (C2) Rejection mode the processing column is optimized to produce more methane CI as an overhead stream (and less C2+ in the bottom stream).
  • Ethane Extraction mode the processing column is optimized to produce more ethane+ (C2+) fractions from the bottoms stream.
  • the use of reflux stream 10B permits reintroduction of methane rich liquid to the processing column as a reflux to optimize the processing column, to increase or manipulate the purity of the methane overhead stream 7, or to increase or control the C2+ fraction in the bottom stream 6.
  • the present invention permits many points of flexibility and control for operational optimization.
  • the processing column may be optimized (via, e.g., reflux, bottoms recycle) to shift the C2 fraction in the column to exit the column as part of the overhead stream (C2 rejection mode) or as part of the bottoms stream (C2 extraction mode).
  • C2 rejection mode e.g., reflux, bottoms recycle
  • C2 extraction mode e.g., C2 extraction mode
  • a typical NGL specification seeks to remove CI content to less than 1-10%. With the present system, the CI content of the NGL stream can be reduced to less than 0.5%.
  • System pressure plays a key role in this process as is outlined in the TABLES.
  • the cold stream is the Rich LNG (streams 1, 1A) and the warm stream is any of the streams from further downstream process(es), more particularly in this instance the overhead vapor stream 7 from the processing column 50.
  • the LNG exchanger 30 prefferably be of any particular suitable design or network of exchangers.
  • any vapor (stream 5) from the degasser vessel 40 be passed to the processing column 50.
  • the liquid (stream 4) from the degasser 40 is passed to an upper section of the processing column 50.
  • the degasser 40 can be a liquid full vessel where no vapor or gas is evolved.
  • the degasser 40 can be of a simplest of device to whatever is dictated by the conditions.
  • processing column 50 is effectively a reboiled absorber complete with the processing column 50 and a reboiler 60.
  • the plant is operated in a way to manage the Temperature Approach within the LNG exchanger 30 so that the whole arrangement can perform practically, economically, and reasonably.
  • the plant is operated in a way to manage the LMTD (Log Mean Temperature Difference) within the LNG exchanger 30 so that the whole arrangement can perform practically, economically, and reasonably.
  • the HYSYS run data tables included here provide example description of the system behavior and operation.
  • the HYSYS run data tables and figures, taken together, provide substantial description of the system to enable one to design a system to operate in practice.
  • the present invention includes an option to include compression.
  • the present invention is also directed to a process that practically eliminates requirements for compression or recompression of gas prior to returning a resulting product Lean LNG in its liquid form after processing the Rich LNG.
  • the process comprises the steps comprise of:
  • the warmed Rich LNG (2, 3) is channeled to degasser equipment 40 ranging from a simple T Pipe device to a substantially liquid full vessel if desired.
  • the processing column 50 operates at a pressure commensurate but selectable along with the full range of pressure of the pumped Rich LNG (1, 1A) from atmospheric to 700 PSIG, and anticipated above if the equilibrium conditions of the processing column 50 fluids allows separation.
  • the processing column 50 produces a methane rich overhead vapor stream (7) from the top section of the column and an essentially NGL stream (6, 0-NGL) from the bottom section of the column 50.
  • the processing column 50 receives when required in its operating mode a cold Lean LNG stream (10B) at a point in the column calculated for a particular combination of Pressures and fluid compositions to enhance its C2 Recovery or its C2 Rejection mode of operation.
  • the column 50 has at least one contemplated reboiler 60 connected to the column for providing heat to the column operation.
  • At least one C2+ enriched liquid stream is drawn from the column (6) and heated in the reboiler prior to returning the boiled stream (6C) back to the column 50.
