EP2029949A2 - Procédé et dispositif pour traiter un courant d'hydrocarbures - Google Patents

Procédé et dispositif pour traiter un courant d'hydrocarbures

Info

Publication number
EP2029949A2
EP2029949A2 EP07765408A EP07765408A EP2029949A2 EP 2029949 A2 EP2029949 A2 EP 2029949A2 EP 07765408 A EP07765408 A EP 07765408A EP 07765408 A EP07765408 A EP 07765408A EP 2029949 A2 EP2029949 A2 EP 2029949A2
Authority
EP
European Patent Office
Prior art keywords
stream
liquid
gas
vaporous
liquid separator
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Withdrawn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
EP07765408A
Other languages
German (de)
English (en)
Inventor
Eduard Coenraad Bras
Hussein Mohammed Ismail Mostafa
Paramasivam Senthil Kumar
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.)
Shell Internationale Research Maatschappij BV
Original Assignee
Shell Internationale Research Maatschappij BV
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 Shell Internationale Research Maatschappij BV filed Critical Shell Internationale Research Maatschappij BV
Priority to EP07765408A priority Critical patent/EP2029949A2/fr
Publication of EP2029949A2 publication Critical patent/EP2029949A2/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Withdrawn legal-status Critical Current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
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G5/00—Recovery of liquid hydrocarbon mixtures from gases, e.g. natural gas
    • C10G5/06—Recovery of liquid hydrocarbon mixtures from gases, e.g. natural gas by cooling or compressing
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • 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
    • C10G7/00—Distillation of hydrocarbon oils
    • C10G7/02—Stabilising gasoline by removing gases by fractioning
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J3/00—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification
    • F25J3/02—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream
    • F25J3/0204—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream characterised by the feed stream
    • F25J3/0209—Natural gas or substitute natural gas
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J3/00—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification
    • F25J3/02—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream
    • F25J3/0228—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream characterised by the separated product stream
    • F25J3/0233—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream characterised by the separated product stream separation of CnHm with 1 carbon atom or more
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J3/00—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification
    • F25J3/02—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream
    • F25J3/0228—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream characterised by the separated product stream
    • F25J3/0242—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
    • F25J3/00—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification
    • F25J3/02—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream
    • F25J3/0228—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream characterised by the separated product stream
    • F25J3/0247—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream characterised by the separated product stream separation of CnHm with 4 carbon atoms or more
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
    • C10G2300/10—Feedstock materials
    • C10G2300/1025—Natural gas
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
    • C10G2300/40—Characteristics of the process deviating from typical ways of processing
    • C10G2300/4012—Pressure
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2200/00—Processes or apparatus using separation by rectification
    • F25J2200/02—Processes or apparatus using separation by rectification in a single pressure main column system
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2200/00—Processes or apparatus using separation by rectification
    • F25J2200/70—Refluxing the column with a condensed part of the feed stream, i.e. fractionator top is stripped or self-rectified
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2200/00—Processes or apparatus using separation by rectification
    • F25J2200/74—Refluxing the column with at least a part of the partially condensed overhead gas
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2205/00—Processes or apparatus using other separation and/or other processing means
    • F25J2205/02—Processes or apparatus using other separation and/or other processing means using simple phase separation in a vessel or drum
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2210/00—Processes characterised by the type or other details of the feed stream
    • F25J2210/06—Splitting of the feed stream, e.g. for treating or cooling in different ways
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2235/00—Processes or apparatus involving steps for increasing the pressure or for conveying of liquid process streams
    • F25J2235/60—Processes or apparatus involving steps for increasing the pressure or for conveying of liquid process streams the fluid being (a mixture of) hydrocarbons
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2245/00—Processes or apparatus involving steps for recycling of process streams
    • F25J2245/02—Recycle of a stream in general, e.g. a by-pass stream
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2260/00—Coupling of processes or apparatus to other units; Integrated schemes
    • F25J2260/20—Integration in an installation for liquefying or solidifying a fluid stream
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2270/00—Refrigeration techniques used
    • F25J2270/04—Internal refrigeration with work-producing gas expansion loop

