WO1990000589A1 - Procede de liquefaction d'hydrocarbures gazeux - Google Patents

Procede de liquefaction d'hydrocarbures gazeux Download PDF

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Publication number
WO1990000589A1
WO1990000589A1 PCT/US1989/002916 US8902916W WO9000589A1 WO 1990000589 A1 WO1990000589 A1 WO 1990000589A1 US 8902916 W US8902916 W US 8902916W WO 9000589 A1 WO9000589 A1 WO 9000589A1
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WO
WIPO (PCT)
Prior art keywords
gas
lhg
selected storage
conditioner
pressure
Prior art date
Application number
PCT/US1989/002916
Other languages
English (en)
Inventor
Virgil Lee Brundige, Jr.
Original Assignee
Mobil Oil Corporation
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 Mobil Oil Corporation filed Critical Mobil Oil Corporation
Publication of WO1990000589A1 publication Critical patent/WO1990000589A1/fr
Priority to KR1019900700478A priority Critical patent/KR900701972A/ko

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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
    • 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
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C1/00—Pressure vessels, e.g. gas cylinder, gas tank, replaceable cartridge
    • F17C1/005—Storage of gas or gaseous mixture at high pressure and at high density condition, e.g. in the single state phase
    • 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
    • F25J1/0047—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 an "external" refrigerant stream in a closed vapor compression cycle
    • F25J1/0052—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 an "external" refrigerant stream in a closed vapor compression cycle by vaporising a liquid refrigerant 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
    • F25J1/00—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
    • F25J1/006—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures characterised by the refrigerant fluid used
    • F25J1/008—Hydrocarbons
    • F25J1/0087—Propane; Propylene
    • 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
    • F25J1/0203—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 using a single-component refrigerant [SCR] fluid in a closed vapor compression cycle
    • F25J1/0204—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 using a single-component refrigerant [SCR] fluid in a closed vapor compression cycle as a single flow SCR cycle
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • 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
    • F25J1/0244—Operation; Control and regulation; Instrumentation
    • F25J1/0254—Operation; Control and regulation; Instrumentation controlling particular process parameter, e.g. pressure, temperature
    • 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
    • F25J1/0244—Operation; Control and regulation; Instrumentation
    • F25J1/0254—Operation; Control and regulation; Instrumentation controlling particular process parameter, e.g. pressure, temperature
    • F25J1/0255—Operation; Control and regulation; Instrumentation controlling particular process parameter, e.g. pressure, temperature controlling the composition of the feed or liquefied gas, e.g. to achieve a particular heating value of 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
    • 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
    • F25J1/0275—Construction and layout of liquefaction equipments, e.g. valves, machines adapted for special use of the liquefaction unit, e.g. portable or transportable devices
    • F25J1/0277—Offshore use, e.g. during shipping
    • F25J1/0278—Unit being stationary, e.g. on floating barge or fixed platform
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J3/00—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification
    • F25J3/02—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream
    • F25J3/0204—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream characterised by the feed stream
    • F25J3/0209—Natural gas or substitute natural gas
    • F25J3/0214—Liquefied natural gas
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J3/00—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification
    • F25J3/02—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream
    • F25J3/0228—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream characterised by the separated product stream
    • F25J3/0233—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream characterised by the separated product stream separation of CnHm with 1 carbon atom or more
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J3/00—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification
    • F25J3/02—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream
    • F25J3/0228—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream characterised by the separated product stream
    • F25J3/0238—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream characterised by the separated product stream separation of CnHm with 2 carbon atoms or more
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J3/00—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification
    • F25J3/02—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream
    • F25J3/0228—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream characterised by the separated product stream
    • F25J3/0242—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream characterised by the separated product stream separation of CnHm with 3 carbon atoms or more
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2200/00—Processes or apparatus using separation by rectification
    • F25J2200/02—Processes or apparatus using separation by rectification in a single pressure main column system
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2200/00—Processes or apparatus using separation by rectification
    • F25J2200/70—Refluxing the column with a condensed part of the feed stream, i.e. fractionator top is stripped or self-rectified
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2205/00—Processes or apparatus using other separation and/or other processing means
    • F25J2205/30—Processes or apparatus using other separation and/or other processing means using a washing, e.g. "scrubbing" or bubble column for purification purposes
    • 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
    • F25J2215/02—Mixing or blending of fluids to yield a certain product
    • 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
    • F25J2290/00—Other details not covered by groups F25J2200/00 - F25J2280/00
    • F25J2290/62—Details of storing a fluid in a tank
    • 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
    • F25J2290/00—Other details not covered by groups F25J2200/00 - F25J2280/00
    • F25J2290/72—Processing device is used off-shore, e.g. on a platform or floating on a ship or barge

Definitions

  • the present invention relates to a process for liquefying hydrocarbon gas (e.g. , natural gas) to produce a liquefied heavy gas (LHG).
