WO2011009832A2 - Procédé pour le traitement d'un courant d'hydrocarbure à plusieurs phases et appareil correspondant - Google Patents

Procédé pour le traitement d'un courant d'hydrocarbure à plusieurs phases et appareil correspondant Download PDF

Info

Publication number
WO2011009832A2
WO2011009832A2 PCT/EP2010/060409 EP2010060409W WO2011009832A2 WO 2011009832 A2 WO2011009832 A2 WO 2011009832A2 EP 2010060409 W EP2010060409 W EP 2010060409W WO 2011009832 A2 WO2011009832 A2 WO 2011009832A2
Authority
WO
WIPO (PCT)
Prior art keywords
stream
hydrocarbon
gas
separator
vapour
Prior art date
Application number
PCT/EP2010/060409
Other languages
English (en)
Other versions
WO2011009832A3 (fr
Inventor
Alexandra Teodora Anghel
Marco Dick Jager
Original Assignee
Shell Internationale Research Maatschappij B.V.
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 B.V. filed Critical Shell Internationale Research Maatschappij B.V.
Priority to CA2767369A priority Critical patent/CA2767369C/fr
Priority to RU2012106137/06A priority patent/RU2554736C2/ru
Priority to BR112012001046-8A priority patent/BR112012001046B1/pt
Priority to EP10736661A priority patent/EP2457046A2/fr
Priority to CN201080032554XA priority patent/CN102782430A/zh
Priority to JP2012521012A priority patent/JP5730302B2/ja
Priority to AU2010275307A priority patent/AU2010275307B2/en
Priority to US13/384,783 priority patent/US20120167617A1/en
Publication of WO2011009832A2 publication Critical patent/WO2011009832A2/fr
Publication of WO2011009832A3 publication Critical patent/WO2011009832A3/fr

Links

Classifications

    • 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
    • F25J1/00—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
    • F25J1/02—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures requiring the use of refrigeration, e.g. of helium or hydrogen ; Details and kind of the refrigeration system used; Integration with other units or processes; Controlling aspects of the process
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J1/00—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
    • F25J1/0002—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures characterised by the fluid to be liquefied
    • F25J1/0022—Hydrocarbons, e.g. natural gas
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J1/00—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
    • F25J1/003—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures characterised by the kind of cold generation within the liquefaction unit for compensating heat leaks and liquid production
    • F25J1/0032—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures characterised by the kind of cold generation within the liquefaction unit for compensating heat leaks and liquid production using the feed stream itself or separated fractions from it, i.e. "internal refrigeration"
    • F25J1/004—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures characterised by the kind of cold generation within the liquefaction unit for compensating heat leaks and liquid production using the feed stream itself or separated fractions from it, i.e. "internal refrigeration" by flash gas recovery
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J1/00—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
    • F25J1/003—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures characterised by the kind of cold generation within the liquefaction unit for compensating heat leaks and liquid production
    • F25J1/0032—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures characterised by the kind of cold generation within the liquefaction unit for compensating heat leaks and liquid production using the feed stream itself or separated fractions from it, i.e. "internal refrigeration"
    • F25J1/0042—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures characterised by the kind of cold generation within the liquefaction unit for compensating heat leaks and liquid production using the feed stream itself or separated fractions from it, i.e. "internal refrigeration" by liquid expansion with extraction of work
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J1/00—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
    • F25J1/02—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures requiring the use of refrigeration, e.g. of helium or hydrogen ; Details and kind of the refrigeration system used; Integration with other units or processes; Controlling aspects of the process
    • F25J1/0228—Coupling of the liquefaction unit to other units or processes, so-called integrated processes
    • F25J1/0229—Integration with a unit for using hydrocarbons, e.g. consuming hydrocarbons as feed stock
    • F25J1/023—Integration with a unit for using hydrocarbons, e.g. consuming hydrocarbons as feed stock for the combustion as fuels, i.e. integration with the fuel gas 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
    • F25J1/00—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
    • F25J1/02—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures requiring the use of refrigeration, e.g. of helium or hydrogen ; Details and kind of the refrigeration system used; Integration with other units or processes; Controlling aspects of the process
    • F25J1/0243—Start-up or control of the process; Details of the apparatus used; Details of the refrigerant compression system used
    • F25J1/0257—Construction and layout of liquefaction equipments, e.g. valves, machines
    • F25J1/0262—Details of the cold heat exchange system
    • F25J1/0264—Arrangement of heat exchanger cores in parallel with different functions, e.g. different cooling streams
    • 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
    • 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
    • F25J3/0257—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 nitrogen
    • 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
    • F25J2200/40—Features relating to the provision of boil-up in the bottom of a column
    • 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
    • F25J2215/00—Processes characterised by the type or other details of the product stream
    • F25J2215/04—Recovery of liquid products
    • 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
    • F25J2240/00—Processes or apparatus involving steps for expanding of process streams
    • F25J2240/30—Dynamic liquid or hydraulic expansion with extraction of work, e.g. single phase or two-phase turbine
    • 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
    • F25J2245/00—Processes or apparatus involving steps for recycling of process streams
    • F25J2245/90—Processes or apparatus involving steps for recycling of process streams the recycled stream being boil-off gas from storage
    • 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
    • F25J2260/60—Integration in an installation using hydrocarbons, e.g. for fuel purposes
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02T—CLIMATE CHANGE MITIGATION TECHNOLOGIES RELATED TO TRANSPORTATION
    • Y02T10/00—Road transport of goods or passengers
    • Y02T10/10—Internal combustion engine [ICE] based vehicles
    • Y02T10/30—Use of alternative fuels, e.g. biofuels