Definitions

  • the present invention relates to a method of treating a hydrocarbon stream such as a natural gas stream, in particular in a process for the production of liquefied natural gas .
  • a hydrocarbon stream such as a natural gas stream
  • Several methods of treating a natural gas stream are known, e.g. to remove undesired components from the natural gas and/or to meet the required specifications of a client.
  • LNG liquefied natural gas
  • the natural gas stream to be liquefied (mainly comprising methane) contains ethane, heavier hydrocarbons and possibly other components that are to be removed to a certain extent before the natural gas is liquefied.
  • the natural gas stream is treated.
  • One of the treatments may involve the removal of at least some of the ethane, propane and higher hydrocarbons such as butane and propane.
  • a known method of treating a natural gas stream is disclosed in US 5 291 736 relating to a method for the liquefaction of natural gas, at the same time separating hydrocarbons heavier than methane.
  • One or more of the above or other objects are achieved according to the present invention by providing a method of treating a hydrocarbon stream such as a natural gas stream, the method at least comprising the steps of:
  • step (b) separating the feed stream in the first gas/liquid separator into a first vaporous stream and a first liquid stream; (c) expanding the first vaporous stream obtained in step (b) , thereby obtaining an at least partially condensed first vaporous stream;
  • step (d) supplying the at least partially condensed first vaporous stream obtained in step (c) to a second gas/liquid separator;
  • step (e) separating the stream as supplied in step (d) in the second gas/liquid separator into a second vaporous stream and a second liquid stream;
  • step (f) increasing the pressure of the second liquid stream obtained in step (e) to a pressure of at least 50 bar, thereby obtaining a pressurized second liquid stream;
  • the invention relates to a method of treating a hydrocarbon stream such as a natural gas stream, the method at least comprising the steps of: (a) supplying a partially condensed feed stream (10) to a first gas/liquid separator (2), the feed stream (10) preferably having a pressure > 30 bar;
  • step (c) expanding the first vaporous stream (20) obtained in step (b) , thereby obtaining an at least partially condensed first vaporous stream (30);
  • step (d) supplying the at least partially condensed first vaporous stream (30) obtained in step (c) to a second gas/liquid separator (4);
  • step (e) separating the stream (30) as supplied in step (d) in the second gas/liquid separator (4) into a second vaporous stream (60) and a second liquid stream (40) ;
  • step (f) increasing the pressure of the second liquid stream (40) obtained in step (e) to a pressure of at least 30 bar, thereby obtaining a pressurized second liquid stream (50); and (g) returning the pressurized second liquid stream (50) obtained in step (f) to the first gas/liquid separator ( 2 ) .
  • the method according to the invention is especially advantageous as the feed stream is available at a relatively high pressure, typically > (above) 50 bar, preferably above 55 bar, more preferably above 60 bar. Whenever in the specification and claims reference is made to a pressure in bar, this is a pressure in bar (absolute) .
  • the hydrocarbon stream may be any suitable stream to be treated, but is usually a natural gas stream obtained from natural gas or petroleum reservoirs.
  • the natural gas stream may also be obtained from another source, also including a synthetic source such as a Fischer-Tropsch process.
  • the natural gas stream is comprised substantially of methane.
  • the feed stream comprises at least 60 mol% methane, more preferably at least 75 mol%, such as at least 80 mol% methane.
  • the natural gas may contain varying amounts of hydrocarbons heavier than methane such as ethane, propane, butanes and pentanes as well as some aromatic hydrocarbons.
  • the natural gas stream may also contain non-hydrocarbons such as H2O, mercury, N2, CO2,
  • the feed stream containing the natural gas may be pre-treated before feeding it to the first gas/liquid separator.