  • hydrocarbon gas e.g. , natural gas
  • LHG liquefied heavy gas
  • Vast reserves of hydrocarbon gas e.g., natural gas
  • hydrocarbon gas e.g., natural gas
  • the distances and terrain e.g., sea bottom
  • the gas from these areas must be processed at the remote site and then transported aboard specially-constructed, marine vessels to those market ports which have the proper facilities for off-loading the processed gas.
  • an LPG process only propane and possibly some butane are extracted from the natural gas feed stream and are cooled to a low temperature, e.g., from -70 to -40°C (-90 to -40°F) while maintaining the cooled components at a pressure of 110 Pa (16 psia) 5; in storage. Due to the higher temperature, an LPG process is cheaper to build and operate than an LNG process but the methane and ethane components of the natural gas are either sacrificed or must be handled separately, thereby making LPG less commercially attractive overall.
  • MLG medium condition liquefied gas
  • CNG compressed natural gas
  • MLG requires that any condensates in the natural gas feed stream be removed before liquefication and must be handled separately from the MLG.
  • specialized storage facilities are require ⁇ for transporting MLG which are substantially different from either LNG or LPG storage facilities with none of these storage facilities being interchangeable without substantial modification.
  • CNG merely involves compressing natural gas under extremely high pressures, e.g., 20700 kPa (3000 psi) at ambient temperatures. However, since the gas is not liquefied at these conditions, the volumetric efficiency of CNG does not make this process attractive for transporting large volumes of gas over long distances.
  • Still another process for transporting natural gas proposes to saturate the natural gas with a liquid organic additive whereby the gas-additive mixture will liquefy at a higher temperature than that of the gas alone; see U.S. Patent 4,010,622.
  • the additive is selected from hydrocarbons, alcohols, or esters having a chain length of C ⁇ to C-Q and which is liquid at ambient conditions. While this mixture does liquefy at higher temperatures thereby decreasing the refrigeration costs involved, the resulting liquefied ixture presents certain problems.
  • the solubility of methane decreases as the molecular weight of the additive increases so with heavier hydrocarbon additives, less methane can be liquefied.
  • the invention resides in a process for liquefying hydrocarbon gas comprising: adding an organic conditioner which is normally gaseous at ambient conditions to said hydrocarbon gas to change the composition of said hydrocarbon gas and form an altered gas having a composition which will be in a liquid phase at a selected storage tmeperature and pressure; and cooling said altered gas to at least said selected storage temperature and maintaining said altered gas at said selected storage pressure to form a liquefied heavy gas.
  • the present invention provides a process for liquefying substantially any hydrocarbon gas, e.g., natural gas, wherein all of the components of the gas are liquefied into a single, liquefied heavy gas (LHG) .
  • the present process will liquefy natural gases produced from different sources which may have substantially different original compositions (e.g . , lean gas, rich gas, gas with substantial amounts of condensates and gases produced with crude oil ) .
  • LHGs liquefied from feed gases having different compositions are always in the liquid phase at the same common, selected storage temperature and pressure regardless of their original composition. This permits LHGs formed from natural gases of different original compositions to be stored and shipped in the same, standardized storage containers .
  • any marine vessel equipped with such storage containers can be used to transport LHG regardless of its origin or original composition. Further, there is no need to have separate storage available on board the vessel for condensates and/or other individual components of the natural gas since all of these are liquefied in the LHG.
  • the present invention relates to a process for liquefying natural gas wherein an "organic conditioner" is added to the natural gas feed stream after it has been dehydrated to change the composition of the natural gas and thereby form an altered gas which has a composition that will be in the liquid phase at a selected storage temperature and pressure.