  • a stream (6A) for recycle to the column 50 could be drawn from the reboiler 60 directly or the Product NGL Stream (6) and recycling that stream to the degasser 40 or at a point in the column 50.
  • a stream (6A) for recycle to the column could be drawn from the NGL Product stream (6) and thence leaving the column arrangements as a NGL product stream (0- NGL).
  • the column 50 can be made to operate at various pressures (see streams 6 and 7) to meet the various interdependent parameters of the whole facility and desired performance.
  • the Lean LNG (9) is stored in a surge drum / receiving vessel 70, prior to pumping it (10A, 0-LEAN LNG) to storage or Pipeline at the required pressure.
  • the present invention provides advantages and features distinguishing over the systems of the prior art.
  • a flexible and streamlined NGL and C2+ extraction/rejection process is disclosed and as embodied for processing liquid, rich or virgin (feed composition) LNG (hereinafter called RLNG or also called VLNG) and essentially producing one, a liquid lean LNG (hereinafter may be called LLNG) product and second, liquid NGL (hereinafter also referred to as NGL) product(s) without the need of any of the typical compression or expansion work equipment, which however can be an optional part(s) of other embodiments (which as shown in one embodiment here, as an optional item (which further as demonstrated here requires 0 (zero) compression power, meaning there is no need for one in the instances shown with 0 (zero) horsepower).
  • the present invention is a pressure flexible - source/(feed composition) flexible - product flexible - operation flexible - equipment and capital wise economic system/method/process.
  • a liquid phase hydrocarbon stream such as in this instance rich LNG (termed RLNG, or until its composition is affected/changed, called virgin LNG (VLNG)) which is rich in heavier/(less volatile) hydrocarbon components than such as in this instance methane, is introduced into the system as liquid phase VLNG from storage or transport system/pipeline.
  • the liquid phase VLNG is introduced either in pressured state to or thence pumped (in a VLNG Pump) up to a pressure that as part of the inventive device/method/process supports the whole system's various parts' operating pressures as part of this inventive system.
  • the stream is then passed via a heat exchanger (herein sometimes called LNG exchanger, essentially a single exchanger but optionally more or a network of exchangers) while keeping it all as part of this inventive process essentially maintained in the heat exchanger(s) in a liquid phase with the controlled applied pressures (variable).
  • the heat exchange takes place by picking up heat from the processing column (further downstream) vapor overhead stream (OVHD).
  • OVHD vapor overhead stream
  • the stream is then directed to a back pressure holding valve/device/(or back pressure from a downstream equipment/column) to maintain the stream in liquid phase.
  • the stream is then sent to a mixer/separator/vessel/device (here called degasser) wherein the VLNG can be degassed of inert or light(er) components such as hydrogen, nitrogen, H2S, C02, etc., but not limited to and thereafter, the gas stream is connected up to the processing column as gas/vapor inlet to the column.
  • the gas stream can also be mixed with other optional streams.
  • a composition and enthalpy change can be effected to the VLNG via the degasser by optionally mixing with another stream which changes the state/composition of the feed VLNG prior to feeding (FEED) it to the processing/fractionation column.
  • the stream is then directed to a column (wherein the vapor/liquid streams from the degasser can be connected at any number(s) of optimal feed locations on the fractionation column either as VLNG feed or changed composition feed stream or vapor and liquid streams. Pumping could be added where needed to pump the feed liquid to the processing column.
  • the present disclosure teaches pumping the RLNG from storage temperature and pressure to any particular pressure up to (and beyond if required) any process mixture thermodynamic critical pressure required in the column.