  • This pre-treatment may comprise removal of undesired components such as H2O, mercury, N2, CO2, H2S and other sulphur compounds, or other steps such as pre-cooling or pre-pressurizing. As these steps are well known to the person skilled in the art, they are not further discussed here.
  • the feed stream has a temperature in the range from ambient to 90 0 C, preferably from 20 0 C to 80 0 C.
  • the pressure of the feedstream is in the range from more than 50 bar to 100 bar, more preferably from more than 55 bar to 90 bar, even more preferably from more than 60 bar to 80 bar.
  • the first and second gas/liquid separators may be any suitable means for obtaining a vaporous stream and a liquid stream, such as a vessel, a scrubber, a distillation column, etc.
  • the first gas/liquid separator comprises a column having 1-30 trays, preferably 1-15 trays .
  • the second gas/liquid separator usually comprises a simple vessel with only one tray.
  • the second gas/liquid separator preferably comprises a column having 1-30 trays, more preferably 1-15 trays.
  • the first and second gas/liquid separators may each be provided with packing (random or structured) . When the gas/liquid separator is provided with trays, a distillation stage corresponds to one tray, and when the gas/liquid separator is provided with packing (random or structured) a distillation stage corresponds to a theoretical stage.
  • a level of introducing a stream into the gas/liquid separator is defined relative to introducing another stream, there is at least one distillation stage between the two levels, the same applies to defining the level of removing a stream from the gas/liquid separator.
  • the top of the gas/liquid separator is that part of the gas/liquid separator that is located above the uppermost distillation stage, and the bottom of the gas/liquid separator is that part of the gas/liquid separator that is located below the lowermost distillation stage.
  • the first liquid stream and the second vaporous stream may be used as product streams or may be further processed, if desired.
  • step (f) of the method of the present invention the pressure of the second liquid stream obtained in step (e) is increased to a pressure of at least 50 bar, thereby obtaining a pressurized second liquid stream.
  • the pressure of the second liquid stream is increased to a pressure in the range from more than 50 bar to 100 bar, more preferably from more than 55 bar to 90 bar, even more preferably from more than 60 bar to 80 bar .
  • the pressure of the second liquid stream is in the range from 0 to 5 bar higher than the pressure in the first gas/liquid separator, preferably from 0 to 2 bar higher, even more preferably from 0 to 1 bar higher, in particular substantially the same pressure.
  • the feed stream is supplied as at least two different streams to the first gas/liquid separator, the feed stream comprising a higher feed stream and a lower feed stream.
  • the higher feed stream is fed at a warmer (i.e. higher) point of the first gas/liquid separator than the lower feed stream (that is fed at a lower, i.e. colder, point of the first gas/liquid separator) .
  • the higher feed stream is cooled, preferably against the second vaporous stream obtained in step (e) .
  • a heat exchanger may be used.
  • the first liquid stream obtained in step (b) is supplied to a third gas/liquid separator thereby obtaining a third vaporous stream and a third liquid stream.
  • the third vaporous stream is combined with the second vaporous stream.
  • the present invention relates to an apparatus for treating a hydrocarbon stream such as a natural gas stream, the apparatus at least comprising: a first gas/liquid separator for separating a partially condensed feed stream into a first vaporous stream and a first liquid stream; an expander for expanding the first vaporous stream; - a second gas/liquid separator for separating the expanded first vaporous stream into a second vaporous stream and a second liquid stream; and a pressurizing unit for increasing the pressure of the second liquid stream to at least 50 bar before being returned to the first gas/liquid separator.
  • a first gas/liquid separator for separating a partially condensed feed stream into a first vaporous stream and a first liquid stream