  • the altered gas stream is then cooled to at least the selected storage temperature , e.g . , -40°C, while the gas is maintained at the selected storage pressure, e.g . , 8380 kPa (1200 psia) , to thereby form LHG.
  • the selected storage temperature is selected so that it is well above cryogenic temperatures requi red for LNG (e.g . , -160°C or -260°F) .
  • LHG' s higher temperature significantly reduces the compressor horsepower needed for the LHG system when compared to that for a LNG system ( i. e. , up to a 90% reduction in compressor horsepower) .
  • the selected storage pressure can be low enough (e.g. , 8380 kPa or 1200 psia) that LHG can be stored and transported in storage containers made from relatively inexpensive materials (e.g . , commercially available steel storage cylinders) with no expensive alloys being required as is the case with LNG storage.
  • the organic conditioner used to alter the original composition of the natural gas is a low molecular weight organic compound or mixture therof (e.g.
  • each natural gas to be liquefied will depend upon the original composition of the particular natural gas to be liquefied and can easily be determined once the particulars are known. That is, it is preferred to "tailor" each natural gas to be liquefied by matching the organic conditioner to a predominant light hydrocarbon fraction present in the original natural gas. For example, if a natural gas has a predominant amount of ethane, then ethane is the preferred organic conditioner. This allows the liquid conditioner to be easily recovered from the LHG at its destination by known means, e.g. , fractionation, whereby the conditioner can be "back-hauled” to a production area in the otherwise empty LHG ships for reuse in the liquification process.
  • LHG offers many advantages over other known gas liquefication processes, some of these being: a. Substantially less horsepower (up to 90% less than LNG) is required to liquefy LHG. b. LPG is included in LHG while butane is normally limited in LNG. c. Condensates are included in LHG while they must be separated and handled separately with LNG. d. The overall thermal efficiency from well head to burner tip is about 95% with LHG compared to about 70% with LNG. e. Significantly less pretreatment is required for LHG, e.g. , the feed natural gas for LHG need only to be pretreated to pipeline conditions (e.g .
  • Figure 1 is a phase diagram of three hydrocarbon gases of different composition before and after the same organic conditioner has been added to each in accordance with the present invention to establish a common bubble point (i. e. , selected storage point) for all of the gases;
  • Figure 2 is a phase diagram of a single hydrocarbon gas wherein three different organic conditioners have been added thereto in accordance with the present invention to produce three gases having a common bubble point temperature and pressure;
  • Figure 3 is a phase diagram of another single hydrocarbon gas wherein three different organic conditioners that could be made from said gas have been added to another portion of the same gas in accordance with the present invention to produce three gases having a common bubble point temperature and pressure.
  • Figure 4 is a schematic view of a system used to determine the amount of an organic conditioner to be added to a particular feed gas to form LHG in accordance with the present invention
  • Figure 5 is a schematic view of a LHG liquefication system
  • Figure 6 is a schematic view of a LHG storage and transportation system
  • Figure 7 is a schematic vi ew of a LHG off-loading system.
  • Figure 8 is a graph depicting the results of experiments dete rmining the solubility of methane in hydrocarbon liquids having different molecular weights .
  • the chemical composition of common hydrocarbon gases can vary substantially depending on the source from which the gas originates. That is, there are lean gases (i.e., substantially methane), rich gases (i.e., methane plus substantial amounts of heavier hydrocarbon components) , and many gases of varying compositions in between.
  • lean gases i.e., substantially methane
  • rich gases i.e., methane plus substantial amounts of heavier hydrocarbon components
  • the following represents the compositions of three actual produced gases, i.e., X, Y and Z:
  • the liquid-gas phase behavior of any gas will differ depending on its particular composition. That is, a rich gas will a ⁇ have a higher cri tical point (e.g . , temperature above which the gas cannot exist as a liquid) than that of a leaner gas.
  • cri tical point e.g . , temperature above which the gas cannot exist as a liquid
  • the composition of a particular gas its phase behavior, e.g . , critical point, can also be changed.
  • the critical temperature the bubble point line is changed to allow the storage pressure to be selected in a cost effective manner for the storage containers required.