  • the feed location on the column varies according to the mode of operation dictated from the hybrid functionality of the column described herein.
  • Column temperatures are managed by managing the bottoms exchanger temperature and feed stream properties to the column as demonstrated in the various streams to and from the column shown in TABLES 1A to 6A embodiments; stream 6 being indicative of bottoms temperature.
  • the present disclosure teaches obtaining almost 100% liquid lean LNG via condensing in the LNG exchanger against the cold of feed Rich LNG being processed as shown in the embodiments.
  • the process can achieve up to 99% ethane recovery.
  • the present teachings can achieve industry/commercial Pipeline Specification ( ⁇ 0.5 v CI content, ⁇ 600 psi TVP), NGL product without any further processing to achieve this result.
  • the present teaching can perform in "most" of the desirable modes liquid Lean LNG and high C2+ recoveries without any need for compression equipment.
  • a smaller Column is contemplated than other arts - the column of the present invention can require about 10 theoretical trays vs. others requiring about 20 trays.
  • the present invention teaches a versatile Column - a Column with hybrid- configurations and performance.
  • the present invention provide for economy of all equipment - number and duties.
  • liquid state is maintained for the feed LNG (RLNG/VLNG) from storage to being warmed in exchanger(s) to liquid feed to degasser to column (optionally liquid feed can be connected directly to column) in contrast to the prior art teachings of vaporizing or partially vaporizing feed stream(s) or split parts of streams in exchanger/exchangers prior to feeding the VLNG stream(s) to the column.
  • One manner in which to maintain the mixture in its liquid state is to maintain the mixture substantially or discernibly below bubble point.
  • a column bottoms liquid stream is recycled to the column via mixing in the degasser (vessel/device) changing the composition/enthalpy of the feed LNG which was up to this point VLNG (virgin LNG) prior to mixing with the warm bottoms stream.
  • VLNG virtualgin LNG
  • the fractionation / processing column pressure is controlled to manage the LNG exchanger operation so that VLNG is kept in its liquid state while exchanging heat from the warmer processing column OVHD (overhead) stream.
  • VLNG pump pressuring can be controlled flexibly depending on VLNG composition and state as a utility to make the overall system work as required in tandem with processing column pressure operation selection.
  • the OVHD stream can be essentially fully condensed while exchanging heat and cooling down against the VLNG (or other optional streams/refrigeration not shown) without need for recompression prior to condensing as the LLNG liquid Product.
  • the invention provides the ability for a purified lean LNG (LLNG) to be split and utilized as reflux in the processing column.
  • the invention also provides, optionally, combinations of VLNG- Pump/Column/LNG-Exchanger/Bottoms-Recycle pressures/temperatures/compositions that can be adjusted to adjust slates of required product or BTU specifications for OVHD LLNG.
  • the present invention provides, optionally, combinations of VLNG-Pump/Column/LNG-Exchanger/Bottoms-Recycle pressures/temperatures/compositions that can be flexibly adjusted (essentially utilizing VLNG-pump pressure, valves, processing column pressure with valves, stream recycles, reflux) to adjust slates of required product specifications for NGL products for varying C2+ extraction/rejection content.
  • vapor stream 11 from vessel 70 if generated which as gas stream can be condensed in a heat Exchanger CXG 90 after compression (80) and the condensed portion (12) can be mixed in with the LLNG (12D) or with the reflux (15A, 15B) to the column or degasser.
  • stream 13 (or can be independent from process refrigeration/cooling stream 14A, 14B) can be used for condensing stream 12 from the compressor 80, and stream 13 may comprise another RLNG or other desirable stream to be processed or to enhance the operation that can be added in or mixed with the main VLNG or optionally connected directly to the column.