Definitions

  • the present invention relates to a method and
  • the method and apparatus provide a treated liquid hydrocarbon stream.
  • a low pressure fuel gas stream may additionally be provided.
  • a common source for a multi-phase hydrocarbon stream is a natural gas stream or a multi-phase stream produced from natural gas e.g. by forming a multi-phase stream comprising a vapour phase and a liquid phase by way of cooling and/or changing the pressure of the natural gas.
  • the methods described herein may thus be employed to provide a treated liquid hydrocarbon stream in the form of a liquefied natural gas (LNG) stream.
  • LNG liquefied natural gas
  • Natural gas is a useful fuel source, as well as being a source of various hydrocarbon compounds. It is often desirable to liquefy natural gas in a liquefied natural gas (LNG) plant at or near the source of a natural gas stream for a number of reasons. As an example, natural gas can be stored and transported over long distances more readily as a liquid than in gaseous form because it occupies a smaller volume and does not need to be stored at high pressure.
  • LNG liquefied natural gas
  • natural gas comprising predominantly methane
  • the purified gas is processed through a plurality of cooling stages using heat exchangers to progressively reduce its
  • the flashed vapour from each expansion can be used as a source of fuel gas.
  • Some hydrocarbon streams such as natural gas, may contain significant quantities of nitrogen such that if special measures are not taken to remove at least a part of the nitrogen from the hydrocarbon stream, the fuel gas and any liquefied hydrocarbon stream produced may contain undesirably high nitrogen levels.
  • Many LNG specifications require less than 1 mol% nitrogen in the final product.
  • US 2008/0066493 discloses a method of treating liquefied natural gas to provide a liquid natural gas stream having a reduced content of components having low boiling points, such as nitrogen (N2)• The method
  • At least part of the cold present in the overhead gaseous stream is thus used to recondense a recycle stream to produce reflux, which cold cannot be used to cool another process stream elsewhere in the process.
  • the present invention provides a method of treating a multi-phase hydrocarbon stream to provide a treated liquid hydrocarbon stream, comprising at least the steps of:
  • the present invention provides an apparatus for treating a multi-phase hydrocarbon stream comprising a liquid phase and a vapour phase to provide a treated liquid hydrocarbon stream in the form of LNG, comprising at least:
  • - means for producing a multi-phase hydrocarbon stream from natural gas comprising at least one of a liquefaction unit and one or more hydrocarbon stream expansion devices;
  • first gas/liquid separator arranged to receive the multi-phase hydrocarbon stream and separate it into a first separator hydrocarbon vapour stream, comprising hydrocarbons and nitrogen, and a first separator bottoms stream, said first gas/liquid separator having a first inlet for feeding the multi-phase hydrocarbon stream into the first gas/liquid separator, a first outlet for discharching the first separator hydrocarbon vapour stream from the first gas/liquid separator, a second outlet for discharging the first separator bottoms stream from the first gas/liquid separator and a second inlet, located at a level gravitationally lower than said first inlet, for feeding a stripping vapour stream into the first gas/liquid separator;
  • a second gas/liquid separator arranged to receive the first separator bottoms stream and separate it into a second separator hydrocarbon vapour stream and a treated liquid hydrocarbon stream in the form of LNG, said second gas/liquid separator having a first inlet in fluid communication with the second outlet of the first
  • an overhead stream compressor to compress the second separator hydrocarbon vapour stream to provide the stripping vapour stream
  • said overhead stream compressor having an inlet in fluid communication with the first outlet of the second gas/liquid separator to receive the second separator hydrocarbon vapour stream, and an outlet in fluid communication with the second inlet of the first gas/liquid separator for discharging the stripping vapour stream.
  • Figure 1 is a diagrammatic scheme of a method of and apparatus for treating a multi-phase hydrocarbon stream according to one embodiment
  • Figure 2 is a diagrammatic scheme of a method of and apparatus for liquefying a hydrocarbon feed stream incorporating the multi-phase hydrocarbon stream treating method and apparatus .
  • the second separator hydrocarbon vapour stream from the second gas/liquid separator is compressed in an overhead stream compressor and returned to the first gas/liquid separator as a stripping vapor stream.
  • hydrocarbon stream that does not require the cold in the overhead gaseous stream to be used to produce a reflux stream.
  • the method and apparatus of the present invention advantageously utilize a stripping vapor in the first gas/liquid separator that is provided by the compression of the vapour stream from the second gas/liquid
  • the one or more hydrocarbon stream expansion devices and the first and second gas/liquid separators may form part of an LNG end flash system.
  • the reducing of the pressure of the at least partially liquefied hydrocarbon stream to provide the multi-phase hydrocarbon stream and the subsequent separation in the first and second gas/liquid separators may form part of an LNG end flash process.
  • hydrocarbon stream from the natural gas may comprise the following steps:
  • the multi-phase stream may comprise a vapour phase and a liquid phase.
  • the treated liquid hydrocarbon stream produced in accordance with the present invention in particular when provided in the form of LNG, may have a specification suitable for it to be vaporized and used as network gas .
  • the Applicant suggests that the overhead stream compressor provides heat of compression to the second separator hydrocarbon vapour stream and thus functions as a special reboiler, providing a stripping vapour stream at a higher pressure and
  • This stripping vapor stream enhances the separation of the lower boiling point components, such as nitrogen, from the expanded hydrocarbon stream in the first gas/liquid separator.
  • the lower boiling point components are ejected to the first separator hydrocarbon vapor stream.
  • the method may further comprise:
  • the combustion device at a fuel gas pressure not higher than the pressure of the first separator hydrocarbon vapour stream.
  • the first pressure of the first gas/liquid separator may be at or above the fuel gas pressure.
  • the first separator hydrocarbon vapour stream nor the low pressure fuel gas stream is compressed before use in the combustion device.
  • Table 1 of US 2008/0066493 discloses an example in which a natural gas feed stream having a nitrogen content of 3.05 mol% is treated to provide a liquefied natural gas stream having a nitrogen content of 0.65 mol% and a fuel gas having a nitrogen content of 24 mol%.
  • the first separator hydrocarbon vapour stream is employed as low pressure fuel gas stream.
  • Fuel gas with large amounts of nitrogen can still be used as low pressure fuel gas to fuel for instance a furnace, a boiler, and/or a dual fuel diesel engine.
  • low pressure in the low pressure fuel gas stream is relative to the "high
  • a low pressure fuel gas may be at a pressure in a range of from 2 to 15 bara, more specifically in a range of from 2 to 10 bara.
  • a high pressure (HP) fuel may be at a pressure of higher than 15 bara, generally in a range of 15 to 40 bara, more specifically in a range of from 20 to 30 bara.
  • the first gas/liquid separator may advantageously be operated at a suitable fuel gas pressure or above, such that the first separator hydrocarbon vapour stream may advantageously be provided at high enough pressure requiring no, or no extensive, compression before use. It is thus preferred to select the first pressure of the first gas/liquid separator such that the first separator hydrocarbon vapour stream is provided at or above the desired fuel gas pressure.
  • the first separator hydrocarbon vapour stream of the present invention may comprise N2 in a wide range, for instance in a range of from 30 mol% to 95 mol% N2, more preferably in the range of from 60 mol% to 95 mol%.
  • the present invention may advantageously be employed to provide a low pressure fuel gas stream, suitable for use in a combustion device such as a furnace or incinerator, or for instance in a dual fuel diesel engine that may be employed for electric power generator.
  • the low pressure fuel gas stream may be derived from the first separator hydrocarbon vapour stream by warming.
  • the first separator hydrocarbon vapour stream can be sent to any suitable heat exchange device in which it can be used to cool a process stream.
  • the process stream may be provided in the form of a part of the natural gas to cool this part of the natural gas.
  • the treating method and apparatus disclosed herein may be incorporated into a method of liquefying a hydrocarbon feed stream and an apparatus therefor.