  • the phase behavior of particular gas is changed by adding an organic conditioner thereto before it is liquefied.
  • composition of a feed gas is changed so that its cri tical point is changed to a point where the altered gas is always in the liquid phase at a selected temperature and pressure, collectively called "selected storage point" .
  • the selected storage point is selected so that different hydrocarbon gases whi ch are conditioned in accordance with the present invention will be li quid at the same, common selected storage point .
  • This allows gases of different composition from different areas to be conditioned so that all are in a liquid phase at the same temperature and pressure the reby facilitating transport and/or storage of the liquefied gases in standa rdi zed vessels.
  • Figure 1 is a phase diagram for the three hydrocarbon gases
  • Curve X represents the phase behavior of an actual produced , lean gas X having a "critical point" "C" of approximately -81°C (- 114°F) at 4758 kPa (690 psia) ;
  • Curve Y represents an actual produced gas-condensate Y having a critical point "C” of -7°C (-20°F) at 20000 kPa (2900 psia) ; and
  • Curve Z represents a rich gas Z having a critical point of -24°C (-12°F) at 10480 kPa (1520 psia) .
  • a selected storage point "S" i. e. , a common temperature and pressure at which each of gases X, Y, and Z will be in the liquid phase
  • S a selected storage point
  • An organic conditioner i . e. , commercial grade propane
  • LHG liquef ied heavy gases
  • the solubility of methane in the LHG is of prime importance to the overall efficiency of LHG transportation since the main objective is to maximize the amount of feed gas that will be liquefied into a LHG while minimizing the liquefication operation.
  • the "organic conditioner" used in the present invention is selected from the lightest hydrocarbons (other than methane) normally found in the natural gas (i. e. , principally ethane and propane with limited quantities of butane and heavier components such as condensates and pentane-plus) . These light hydrocarbons are normally gaseous at ambient conditions.
  • Figure 8 illustrates graphically the results of experiments to test the solubility of methane at 2760 kPa (400 psia) and at 6200 kPa (900 psia) in ethane, propane, butane, and heptane, respectively.
  • Heavier hydrocarbons i. e. , pentanes and heavier
  • they while providing some lowering of the storage pressure of the LHG should be limited in the present organic conditioner in that they not only decrease the solubility of methane in the LHG but they also become insoluble and form solids in particular LHGs under certain conditions of concentration, pressure, and temperatures.
  • the "organic conditioner” changes the original composition of a feed gas to an altered gas which will be in the liquid phase at a selected storage point S.
  • the conditioner is preferably derived directly from the normally gaseous components of produced natural gases , themselves . That is, a portion of the natural gas production in an area can be processed to recover an organic conditioner (e.g. , ethane, propane, butane and C0 2 ) therefrom which, in turn, is then used to form LHG from another portion of the same production.
  • an organic conditioner e.g. , ethane, propane, butane and C0 2
  • the conditioner can originate from other sources, e.g . , back-hauled from other sites to the remote site.
  • the organic condi tioner can be selected from different gaseous light hydrocarbons or mixtu res the reof .
  • Figure 2 shows the effect of adding three different , light hydrocarbon or CO2 organic conditioners to separate samples of the same feed gas, (gas Z of Figure 1 ) to form three gases having different compositions (Z 3 , Z 4 , Z5) , all of which will be in the liquid phase at a predetermined , common selected storage point S (i. e. , -40°C, 1165 psia [8033 kPa] in Figure 2) .
  • Z are commercial grade propane, C0 2 , and commercial grade butane, respectively.
  • These conditioners are added in amounts of 9000, 3600, and 2800 barrels (1440 , 576 and 448 -m 3 respectively) per one hundred million standard cubic feet ( 2.8 x 10 ) of feed gas, respectively, to produce the different gases, Z-r , Z , t Zr, all of which have the same, common storage point S at which each gas is in a liquid phase.
  • Figure 3 plots the phase diagram of further diffe rent gases , Y-, (also plotted in Figure 1) , Y 2 and Y, , formed by adding three different organic condi tioners to feed gas Y wherein the conditioners themselves are deri ved from the feed gas Y. That is , a portion of feed gas Y is processed to extract a component (s) thereof which, in turn, is then added to another portion of feed gas Y to form LHG.