  • an expander for expanding the first vaporous stream
  • - a second gas/liquid separator for separating the expanded first vaporous stream into a second vaporous stream and a second liquid stream
  • a pressurizing unit for increasing the pressure of the second liquid stream to at least 50 bar before being returned to
  • the first gas/liquid separator comprises at least two inlets for the feed stream, including an inlet for a higher feed stream and an inlet for a lower feed stream. It is especially preferred that the apparatus further comprises a heat exchanger for cooling the higher feed stream against the second vaporous stream.
  • the apparatus further comprises a third gas/liquid separator for separating the first liquid stream into a third vaporous stream and a third liquid stream.
  • a third gas/liquid separator for separating the first liquid stream into a third vaporous stream and a third liquid stream.
  • the third vaporous stream can be combined with the second vaporous stream.
  • FIG. 1 schematically a process scheme in accordance with an embodiment of the present invention.
  • FIG. 2 schematically a process scheme in accordance with another embodiment of the present invention.
  • Figure 1 schematically shows a process scheme enabling selective low temperature separation of heavy hydrocarbons (C5 + ) in a gas plant with flexibility to recover/reject LPGs.
  • a partially condensed hydrocarbon feed stream 10 such as natural gas is supplied to a first gas/liquid separator 2 at a certain inlet pressure and inlet temperature .
  • the feed stream 10 is fed as two different streams, viz. a higher feed stream 10a and a lower feed stream 10b. If desired the feed stream 10 may be split in more than two sub- streams.
  • the higher feed stream 10a is pre-cooled in heat exchanger 6 and fed to the separator 2 at first inlet 11; the lower feed stream 10b is fed to the separator 2 at second inlet 12.
  • stream 10a is cooled against another stream in the process (i.e. stream 60) .
  • any other cooling may be used, if desired.
  • the feed stream 10 has a temperature in the range from ambient to 90 0 C, preferably from 20 0 C to 80 0 C.
  • the pressure of the feedstream is in the range from more than 50 bar to 100 bar, more preferably from more than 55 bar to 90 bar, even more preferably from more than 60 bar to 80 bar.
  • the temperature and pressure of the streams 10a and 10b is chosen to optimise a gas/liquid separation step in separator 2. If desired, the pressure of the streams 10a and 10b may have been adjusted in valves 13 and 14, respectively .
  • stream 10 is fed to the gas/liquid separator 2 as streams 10a and 10b.
  • the feed stream 10 is separated into a first vaporous (i.e. overhead) stream 20 and a first liquid (i.e. bottom) stream 70.
  • the overhead stream 20 leaves the separator 2 at first outlet 15 and is enriched in methane (and usually also ethane) relative to the feed stream 10.
  • the bottom stream 70 leaves the separator 2 at second outlet 16 and is generally liquid; stream 70 may contain hydrocarbons that can be separately processed to form liquefied petroleum gas (LPG) products.
  • LPG liquefied petroleum gas
  • the bottom stream 70 is subjected to one or more fractionation steps to collect various natural gas liquid products .
  • the overhead stream 20 is led to an expander 3, thereby at least partially condensing the stream 20, thereby obtaining stream 30.
  • stream 30 is fed to a second gas/liquid separator 4 at inlet 21.
  • the partially condensed stream 30 is separated into a second vaporous (i.e. overhead) stream 60 and a second liquid (i.e. bottom) stream 40.
  • the overhead stream 60 leaves the separator 4 at outlet
  • the bottom stream 40 leaves the separator 4 at outlet 23 and is generally liquid. Then the stream 40 is pressurized in pressurizing unit 5 to a pressure of at least 50 bar.
  • the pressurizing unit 5 may be any suitable means for increasing the pressure such as a pump.
  • the pressurized stream 50 leaving the pressurizing unit 5 is subsequently returned to the first gas/liquid separator 2, preferably at the warm (i.e. high) part thereof, at third inlet 17 of the first separator 2.
  • the first liquid stream 70 and the second vaporous stream 60 may be used as product streams or may be further processed, if desired.