  • High pressure fuel gas may be extracted from the hydrocarbon feed stream prior to liquefaction. This is advantageous because the hydrocarbon feed stream may have a low nitrogen content compared to the low pressure fuel gas stream derived from the first separator hydrocarbon vapour stream.
  • the hydrocarbon feed stream is a high pressure stream, such that further pressurization of a portion of this stream for use as a fuel gas stream is not required.
  • a high pressure fuel gas compressor there is no requirement for a high pressure fuel gas compressor.
  • the pressure of the extracted fuel gas may optionally be reduced in pressure before use as fuel.
  • gaseous streams produced by gas/liquid separation steps such as end flash processes, would have a higher content of lower boiling components, such as nitrogen, compared to the liquid product produced by the separator.
  • Figure 1 shows a method of and apparatus 1 for treating a multi-phase hydrocarbon stream 145 according to a first embodiment.
  • the multiphase hydrocarbon stream 145 is derived from natural gas.
  • the multi-phase hydrocarbon stream 145 comprises vapour and liquid phases.
  • One example of how the multi-phase hydrocarbon stream 145 may be provided is discussed in greater detail below with reference to Figure 2.
  • the multi-phase hydrocarbon stream 145 is passed to a first inlet 148 of a first gas/liquid separator 150.
  • the first gas/liquid separator 150 provides a first separator hydrocarbon vapour stream 205 as an overhead stream at a first outlet 151 and a first separator bottoms stream 155a, which is a liquid stream, at a second outlet 152 at or near the bottom of the first gas/liquid separator 150.
  • the first gas/liquid separator 150 may be in the form of a separation column such as a fractionation or
  • the first gas/liquid separator 150 is preferably provided in the form of a nitrogen
  • the first separator hydrocarbon vapour stream 205 typically comprises hydrocarbons, typically predominantly methane, and nitrogen.
  • a stripping vapour stream 185a is provided at a second inlet 149.
  • the second inlet 149 typically comprises a vapour inlet device known to the skilled person.
  • the second inlet 149 is preferably at a level gravitationally lower than the first inlet 148 in order to provide efficient stripping of the lighter components of the hydrocarbon mixture, such as nitrogen, from the liquid phase of the multi-phase hydrocarbon stream to the vapour phase.
  • the first inlet 148 may typically comprise an inlet distributor known to the skilled person.
  • the first gas/liquid separator 150 comprises a contacting zone preferably comprising contact enhancing means 154 such as trays or packing, to enhance separation.
  • the contact enhancing means 154 is preferably placed gravitationally between the first and second inlets 148, 149.
  • the contact enhancing means may comprise a plurality of trays stacked one above the other can be arranged to force the liquid phase to flow horizontally along each tray before falling to the next tray, with the vapour phase bubbling through holes in the trays. This increases the amount of contact area between the liquid and vapour phases.
  • the contact enhancing means may comprise packing. A contacting zone of packing operates in a similar manner to the trays with the packing, which can be either structured or random, increasing the contact area between the liquid and vapour phases.
  • the first separator hydrocarbon vapour stream 205 may comprise hydrocarbons and an inventory of greater than or equal to 30 mol% N2. It is preferred that the first separator hydrocarbon vapour stream 205 has a pressure of less than or equal to 10 bara.
  • a low pressure fuel gas stream 215 may be derived from the first separator hydrocarbon vapour stream 205.
  • the first separator hydrocarbon vapour stream 205 may be passed to a fuel gas heat exchanger 210, where it is warmed against a warming stream 355 to provide the low pressure fuel gas stream 215, for
  • the warming stream is cooled and turned into a cooled warming stream 365.
  • the fuel gas heat exchanger 210 may be a heater, such as an ambient heater in which case the warming stream 355 may be provided in the form of ambient air or ambient water, to provide the cooled warming stream 365 in the form of cooled air or cooled water stream.
  • the cooled warming stream 365 may be employed as an intermediate stream to chill another stream.
  • the warming stream 355 is provided in the form of a process stream that needs to be cooled, thus additionally providing a cooled process stream.
  • the cold energy from the first separator hydrocarbon vapour stream 205 can be efficiently used to provide cooling to a process stream in the apparatus 1, such as a hydrocarbon or refrigerant stream. An example of this is provided in relation to the embodiment of Figure 2.
  • the low pressure fuel gas stream 215 may comprise greater than or equal to 30 mol% N2.
  • the low pressure fuel gas stream 215 can then be passed to a low pressure fuel gas network.
  • Figure 1 shows the low pressure fuel gas stream 215 being passed directly to one or more low pressure fuel gas consumers 220, for example a combustion device, such as a furnace, boiler, or dual fuel diesel engine. Such combustion devices can typically tolerate high levels of nitrogen in the low pressure fuel gas, as known to the skilled person.
  • the first separator bottoms stream 155a from the first gas/liquid separator 150 may be passed to the first inlet 158 of a second gas/liquid separator 160.
  • the second gas/liquid separator 160 operates at a second pressure, which is lower that the first pressure used to provide separation in the first gas/liquid separator 150.
  • the second pressure is preferably less than 4 bara, still more preferably less than 2 bara.
  • the second pressure may suitably be at or near atmospheric pressure.
  • at or near atmospheric pressure is preferably interpreted as a pressure of between 1 and 1.3 bara.
  • the first separator bottoms stream 155a can be passed through a bottoms stream expansion device 200, which provides an (expanded) first separator bottoms stream 155b to the first inlet 158 of a second gas/liquid separator 160 at the second pressure .
  • the second gas/liquid separator 160 provides a second separator hydrocarbon vapour stream 175 as an overhead stream at a first outlet 161 and a treated liquid
  • the second gas/liquid separator 160 may be a suitable flash vessel.
  • the treated liquid hydrocarbon stream 165 which may be a LNG stream when the multi-phase hydrocarbon stream 145 is derived from natural gas, can be provided at or near atmospheric pressure.
  • the treated liquid hydrocarbon stream 165 may be passed to a storage tank 170, such as a cryogenic storage tank.
  • the second separator hydrocarbon vapour stream 175 is passed to an overhead stream compressor 180, where it is compressed to provide a stripping vapour stream 185.
  • the overhead stream compressor 180 may be mechanically driven by an overhead stream compressor driver 190, such as a gas turbine, a steam turbine, and/or an electric motor.
  • the stripping vapour stream 185 may optionally be
  • the stripping vapour stream 185 is provided at a third pressure which should be typically equal to or slightly higher than the first pressure, for example the first pressure plus any pressure loss between the
  • the third pressure may be in the range of from 0 to 2 bara higher than the first pressure.
  • the supplementary stripping vapour stream 235 may comprise boil off gas from a cryogenic storage tank. In case of cryogenic storage of the treated liquid
  • boil off gas (BOG) stream 195 The boil off gas stream 195 can be passed to boil off gas compressor 230, where it is compressed to provide compressed a compressed boil off gas stream 235 for use as supplementary stripping vapour stream.
  • the boil off gas compressor 230 can be driven by a boil off gas compressor driver 240, such as a gas or steam turbine and/or electric motor.
  • the supplemental stripping vapour stream 235 may be passed directly to a further, separate inlet of the first gas/liquid separator 150.
  • the ultimate choice for where the supplemental stripping vapour 235 is supplied to the first gas/liquid separator may be driven by by the composition and temperature of the supplemental stripping vapour stream 235, such as the compressed boil off gas stream.
  • the method disclosed herein can be utilised as part of a liquefaction process for a hydrocarbon feed stream in which case the multiphase hydrocarbon stream to be treated may be formed by cooling and/or changing the pressure of a hydrocarbon feed stream.
  • the hydrocarbon feed stream may be any suitable gas stream to be cooled and liquefied, but is usually a natural gas stream obtained from natural gas or petroleum reservoirs.
  • the hydrocarbon feed stream may also be obtained from another source, also including a synthetic source such as a Fischer- Tropsch process.
  • a natural gas stream is a hydrocarbon
  • composition comprised substantially of methane.
  • the hydrocarbon feed stream comprises at least 50 mol% methane, more preferably at least 80 mol% methane .
  • Hydrocarbon compositions such as natural gas may also contain non-hydrocarbons such as H2O, N2, CO2, Hg, H2S and other sulphur compounds, and the like.