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  • Engineering & Computer Science (AREA)
  • Chemical & Material Sciences (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Mechanical Engineering (AREA)
  • Thermal Sciences (AREA)
  • General Engineering & Computer Science (AREA)
  • Physics & Mathematics (AREA)
  • Organic Chemistry (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • General Chemical & Material Sciences (AREA)
  • Analytical Chemistry (AREA)
  • Water Supply & Treatment (AREA)
  • Separation By Low-Temperature Treatments (AREA)
  • Filling Or Discharging Of Gas Storage Vessels (AREA)

Abstract

L'invention concerne un procédé d'extraction de composants lourds, par exemple des condensats de gaz naturel issus de courants de liquide/fluide tels que des courants de GNL enrichi (RGNL), permettant des économies rationalisées. Le procédé comprend le chauffage du courant de RGNL dans un ou plusieurs échangeurs de chaleur (LNGX) contre un courant de vapeur de distillat de tête de colonne, sans qu'il soit nécessaire de séparer les courants d'alimentation en alimentation et en reflux par division du pré-courant ou du post-courant du LNGX chauffé. Quand le RGNL liquide source est traité, des condensats de gaz naturel sont produits et, en même temps, un produit de GNL appauvri purifié (LGNL) retrouve sa forme liquide de GNL. Le procédé peut être essentiellement utilisé sans équipement de compression. De plus, le procédé permet d'obtenir, sans compresseur, un gaz naturel vaporisé à la pression du pipeline et correspondant aux spécifications. Le système de l'invention permet une modification souple de la composition des produits et des spécifications d'un produit de condensat de gaz naturel/GNL appauvri/gaz de pipeline, et fonctionne à la fois en mode extraction d'éthane (C2) à 99 % selon les spécifications du pipeline et en mode récupération de condensats de gaz naturel par rejet d'éthane (C2), avec des économies en équipement et en énergie.
EP11835149.3A 2010-10-20 2011-10-20 Procédé de séparation et de récupération d'éthane et d'hydrocarbures plus lourds à partir de gnl Withdrawn EP2630220A4 (fr)

Applications Claiming Priority (3)

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US40519210P 2010-10-20 2010-10-20
US13/277,351 US20120096896A1 (en) 2010-10-20 2011-10-20 Process for separating and recovering ethane and heavier hydrocarbons from LNG
PCT/US2011/057106 WO2012054729A2 (fr) 2010-10-20 2011-10-20 Procédé de séparation et de récupération d'éthane et d'hydrocarbures plus lourds à partir de gnl

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EP2630220A2 true EP2630220A2 (fr) 2013-08-28
EP2630220A4 EP2630220A4 (fr) 2018-07-18

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US (1) US20120096896A1 (fr)
EP (1) EP2630220A4 (fr)
KR (1) KR20140123401A (fr)
AU (2) AU2011316983A1 (fr)
BR (1) BR112013009599A8 (fr)
CA (1) CA2818326A1 (fr)
EA (1) EA201390572A1 (fr)
MX (1) MX2013004441A (fr)
MY (1) MY184535A (fr)
SG (2) SG190306A1 (fr)
WO (1) WO2012054729A2 (fr)
ZA (1) ZA201303575B (fr)

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CA2958091C (fr) 2014-08-15 2021-05-18 1304338 Alberta Ltd. Procede d'elimination de dioxyde de carbone pendant la production de gaz naturel liquide a partir de gaz naturel dans des stations d'abaissement de pression de gaz
JP6527714B2 (ja) * 2015-02-25 2019-06-05 レール・リキード−ソシエテ・アノニム・プール・レテュード・エ・レクスプロワタシオン・デ・プロセデ・ジョルジュ・クロード 液体燃料ガスの供給装置および供給方法
KR102291922B1 (ko) 2015-04-28 2021-08-20 대우조선해양 주식회사 천연가스를 이용하여 중질탄화수소를 생산하는 ｆｌｎｇ 및 ｆｌｎｇ에서 천연가스를 이용하여 중질탄화수소를 생산하는 방법
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WO2012054729A3 (fr) 2012-07-12
SG10201508651UA (en) 2015-11-27
EP2630220A4 (fr) 2018-07-18
BR112013009599A2 (pt) 2018-09-25
AU2017200595B2 (en) 2019-02-07
AU2011316983A1 (en) 2013-06-06
AU2017200595A1 (en) 2017-02-23
BR112013009599A8 (pt) 2018-09-25
WO2012054729A2 (fr) 2012-04-26
MX2013004441A (es) 2014-07-24
ZA201303575B (en) 2015-08-26
KR20140123401A (ko) 2014-10-22
US20120096896A1 (en) 2012-04-26
EA201390572A1 (ru) 2013-11-29
CA2818326A1 (fr) 2012-04-26
SG190306A1 (en) 2013-06-28
MY184535A (en) 2021-04-01

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