  • the respective conditioners for gases Y, , Y 2 , Y, in Figure 3 are butane; a 40-60 mixture of isobutane/normal butane; and natural gas liquids (a mixture of 44.4 Mol % ethane; 39.4 Mol % propane 6.7 Mol % isobutane; and 9.5 Mol % normal butane) .
  • a particular conditioner for any gi ven feed gas For example, how the LHG is to be processed at its market destination should be considered in selecting the organic conditioner for a particular feed gas. That is, if the LHG is to undergo fractionation at its destination, the LHG should be made up so that a minimum of organic conditioner will remain in the methane gas upon separation to prevent any substantial loss of the conditioner. To do this, the LHG should be "tailored" by matching the organic conditioner to the dominant hydrocarbon component naturally found in the particular feed gas being liquefied. For example, gas X (see TABLE 1) has very little pr ⁇ ane therein.
  • propane as the conditioner for gas X would result in an unavoidable loss of propane during fractionation of the LHG conditioned with propane.
  • ethane would be the preferred organic conditioner for gas X.
  • gas Z has nearly equal quantities of ethane and propane, thus either ethane, propane, or mixtures thereof would be a preferred conditioner.
  • Gas Y has approximately 2.5 times as much ethane as propane and both are insufficient quantities whereby the conditioner should contain more ethane than propane.
  • the liquid conditioner can be easily recovered from the LHG and then back-hauled in the LHG transport ships to the production area for reuse in liquefying additional LHG.
  • the selected storage point S for LHG formed in accordance with the present invention is selected such that the storage temperature, preferably -100°C to -7°C, (-150°F to 20 °F) , is well above cryogenic temperatures and the pressure, preferably 3450 to 9650 kPa (300 to 1400 psia), is low enough so that the LHG can easily be stored and transported using only conventional materials such as commercially-available steel cylinders.
  • This allows a marine vessel which is equipped with standardized storage facilities that are capable of maintaining LHG at the common selected storage point S during transit to be used for transporting LHG regardless of the original composition or source of the LHG.
  • a storage pressure and temperature is selected for the LHG, certain other constraints may be placed on the organic conditioner.
  • the conditioner For normal storage of the conditioner, its composition should be such that it has a vapor pressure above atmospheri c pressure at the storage temperature in order for the conditioner to be back-hauled efficiently to the production area in the same ships that are used to haul the LHG from the production area.
  • FIG. 3 illustrates a simple apparatus 10 that can be used to physically make the same determination.
  • Feed gas e.g . , produced natural gas Z
  • organic conditioner e.g. , pr ⁇ ane
  • the mixture is passed through heat exchanger 13 where it is cooled to the selected storage temperature (e.g. , -40°C) .
  • the cooled mixture is then passed into separator 14 whe rein the pressure is maintained at the selected storage pressure, e.g.
  • FIG. 5 illustrates a system for forming LHG from a feed gas at a producing site.
  • the feed gas ordinary produced natural gas or compressed casing head gas from oil wells
  • the selected storage pressure e. g. , 1200 psia (8270 kPa) through feed line 20.
  • the feed gas passes through filter- separator 21 to remove ent rained solids and the like and through a glycol dehydration unit 22 to produce a dry gas of about -50°F (-46°C) water dew point .
  • any entrained liquids e.g.
  • condensates can be removed by standard separation techniques but with the present invention, it is preferred to leave the condensates in the gas so there will be no need to handle these separately.
  • acid-forming gases e.g. , C0 2 , H 2 S, etc.
  • C0 2 , H 2 S, etc. may be removed by known techniques if they are present in such quantities to present corrosion problems during storage. Otherwise, it is not necessary to remove these components .
  • the dehydrated gas stream is next passed through a refrigeration unit 23 (shown as a three-stage system) to reduce the temperature of the pressurized feed gas to the selected storage temperature (e.g. , -40°C) .
  • a refrigeration unit 23 shown as a three-stage system
  • an inexpensive refrigerant e.g. , propane
  • propane can be used in unit 23 and may be the same material which is used as the organic conditioner.