  • the natural gas may be pre-treated before cooling and any liquefying. This pre-treatment may comprise reduction and/or removal of undesired components such as CO2 and H 2 S or other steps such as early cooling, pre- pressurizing or the like. As these steps are well known to the person skilled in the art, their mechanisms are not further discussed here.
  • hydrocarbon feed stream may also include a composition prior to any treatment, such treatment including cleaning, dehydration and/or
  • scrubbing as well as any composition having been partly, substantially or wholly treated for the reduction and/or removal of one or more compounds or substances, including but not limited to sulphur, sulphur compounds, carbon dioxide, water, Hg, and one or more C2+ hydrocarbons.
  • natural gas may contain varying amounts of hydrocarbons heavier than methane such as in particular ethane, propane and butanes, and
  • hydrocarbons The composition varies depending upon the type and location of the gas.
  • the hydrocarbons heavier than methane are removed to various extents from the hydrocarbon feed stream prior to liquefaction for several reasons, such as having different freezing or liquefaction temperatures that may cause them to block parts of a methane
  • C2+ hydrocarbons can be separated from, or their content reduced in a hydrocarbon feed stream by a demethaniser, which will provide an overhead hydrocarbon stream which is methane-rich and a bottoms methane-lean stream comprising the C2+
  • the bottoms methane-lean stream can then be passed to further separators to provide Liquefied
  • the hydrocarbon stream so produced can be further cooled, preferably liquefied.
  • the cooling could be provided by a number of methods known in the art.
  • the hydrocarbon stream is passed against one or more refrigerant streams in one or more refrigerant circuits.
  • a refrigerant circuit can comprise one or more refrigerant compressors to compress an at least partly evaporated refrigerant stream to provide a compressed refrigerant stream.
  • the compressed refrigerant stream can then be cooled in a cooler, such as an air or water cooler, to provide the refrigerant stream.
  • refrigerant compressors can be driven by one or more gas and/or steam turbines and/or electric motors.
  • the cooling of the hydrocarbon stream can be carried out in one or more stages.
  • Initial cooling also called pre-cooling or auxiliary cooling, can be carried out using a pre-cooling refrigerant, such as a mixed
  • the pre-cooled hydrocarbon stream is preferably partially liquefied, such as at a temperature below O 0 C.
  • such pre-cooling heat exchangers could comprise a pre-cooling stage, with any subsequent cooling being carried out in one or more main heat exchangers to liquefy a fraction of the hydrocarbon stream in one or more main and/or sub-cooling cooling stages.
  • each cooling stage may comprise one to five heat exchangers.
  • the or a fraction of a hydrocarbon stream and/or the refrigerant may not pass through all, and/or all the same, heat exchangers of a cooling stage.
  • the hydrocarbon may be cooled and liquefied in a method comprising two or three cooling stages.
  • a pre-cooling stage is preferably intended to reduce the temperature of a hydrocarbon feed stream to below O 0 C, usually in the range -2O 0 C to -7O 0 C.
  • a main cooling stage is preferably separate from the pre-cooling stage. That is, the main cooling stage comprises one or more separate main heat exchangers.
  • a main cooling stage is preferably intended to reduce the temperature of a hydrocarbon stream, usually at least a fraction of a hydrocarbon stream cooled by a pre-cooling stage, to below -100 0 C.
  • Heat exchangers for use as the two or more pre- cooling or any main heat exchangers are well known in the art.
  • the pre-cooling heat exchangers are preferably shell and tube heat exchangers.
  • At least one of any of the main heat exchangers is preferably a spool-wound cryogenic heat exchanger known in the art.
  • a heat exchanger could comprise one or more cooling sections within its shell, and each cooling section could be considered as a cooling stage or as a separate 'heat exchanger' to the other cooling locations.
  • one or both of the pre-cooling refrigerant stream and any main refrigerant stream can be passed through one or more heat exchangers, preferably two or more of the pre-cooling and main heat exchangers described hereinabove, to provide cooled refrigerant streams .
  • the refrigerant is a mixed refrigerant in a mixed refrigerant circuit, such as the pre-cooling refrigerant circuit or any main refrigerant circuit, it may be formed from a mixture of two or more components selected from the group comprising: nitrogen, methane, ethane,
  • refrigerants may be used, in separate or overlapping refrigerant circuits or other cooling
  • the pre-cooling refrigerant circuit may comprise a mixed pre-cooling refrigerant.
  • the main refrigerant circuit may comprise a mixed main refrigerant.
  • a mixed refrigerant or a mixed refrigerant stream as referred to herein comprises at least 5 mol% of two different components. More preferably, the mixed refrigerant comprises two or more of the group comprising: nitrogen, methane, ethane, ethylene, propane, propylene, butanes and pentanes.
  • refrigerant can be:
  • the total composition comprises 100 mol%.
  • refrigerant can be:
  • the total composition comprises 100 mol%.
  • the pre-cooled hydrocarbon stream such as a pre-cooled natural gas stream can be further cooled to provide an at least partially,
  • the further cooling may be carried out in the main cooling stage.
  • the treated liquid hydrocarbon stream provided in the method and apparatus described herein can be stored in one or more storage tanks.
  • the fully liquefied hydrocarbon stream is preferably sub-cooled.
  • the further cooling e.g. in the main cooling stage or in a separate sub-cooling stage, may thus comprise sub-cooling of the liquefied
  • liquefied hydrocarbon stream can be expanded to provide the multi-phase hydrocarbon stream which can be further processed according to the method and apparatus described herein.
  • Figure 2 shows a second embodiment of an apparatus in which a pressurized hydrocarbon feed stream 85 is treated, cooled, at least partially liquefied and
  • the multi-phase hydrocarbon stream 145 may be provided by the steps of:
  • hydrocarbon stream expansion devices 120,140 to provide the multi-phase hydrocarbon stream 145 in the form of an expanded hydrocarbon stream.
  • the at least partially, preferably fully, liquefied hydrocarbon stream 115 may be provided by the steps of:
  • the high pressure fuel gas stream 107 may have one or both of a nitrogen content of lower than 15 mol% and a pressure of higher than 15 bara.
  • the high pressure fuel gas stream 107 may suitably be passed to one or more high pressure fuel gas consumers 300, such as gas turbines.
  • a supply stream separation device 80 may be provided to separate the hydrocarbon supply stream 105 into the continuing hydrocarbon stream 108 and the high pressure fuel gas stream 107.
  • the supply stream separation device 80 may suitably have an inlet 78 for the hydrocarbon supply stream 105, a first outlet 81 for the high
  • the at least partially, preferably fully, liquefying step may comprise:
  • the apparatus may comprise one or more cooling stages 110 to cool and at least partially, preferably fully, liquefy the continuing hydrocarbon stream 108 to provide the at least partially, preferably fully,
  • Said one or more cooling stages 110 may suitably have an inlet 109 for the continuing hydrocarbon stream 108 in fluid communication with the second outlet 82 of the supply stream separation device 80 and an outlet 112 for the at least partially, preferably fully, liquefied hydrocarbon stream 115 connected to an inlet 118 of the one or more hydrocarbon stream expansion devices 120,140.
  • the hydrocarbon feed stream 85 which can be a natural gas stream, is provided as a pressurised stream, usually at a pressure in the range of from 30 to 90 bara.
  • the hydrocarbon feed stream 85 may be passed to an acid gas removal unit 90.
  • the acid gas removal unit 90 lowers the content of acid gases such as carbon dioxide and hydrogen sulphide in the hydrocarbon feed stream 85 by known methods to provide a treated hydrocarbon stream 95.
  • the treated hydrocarbon stream 95 which will be depleted in acid gases, may then be passed to a Natural Gas Liquids (NGL) extraction unit 100, optionally via a dryer (not shown) .
  • NNL Natural Gas Liquids
  • the NGL extraction unit 100 At least a portion of any natural gas liquids such as propane, butanes and pentanes, together with heavier hydrocarbons, can be removed, for instance using one or more scrub columns or fractionation columns.
  • the NGL extraction unit 100 provides a hydrocarbon supply stream 105, which can be depleted in natural gas liquids.
  • Figure 2 shows the hydrocarbon supply stream 105 being passed to the inlet 78 of a supply stream
  • the high pressure fuel gas stream 107 can be drawn from hydrocarbon feed stream 85 and/or treated hydrocarbon stream 95 instead of the hydrocarbon supply stream 105.