  • the second vaporous stream 60 is used to cool the higher feed stream 10a in heat exchanger 6.
  • the first liquid stream 70 is (after being optionally depressurized in valve 33) fed (as stream 70a) to a third gas/liquid separator 7 (at inlet 34) thereby obtaining (at outlet 31) a third vaporous stream 80 and (at outlet 32) a third liquid stream 90.
  • the third vaporous stream 80 is combined with the second vaporous stream 65 (i.e. stream 60 after being heat exchanged in heat exchanger 6) at junction point 18 and is subsequently compressed in compressor 8 thereby obtaining product gas 100 which will usually be subjected to a liquefaction step in one or more heat exchangers (not shown) thereby obtaining liquefied natural gas (LNG) .
  • LNG liquefied natural gas
  • some further treatment steps may take place to remove any contaminants that may solidify during the liquefaction process.
  • a (n optionally additional) CO2 removal step may take place.
  • Stream 80 may be compressed to about the same pressure of the second vaporous stream 65 before stream 80 is combined with the second vaporous stream 65 at the junction point 18.
  • Figure 2 schematically shows an alternative embodiment of the present invention to provide an integrated gas dew pointing and condensate stabilizing process, wherein the third column 7 is in the form of a debutanizer/stabilizer, thereby obtaining a third vaporous stream 80 being enriched in butane and lower hydrocarbons (such as methane, ethane and or propane) relative to the third liquid stream 90.
  • the third column 7 is in the form of a debutanizer/stabilizer, thereby obtaining a third vaporous stream 80 being enriched in butane and lower hydrocarbons (such as methane, ethane and or propane) relative to the third liquid stream 90.
  • Figure 2 shows that the third vaporous stream 80, before being combined with stream 65 in junction point 18, has previously been cooled (as stream 80a) against (an air cooler or water cooler or, as shown) an external refrigerant in heat exchanger 55, fed (as stream 80b) to a fourth gas/liquid separator 19 at inlet 41, and removed at outlet 42 from the fourth gas/liquid separator 19 (as stream 80) .
  • the fourth gas/liquid separator 19 functions as an overhead condenser drum.
  • liquid bottom stream 110 removed at outlet 43 from the fourth gas/liquid separator 19 is pressurized in pump 51 and returned as stream 120 to the top (at inlet 33) of the debutanizer 7.
  • a part of the bottom stream 90 (or 'condensate') of the debutanizer/stabilizer 7 is split off at splitter 56, heat exchanged as stream 130 against an external stream in heat exchanger 52 (functioning as a reboiler) and returned as stream 140 to the bottom (at inlet 35) of the debutanizer/stabilizer 7.
  • the major part of the condensate stream 90 is (after splitter 56) heat exchanged against the first liquid stream 70 in heat exchanger 53 and subsequently against stream 10b in heat exchanger 54 and used as a product stream.
  • stream 70 (or 70a) against stream 90 in heat exchanger 53
  • stream 70 (or 70a) may be heat exchanged against stream 80a, for example in heat exchanger 55.
  • one or more further gaseous and/or liquid streams may be introduced into the debutanizer/stabilizer 7.
  • the line-up as used in Figure 2 allows to produce a product gas stream 80 with a surprisingly high content of LPGs (i.e. propane and/or butane) and a condensate stream 90 with a surprisingly high content of C5+ (i.e. pentane and higher components) .
  • LPGs i.e. propane and/or butane
  • C5+ i.e. pentane and higher components
  • stream 80 may be used as a separate product stream, but will usually combined with stream 65 to enrich the latter stream.
  • Table I gives an overview of the estimated pressures and temperatures of a stream at various parts in an example process of Fig. 2. Also the mole fraction of methane is indicated.
  • the feed stream in line 10 of Fig. 2 comprised approximately the following composition: 75.2 mole % methane, 9.2 mole % ethane, 4.3 mole % propane, 2.1 mole % butanes, 5.2 mole % 05+, 1.2 mole % N2 and 2.7 mole % CO2 ⁇ H2S and H2O were previously removed.
  • the expander 3 and compressor 8 may be functionally coupled.