  • the bleed point for the high pressure fuel gas stream 107 will be determined by the composition of the hydrocarbon mixture. For example, if the hydrocarbon mixture is naturally low in acid gasses, the high pressure fuel gas stream 107 can be drawn from the hydrocarbon feed stream 85 and the pressure be reduced in a device such as valve 106 provided in line 107, to match the high
  • the high pressure fuel gas stream may be drawn from the NGL extraction unit 100 at a lower pressure if the NGL extraction unit 100 is operated at a lower pressure.
  • the NGL extraction unit 100 is operated at a lower pressure.
  • the high pressure fuel gas stream 107 can then be passed to a high pressure fuel gas network, or as shown in Figure 2 directly to one or more high pressure fuel gas consumers 300, such as gas turbines.
  • the gas turbines may mechanically drive electric generators for power production, or more preferably mechanically drive
  • compressors such as those present in a refrigerant circuit.
  • the continuing hydrocarbon stream 108 from the second outlet 82 of the supply stream separation device 80 can then be passed to a cooling and liquefaction unit 110, where it is cooled and at least partially, preferably fully, liquefied.
  • the liquefaction unit 100 provides an at least partially, preferably fully, liquefied
  • hydrocarbon stream 115 at a first outlet 112.
  • Such liquefaction units are well known in the art, from instance from U.S. Patent No. 6,370,910.
  • the liquefaction unit 110 shown in Figure 2 comprises a first and a second cooling stage.
  • the first cooling stage comprises one or more pre-cooling heat exchangers 110a, which cool the continuing hydrocarbon stream 108 against a pre-cooling refrigerant in a pre-cooling refrigerant circuit (not shown) .
  • the one or more pre- cooling heat exchangers 110a provide a pre-cooled
  • hydrocarbon stream 113 hydrocarbon stream 113.
  • Pre-cooled hydrocarbon stream 113 can be passed to pre-cooled stream separation device 70, where it may optionally be split into a (continuing) pre-cooled hydrocarbon stream part 113b and a process stream to be employed as warming stream 355.
  • the second cooling stage comprises one or more main cooling heat exchangers 110b, which at least partially, preferably fully, liquefy the pre-cooled hydrocarbon stream 113, or at least the continuing part 113b thereof, against a main cooling refrigerant in a main cooling refrigerant circuit (not shown) .
  • the one or more main cooling heat exchangers 110b provide an at least partially, preferably fully,
  • the NGL extraction unit 100 may be located somewhere in the liquefaction unit 110 instead of upstream thereof such as depicted in Figure 2.
  • the supply stream separation device 80 may also be located in the liquefaction unit 110. Both the NGL extraction unit 100 as well as the supply stream separation device 80 would preferably be located upstream of where full condensation of the feed stream is
  • the at least partially, preferably fully, liquefied hydrocarbon stream 115 can be passed to an inlet 118 of one or more hydrocarbon stream expansion devices 120, 140, such as two or more expansion devices in series which sequentially reduce the pressure of the stream to provide the multi-phase hydrocarbon stream 145 at outlet 142.
  • the at least partially, preferably fully, liquefied hydrocarbon stream 115 can be passed to a first hydrocarbon stream expansion device 120, which may be a turbine, in which it is dynamically expanded to provide expanded hydrocarbon stream 125.
  • the energy released in the dynamic expansion of the at least partially, preferably fully, liquefied hydrocarbon stream 115 in the first expansion device 120 can be recovered, e.g. by mechanically driving an
  • electric generator 130 or another device such as a compressor (not shown) .
  • the expanded hydrocarbon stream 125 can then be passed to an expanded hydrocarbon stream splitting device 60 to provide expanded hydrocarbon slip stream 305 and (continuing) expanded hydrocarbon stream 125b.
  • (continuing) expanded hydrocarbon stream 125b can then be passed through the second expansion device 140, such as a Joule-Thomson valve, in which it is expanded to provide the multi-phase hydrocarbon stream 145.
  • the second expansion device 140 such as a Joule-Thomson valve
  • the cooled warming stream 365 may be injected into the (continuing) expanded
  • hydrocarbon stream 125b to be sent to the second
  • hydrocarbon stream expansion device 140 it may be beneficial to recombine the cooled warming stream 365 with the
  • expansion device 120 so that these streams can be jointly expanded.
  • the warming stream 355 is provided in the form of the slip stream withdrawn from pre-cooled hydrocarbon stream 113 by pre-cooled stream separation device 70.
  • the warming stream may also be obtained at different pressures from other sources, including but not limited to from the NGL — Z O Qo — extraction unit 100 or a fractionation train (not shown) that is typically installed to fractionate the NGL product obtained from the NGL extraction unit 100.
  • the pre-cooled hydrocarbon stream may not be split at all whereby the warming stream 355 consist of an entirely different process stream such as a refrigerant (slip) stream or an intermediate chilling fluid stream.
  • the multi-phase hydrocarbon stream 145 can be passed to a first inlet 148 of a first gas/liquid separator 150a, in which it is separated into vapour and liquid fractions, in a similar manner to the embodiment of
  • the first separator vapour stream 205 exits the first gas/liquid separator 150a overhead via a first outlet 151 therein.
  • the first separator bottoms stream 155a which is a liquid stream, exits via second outlet 152 at or near the bottom of the first gas/liquid
  • a combined stripping vapour stream 185a is passed to the first gas/liquid separator 150a a second inlet 149 which is situated gravitationally lower than the first inlet 148.
  • the second inlet 149 can be above second outlet 152.
  • the expanded hydrocarbon slip stream 305 is further expanded, e.g. using Joule Thomson valve 310, and the thus further expanded hydrocarbon slip stream 315 is passed through reflux condenser 320 to recondense some of the vapours at the top of the first gas/liquid separator 150a.
  • the reflux condenser 320 may be located at a level between the first inlet 148 and the first outlet 151, to provide reflux to enhance the separation of the lighter components of the multi-phase hydrocarbon stream.
  • an external reflux condenser may be used instead of such an internal condenser 320.
  • the further expanded hydrocarbon slip stream 315 is warmed in condenser 320 thereby providing a warmed hydrocarbon slip stream 325, which can be passed to the (expanded) first separator bottoms stream 155b.
  • first separator bottoms stream 155b carrying the warmed hydrocarbon from the warmed hydrocarbon slip stream 325 can be passed to the inlet 158 of the second gas/liquid separator 160 as a combined stream 155c.
  • this may comprise two zones with contact enhancing means (154a, 156a), e.g. formed of trays and/or packing, to enhance separation and nitrogen rejection.
  • a first zone of the two zones is situated between the first inlet 148 and the second inlet 149 in a similar manner to the embodiment of Figure 1.
  • a second zone of the two zones 156a is situated between the first outlet 151 for the first separator hydrocarbon vapour stream 205 and the first inlet 148 for the multi-phase hydrocarbon stream 145.
  • the second zone 156a should be below the condenser 320, or below an inlet means for reflux from an external condenser, in order to take advantage of the reflux provided by the condensation of the hydrocarbon vapour on the condenser 320.
  • the first separator hydrocarbon vapour stream 205 which exits the first outlet 151 can be passed to fuel gas heat exchanger 210 where it is warmed against warming stream 355, to provide the low pressure fuel gas stream 215 and cooled warming stream 365. If the warming stream is provided in the form of a process stream, a portion of the cold energy of the first separator hydrocarbon vapour stream 205 can thus be used to cool the process stream, allowing it to bypass the one or more main heat
  • the warming stream 355 may be also be a process stream in the form of a refrigerant stream, such as a pre-cooling and/or main cooling refrigerant stream.
  • a part of the cold energy of the first separator hydrocarbon vapour stream 205 can be returned to one or both of the cooling stages 110, by cooling the refrigerant.
  • This Example provides a comparison of the nitrogen contents of various streams produced from a natural gas hydrocarbon supply stream 105 according to the line-up of Figure 2, with three comparative examples calculated according to the embodiment of Figure 3 of
  • conduit 34a the high pressure fuel gas stream is provided by conduit 34a, from the overhead 25 of the upper part 1Ou of column 10' after heat exchange and compression combined with the overhead 42 of flash vessel 101 after heat exchange and compression. It is pointed out that conduit 33, arising solely form the heat exchange and compression of the overhead 25 of the upper part 1Ou of column 10' was unable to provide sufficient high pressure fuel gas, such that it was drawn instead from conduit 34a in this comparison. In the absence of a check valve in line 34, the conduits 33 and 34a would be in fluid communication.