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  • Engineering & Computer Science (AREA)
  • Chemical & Material Sciences (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Physics & Mathematics (AREA)
  • General Chemical & Material Sciences (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • Mechanical Engineering (AREA)
  • Thermal Sciences (AREA)
  • General Engineering & Computer Science (AREA)
  • Organic Chemistry (AREA)
  • Separation By Low-Temperature Treatments (AREA)
  • Organic Low-Molecular-Weight Compounds And Preparation Thereof (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)

Abstract

La présente invention concerne un procédé de traitement d'un flux d'hydrocarbures tel qu'un flux de gaz naturel, le procédé comportant au moins les étapes consistant à : (a) amener un flux (10) de charge partiellement condensé à un premier séparateur (2) gaz / liquide, ledit flux (10) de charge se trouvant à une pression > 50 bar ; (b) séparer le flux (10) de charge dans le premier séparateur (2) gaz / liquide en un premier flux (20) de vapeur et en un premier flux (70) de liquide ; (c) détendre le premier flux (20) de vapeur, obtenant ainsi un premier flux (30) de vapeur au moins partiellement condensé ; (d) amener le premier flux (30) de vapeur au moins partiellement condensé à un deuxième séparateur (4) gaz / liquide ; (e) séparer le flux (30) tel qu'amené à l'étape (d) dans le deuxième séparateur (4) gaz / liquide en un deuxième flux (60) de vapeur et en un deuxième flux (40) de liquide ; (f) augmenter la pression du deuxième flux (40) de liquide jusqu'à une pression d'au moins 50 bar, obtenant ainsi un deuxième flux (50) de liquide sous pression ; et (g) renvoyer le deuxième flux (50) de liquide sous pression au premier séparateur (2) gaz / liquide.
EP07765408A 2006-06-16 2007-06-14 Procédé et dispositif pour traiter un courant d'hydrocarbures Withdrawn EP2029949A2 (fr)

Priority Applications (1)

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EP07765408A EP2029949A2 (fr) 2006-06-16 2007-06-14 Procédé et dispositif pour traiter un courant d'hydrocarbures

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EP06115604 2006-06-16
EP07765408A EP2029949A2 (fr) 2006-06-16 2007-06-14 Procédé et dispositif pour traiter un courant d'hydrocarbures
PCT/EP2007/055866 WO2007144395A2 (fr) 2006-06-16 2007-06-14 Procédé et appareil de traitement d'un flux d'hydrocarbures

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JP (1) JP5210302B2 (fr)
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EG (1) EG25971A (fr)
RU (1) RU2446370C2 (fr)
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FR2943683B1 (fr) * 2009-03-25 2012-12-14 Technip France Procede de traitement d'un gaz naturel de charge pour obtenir un gaz naturel traite et une coupe d'hydrocarbures en c5+, et installation associee
US10852060B2 (en) 2011-04-08 2020-12-01 Pilot Energy Solutions, Llc Single-unit gas separation process having expanded, post-separation vent stream
RU2460759C1 (ru) * 2011-07-08 2012-09-10 Илшат Минуллович Валиуллин Способ подготовки углеводородного газа
EP2977430A1 (fr) 2014-07-24 2016-01-27 Shell Internationale Research Maatschappij B.V. Stabilisateur de condensat d'hydrocarbure et procédé de production d'un flux de condensat d'hydrocarbure stabilisé
EP2977431A1 (fr) * 2014-07-24 2016-01-27 Shell Internationale Research Maatschappij B.V. Stabilisateur de condensat d'hydrocarbure et procédé de production d'un flux de condensat d'hydrocarbure stabilisé
WO2017040161A1 (fr) * 2015-08-28 2017-03-09 Uop Llc Procédés de stabilisation d'un flux d'hydrocarbure liquide
RU2761489C1 (ru) * 2020-10-29 2021-12-08 Публичное акционерное общество "Газпром" Способ низкотемпературной подготовки природного газа и установка для его осуществления

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US20090188279A1 (en) 2009-07-30
EG25971A (en) 2012-11-13
JP5210302B2 (ja) 2013-06-12
RU2009101148A (ru) 2010-07-27
RU2446370C2 (ru) 2012-03-27
WO2007144395A2 (fr) 2007-12-21
AU2007259229A1 (en) 2007-12-21
JP2009540080A (ja) 2009-11-19
WO2007144395A3 (fr) 2008-10-30
AU2007259229B2 (en) 2010-07-01

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