Landscapes

  • Engineering & Computer Science (AREA)
  • Physics & Mathematics (AREA)
  • Mechanical Engineering (AREA)
  • Thermal Sciences (AREA)
  • General Engineering & Computer Science (AREA)
  • Chemical & Material Sciences (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • General Chemical & Material Sciences (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Combustion & Propulsion (AREA)
  • Separation By Low-Temperature Treatments (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)

Abstract

Un courant d'hydrocarbure à plusieurs phases (145) est traité pour fournir un courant d'hydrocarbure liquide traité (165), tel qu'un courant de gaz naturel liquéfié (GNL). Le courant d'hydrocarbure à plusieurs phases (145) est amené à passer dans un premier séparateur gaz/liquide (150), dans lequel il est séparé à une première pression pour fournir un premier courant de vapeur d'hydrocarbure de séparateur (205) et un premier courant de résidu de séparateur (155). Le premier courant de résidu de séparateur (155) est ensuite séparé dans un second séparateur gaz/liquide (160) à une seconde pression qui est inférieure à la première pression, pour fournir un second courant de vapeur d'hydrocarbure de séparateur (175) et un courant d'hydrocarbure liquide traité (165). Le second courant de vapeur d'hydrocarbure de séparateur (175) est comprimé dans un compresseur de courant de tête (180) pour fournir un courant de vapeur d'extraction au gaz (185) qui est amené à passer dans le premier séparateur gaz/liquide (150).
PCT/EP2010/060409 2009-07-21 2010-07-19 Procédé pour le traitement d'un courant d'hydrocarbure à plusieurs phases et appareil correspondant WO2011009832A2 (fr)

Priority Applications (8)

Application Number Priority Date Filing Date Title
CA2767369A CA2767369C (fr) 2009-07-21 2010-07-19 Procede pour le traitement d'un courant d'hydrocarbure a plusieurs phases et appareil correspondant
RU2012106137/06A RU2554736C2 (ru) 2009-07-21 2010-07-19 Способ очистки многофазного углеводородного потока и предназначенная для этого установка
BR112012001046-8A BR112012001046B1 (pt) 2009-07-21 2010-07-19 Método e aparelho para tratar uma corrente de hidrocarbonetomultifásica
EP10736661A EP2457046A2 (fr) 2009-07-21 2010-07-19 Procédé pour le traitement d'un courant d'hydrocarbure à plusieurs phases et appareil correspondant
CN201080032554XA CN102782430A (zh) 2009-07-21 2010-07-19 用于处理多相烃流的方法及其设备
JP2012521012A JP5730302B2 (ja) 2009-07-21 2010-07-19 多相炭化水素流の処理方法及びそのための装置
AU2010275307A AU2010275307B2 (en) 2009-07-21 2010-07-19 Method for treating a multi-phase hydrocarbon stream and an apparatus therefor
US13/384,783 US20120167617A1 (en) 2009-07-21 2010-07-19 Method for treating a multi-phase hydrocarbon stream and an apparatus therefor

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
EP09165993.8 2009-07-21
EP09165993 2009-07-21

Publications (2)

Publication Number Publication Date
WO2011009832A2 true WO2011009832A2 (fr) 2011-01-27
WO2011009832A3 WO2011009832A3 (fr) 2014-04-03

Family

ID=42102996

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/EP2010/060409 WO2011009832A2 (fr) 2009-07-21 2010-07-19 Procédé pour le traitement d'un courant d'hydrocarbure à plusieurs phases et appareil correspondant

Country Status (10)

Country Link
US (1) US20120167617A1 (fr)
EP (1) EP2457046A2 (fr)
JP (1) JP5730302B2 (fr)
KR (1) KR20120040700A (fr)
CN (1) CN102782430A (fr)
AU (1) AU2010275307B2 (fr)
BR (1) BR112012001046B1 (fr)
CA (1) CA2767369C (fr)
RU (1) RU2554736C2 (fr)
WO (1) WO2011009832A2 (fr)

Cited By (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
JP2013018841A (ja) * 2011-07-08 2013-01-31 Jgc Corp 液状炭化水素の水銀除去方法、及びその装置
US20130119676A1 (en) * 2011-11-15 2013-05-16 Shell Oil Company Method of processing feed streams containing hydrogen sulfide
EP2597406A1 (fr) 2011-11-25 2013-05-29 Shell Internationale Research Maatschappij B.V. Procédé et appareil pour éliminer l'azote d'une composition d'hydrocarbures cryogénique
WO2013087569A2 (fr) 2011-12-12 2013-06-20 Shell Internationale Research Maatschappij B.V. Procédé et appareil pour retirer l'azote d'une composition d'hydrocarbures cryogéniques
WO2013087570A2 (fr) 2011-12-12 2013-06-20 Shell Internationale Research Maatschappij B.V. Procédé et appareil pour retirer de l'azote d'une composition d'hydrocarbures cryogéniques
WO2013087571A2 (fr) 2011-12-12 2013-06-20 Shell Internationale Research Maatschappij B.V. Procédé et appareil pour retirer de l'azote d'une composition d'hydrocarbures cryogéniques
KR101324588B1 (ko) 2011-10-21 2013-11-01 삼성중공업 주식회사 가스처리시스템 및 가스처리방법
RU2685101C1 (ru) * 2018-09-03 2019-04-16 Андрей Владиславович Курочкин Установка низкотемпературной сепарации с дефлегмацией нтсд для выделения углеводородов c2+ из природного газа (варианты)

Families Citing this family (12)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
KR101371485B1 (ko) * 2012-12-07 2014-03-10 현대자동차주식회사 Lpi 차량용 리턴 연료 냉각 시스템
WO2014173598A2 (fr) * 2013-04-22 2014-10-30 Shell Internationale Research Maatschappij B.V. Procédé et appareil de production d'un flux d'hydrocarbure liquéfié
EP2796818A1 (fr) * 2013-04-22 2014-10-29 Shell Internationale Research Maatschappij B.V. Procédé et appareil de production d'un flux d'hydrocarbure liquéfié
EP2857782A1 (fr) 2013-10-04 2015-04-08 Shell International Research Maatschappij B.V. Échangeur de chaleur à bobine enroulée et procédé de refroidissement d'un flux de procédé
KR101634848B1 (ko) * 2013-10-31 2016-06-29 현대중공업 주식회사 액화가스 처리 시스템
US9487458B2 (en) 2014-02-28 2016-11-08 Fluor Corporation Configurations and methods for nitrogen rejection, LNG and NGL production from high nitrogen feed gases
KR20160095597A (ko) * 2015-02-03 2016-08-11 삼성중공업 주식회사 연료가스 공급시스템
WO2017162566A1 (fr) * 2016-03-21 2017-09-28 Shell Internationale Research Maatschappij B.V. Procédé et système de liquéfaction de flux d'alimentation de gaz naturel
CN106082379A (zh) * 2016-07-27 2016-11-09 青岛科技大学 汽提含酸含氨化工废水的方法
EP3510271B1 (fr) * 2016-09-07 2020-06-17 Wärtsilä Finland Oy Circuit de combustible permettant d'alimenter en combustible gazeux un moteur à piston à combustion interne et procédé d'actionnement d'un moteur à piston à combustion interne
AU2017346376B2 (en) 2016-10-18 2023-03-16 Conocophillips Company Internal tank disengaging system
US11221176B2 (en) * 2018-08-14 2022-01-11 Air Products And Chemicals, Inc. Natural gas liquefaction with integrated nitrogen removal

Citations (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6370910B1 (en) 1998-05-21 2002-04-16 Shell Oil Company Liquefying a stream enriched in methane
US20080066493A1 (en) 2004-07-12 2008-03-20 Cornelis Buijs Treating Liquefied Natural Gas

Family Cites Families (22)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CH561620A5 (fr) * 1972-12-11 1975-05-15 Sulzer Ag
US4225329A (en) * 1979-02-12 1980-09-30 Phillips Petroleum Company Natural gas liquefaction with nitrogen rejection stabilization
US4548629A (en) * 1983-10-11 1985-10-22 Exxon Production Research Co. Process for the liquefaction of natural gas
US4809154A (en) * 1986-07-10 1989-02-28 Air Products And Chemicals, Inc. Automated control system for a multicomponent refrigeration system
MY113525A (en) * 1995-10-05 2002-03-30 Bhp Petroleum Pty Ltd Liquefaction process
US5992175A (en) * 1997-12-08 1999-11-30 Ipsi Llc Enhanced NGL recovery processes
MY117066A (en) * 1998-10-22 2004-04-30 Exxon Production Research Co Process for removing a volatile component from natural gas
US6070429A (en) * 1999-03-30 2000-06-06 Phillips Petroleum Company Nitrogen rejection system for liquified natural gas
FR2822838B1 (fr) * 2001-03-29 2005-02-04 Inst Francais Du Petrole Procede de deshydratation et de fractionnement d'un gaz naturel basse pression
US6742358B2 (en) * 2001-06-08 2004-06-01 Elkcorp Natural gas liquefaction
US6740226B2 (en) * 2002-01-16 2004-05-25 Saudi Arabian Oil Company Process for increasing hydrogen partial pressure in hydroprocessing processes
US6672104B2 (en) * 2002-03-28 2004-01-06 Exxonmobil Upstream Research Company Reliquefaction of boil-off from liquefied natural gas
FR2841330B1 (fr) * 2002-06-21 2005-01-28 Inst Francais Du Petrole Liquefaction de gaz naturel avec recyclage de gaz naturel
EA008393B1 (ru) * 2002-08-15 2007-04-27 Флуор Корпорейшн Установка сжиженного природного газа низкого давления
RU2236891C2 (ru) * 2002-11-25 2004-09-27 Открытое акционерное общество "Научно-исследовательский и проектный институт по переработке газа" Способ очистки углеводородного газа
US6907752B2 (en) * 2003-07-07 2005-06-21 Howe-Baker Engineers, Ltd. Cryogenic liquid natural gas recovery process
US7442847B2 (en) * 2004-08-24 2008-10-28 Advanced Extraction Technologies, Inc. Removing diamondoid components from natural gas at reduced temperatures
KR20070111531A (ko) * 2005-02-17 2007-11-21 쉘 인터내셔날 리써취 마트샤피지 비.브이. 천연 가스 액화 설비 및 액화 방법
DE102007010032A1 (de) * 2007-03-01 2008-09-04 Linde Ag Verfahren zum Abtrennen von Stickstoff aus verflüssigtem Erdgas
US8381543B2 (en) * 2007-12-12 2013-02-26 Conocophillips Company System for enhanced fuel gas composition control in an LNG facility
AU2009243512A1 (en) * 2008-12-05 2010-06-24 Shell Internationale Research Maatschappij B.V. Method of cooling a hydrocarbon stream and an apparatus therefor
DE102009038458A1 (de) * 2009-08-21 2011-02-24 Linde Ag Verfahren zum Abtrennen von Stickstoff aus Erdgas

Patent Citations (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6370910B1 (en) 1998-05-21 2002-04-16 Shell Oil Company Liquefying a stream enriched in methane
US20080066493A1 (en) 2004-07-12 2008-03-20 Cornelis Buijs Treating Liquefied Natural Gas

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
See also references of EP2457046A2

Cited By (22)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
JP2013018841A (ja) * 2011-07-08 2013-01-31 Jgc Corp 液状炭化水素の水銀除去方法、及びその装置
KR101324588B1 (ko) 2011-10-21 2013-11-01 삼성중공업 주식회사 가스처리시스템 및 가스처리방법
US20130119676A1 (en) * 2011-11-15 2013-05-16 Shell Oil Company Method of processing feed streams containing hydrogen sulfide
EP2597406A1 (fr) 2011-11-25 2013-05-29 Shell Internationale Research Maatschappij B.V. Procédé et appareil pour éliminer l'azote d'une composition d'hydrocarbures cryogénique
WO2013076185A2 (fr) 2011-11-25 2013-05-30 Shell Internationale Research Maatschappij B.V. Procédé et appareil permettant d'éliminer de l'azote d'une composition d'hydrocarbure cryogénique
WO2013087569A3 (fr) * 2011-12-12 2014-05-01 Shell Internationale Research Maatschappij B.V. Procédé et appareil pour retirer l'azote d'une composition d'hydrocarbures cryogéniques
AU2012350742B2 (en) * 2011-12-12 2015-08-20 Shell Internationale Research Maatschappij B.V. Method and apparatus for removing nitrogen from a cryogenic hydrocarbon composition
WO2013087570A2 (fr) 2011-12-12 2013-06-20 Shell Internationale Research Maatschappij B.V. Procédé et appareil pour retirer de l'azote d'une composition d'hydrocarbures cryogéniques
WO2013087570A3 (fr) * 2011-12-12 2014-05-01 Shell Internationale Research Maatschappij B.V. Procédé et appareil pour retirer de l'azote d'une composition d'hydrocarbures cryogéniques
WO2013087571A3 (fr) * 2011-12-12 2014-05-01 Shell Internationale Research Maatschappij B.V. Procédé et appareil pour retirer de l'azote d'une composition d'hydrocarbures cryogéniques
WO2013087569A2 (fr) 2011-12-12 2013-06-20 Shell Internationale Research Maatschappij B.V. Procédé et appareil pour retirer l'azote d'une composition d'hydrocarbures cryogéniques
CN103988035A (zh) * 2011-12-12 2014-08-13 国际壳牌研究有限公司 用于从低温烃类组合物中去除氮气的方法和装置
CN103998882A (zh) * 2011-12-12 2014-08-20 国际壳牌研究有限公司 用于从低温烃类组合物中去除氮气的方法和装置
US20140345319A1 (en) * 2011-12-12 2014-11-27 Shell Internationale Research Maatschappij B.V. Method and apparatus for removing nitrogen from a cryogenic hydrocarbon composition
WO2013087571A2 (fr) 2011-12-12 2013-06-20 Shell Internationale Research Maatschappij B.V. Procédé et appareil pour retirer de l'azote d'une composition d'hydrocarbures cryogéniques
AU2012350743B2 (en) * 2011-12-12 2015-08-27 Shell Internationale Research Maatschappij B.V. Method and apparatus for removing nitrogen from a cryogenic hydrocarbon composition
AU2012354774B2 (en) * 2011-12-12 2015-09-10 Shell Internationale Research Maatschappij B. V. Method and apparatus for removing nitrogen from a cryogenic hydrocarbon composition
CN103998882B (zh) * 2011-12-12 2016-04-13 国际壳牌研究有限公司 用于从低温烃类组合物中去除氮气的方法和装置
RU2607198C2 (ru) * 2011-12-12 2017-01-10 Шелл Интернэшнл Рисерч Маатсхаппий Б.В. Способ и устройство для удаления азота из криогенной углеводородной композиции
RU2607708C2 (ru) * 2011-12-12 2017-01-10 Шелл Интернэшнл Рисерч Маатсхаппий Б.В. Способ и устройство для удаления азота из криогенной углеводородной композиции
RU2622212C2 (ru) * 2011-12-12 2017-06-13 Шелл Интернэшнл Рисерч Маатсхаппий Б.В. Способ и устройство для удаления азота из криогенной углеводородной композиции
RU2685101C1 (ru) * 2018-09-03 2019-04-16 Андрей Владиславович Курочкин Установка низкотемпературной сепарации с дефлегмацией нтсд для выделения углеводородов c2+ из природного газа (варианты)

Also Published As

Publication number Publication date
BR112012001046B1 (pt) 2021-02-23
EP2457046A2 (fr) 2012-05-30
CN102782430A (zh) 2012-11-14
JP2013503314A (ja) 2013-01-31
CA2767369C (fr) 2017-10-24
RU2012106137A (ru) 2013-08-27
CA2767369A1 (fr) 2011-01-27
AU2010275307B2 (en) 2013-12-19
RU2554736C2 (ru) 2015-06-27
AU2010275307A1 (en) 2012-01-19
WO2011009832A3 (fr) 2014-04-03
US20120167617A1 (en) 2012-07-05
JP5730302B2 (ja) 2015-06-10
KR20120040700A (ko) 2012-04-27
BR112012001046A2 (pt) 2020-07-28

Similar Documents

Publication Publication Date Title
CA2767369C (fr) Procede pour le traitement d'un courant d'hydrocarbure a plusieurs phases et appareil correspondant
KR101657410B1 (ko) 중간 원료 가스 분리를 이용하는 액화 천연 가스 제조시의 통합된 질소 제거
RU2607708C2 (ru) Способ и устройство для удаления азота из криогенной углеводородной композиции
US20100293996A1 (en) Method and apparatus for liquefying a hydrocarbon stream and floating vessel or offshore platform comprising the same
EA011919B1 (ru) Сжижение природного газа
JP2012514050A (ja) 炭化水素流から窒素を排除して燃料ガス流を提供する方法およびそのための装置
US20100175424A1 (en) Methods and apparatus for liquefaction of natural gas and products therefrom
KR20190023100A (ko) 천연 가스에 대한 2 개의 반-개방 냉매 사이클과 냉매 가스에 대한 폐쇄된 냉매 사이클을 포함하는 천연 가스의 액화 방법 및 천연 가스로부터 가용 액체를 회수하기 위한 방법
JP2015210078A (ja) 貢献する再注入回路を使用した液化天然ガスの生成における統合された窒素除去
AU2012350743B2 (en) Method and apparatus for removing nitrogen from a cryogenic hydrocarbon composition
JP2010504499A (ja) 炭化水素流の液化方法
RU2607198C2 (ru) Способ и устройство для удаления азота из криогенной углеводородной композиции
CN113865266A (zh) 液化系统
WO2010040735A2 (fr) Procédés de traitement d’un courant d’hydrocarbures et appareil associé
RU2423653C2 (ru) Способ для сжижения потока углеводородов и установка для его осуществления
WO2013076185A2 (fr) Procédé et appareil permettant d'éliminer de l'azote d'une composition d'hydrocarbure cryogénique
RU2720732C1 (ru) Способ и система охлаждения и разделения потока углеводородов
AU2009216745B2 (en) Method and apparatus for cooling and separating a hydrocarbon stream
WO2010055153A2 (fr) Procédé et dispositif pour liquéfier un flux d'hydrocarbure et bâtiment flottant ou plate-forme au large comprenant ceux-ci
US20200033054A1 (en) Additional liquid natural gas plant and method of operating thereof
AU2014201643A1 (en) Method for treating a multi-phase hydrocarbon stream and an apparatus therefor

Legal Events

Date Code Title Description
WWE Wipo information: entry into national phase

Ref document number: 201080032554.X

Country of ref document: CN

121 Ep: the epo has been informed by wipo that ep was designated in this application

Ref document number: 10736661

Country of ref document: EP

Kind code of ref document: A2

WWE Wipo information: entry into national phase

Ref document number: 2010275307

Country of ref document: AU

WWE Wipo information: entry into national phase

Ref document number: 2010736661

Country of ref document: EP

WWE Wipo information: entry into national phase

Ref document number: 2767369

Country of ref document: CA

ENP Entry into the national phase

Ref document number: 2010275307

Country of ref document: AU

Date of ref document: 20100719

Kind code of ref document: A

Ref document number: 20127001559

Country of ref document: KR

Kind code of ref document: A

WWE Wipo information: entry into national phase

Ref document number: 13384783

Country of ref document: US

WWE Wipo information: entry into national phase

Ref document number: 2012521012

Country of ref document: JP

WWE Wipo information: entry into national phase

Ref document number: 2012106137

Country of ref document: RU

REG Reference to national code

Ref country code: BR

Ref legal event code: B01A

Ref document number: 112012001046

Country of ref document: BR

ENP Entry into the national phase

Ref document number: 112012001046

Country of ref document: BR

Kind code of ref document: A2

Effective date: 20120116