  • the organic conditioner e.g . , propane, flows through line 24 and is mixed with the feed gas within the refrige ration uni t 23 to form LHG whi ch, in turn, can be temporarily stored in tankage
  • the organic conditioner and/or the refrigerant can be stored aboard vessel 26, if applicable, and the refrigerant compressors 27 can be operated by power (e. g. , steam) from vessel 26 and can be cooled by circulating seawater (not shown) .
  • power e. g. , steam
  • FIG. 6 shows further details of forming and loading LHG into storage containers 30 aboard marine vessel 26.
  • Feed gas is passed under pressure, e. g . , 1200 psia (8270 kPa) from feed line 31 through refrigeration unit 23a to cool the gas stream to the selected storage temperature, e. g . , -40°C.
  • the pressurized, cooled gas is then passed through line 32 to fill all of the containers 30 with feed gas at the selected storage temperature and pressure.
  • organic conditioner e.g. , pr ⁇ ane
  • the LHG is passed into the bottom of each cylinder 30 through line 35 to displace the feed gas out of the top of cylinders and back through refrigeration unit 23a via line 36. This is continued until all of cylinders 30 are filled with LHG.
  • Figu re 7 discloses a system for off-loading LHG once vessel 26 reaches a market port. LHG is in the liquid phase and should be displaced with a gas or other working fizid in order to maintain the pressure of the LHG at the selected storage pressure or the temperature will drop substantially, e.g. , from -40°C to as low as -62°C.
  • the LHG is displaced by a product gas, e. g . , natural gas, which is compressed to the selected storage pressu re.
  • the product gas flows into tops of containers 30 ( Figure 5) the reby forcing the LHG out of the bottom thereof .
  • the LHG flows from vessel 26 ( Figure 6) through line 40 via expansion valve 41 to a standard fractionator 42 (e.g. , de-ethanizer column with reboiler 43) .
  • Expansion of the LHG through valve 41 decreases the temperature of the LHG, e.g. , from -40°C to -68°C while reducing the pressure, e.g . , from 1200 psia (8270 kPa) to 450 psia (3100 kPa) which are typical operating conditions of the fractionator 42.
  • the product gas exits the top of fractionator 42 and flows through line 44 to a pipeline or other use.
  • the heavier hydrocarbon products (ethane plus) from the LHG flow from the bottom of fractionator 42 and through line 45 for use or further processing .
  • a portion of the products in line 45 can be diverted through line 46 and heat exchanged at 47 with the produc gas in line 44 to cool and condense the products which are then returned to vessel 26 to be "back-hauled" for use as organic conditioner in future LHG processes, especially in those instances where there is insufficient organic conditioner available at the production site.

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

Abstract

Dans un procédé de liquéfaction d'un gaz naturel, un agent de conditionnement organique, par exemple un hydrocarbure gazeux, lequel est gazeux dans des conditions ambiantes, est ajouté au gaz naturel pour déplacer le point de formation de bulles du gaz naturel vers une pression et une température de stockage sélectionnées auquelles le gaz est en phase liquide.
PCT/US1989/002916 1988-07-11 1989-06-30 Procede de liquefaction d'hydrocarbures gazeux WO1990000589A1 (fr)

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* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO1998053032A1 (fr) * 1997-05-16 1998-11-26 Jl Energy Transportation Inc. Procede et produit de stockage du gaz
EP1019560A1 (fr) * 1997-06-20 2000-07-19 Exxon Mobil Upstream Research Company Systeme ameliore pour le traitement, l'entreposage et le transport de gaz naturel liquefie
EP1021675A2 (fr) * 1997-06-20 2000-07-26 Exxon Mobil Upstream Research Company Systemes pour la distribution par terre par vehicules de gaz naturel liquefie
EP1040305A1 (fr) * 1997-12-19 2000-10-04 Exxonmobil Upstream Research Company Elements de processus, reservoirs et conduits servant a contenir et a transporter des fluides a des temperatures cryogeniques
US6460721B2 (en) 1999-03-23 2002-10-08 Exxonmobil Upstream Research Company Systems and methods for producing and storing pressurized liquefied natural gas
US6539747B2 (en) 2001-01-31 2003-04-01 Exxonmobil Upstream Research Company Process of manufacturing pressurized liquid natural gas containing heavy hydrocarbons
US6672104B2 (en) 2002-03-28 2004-01-06 Exxonmobil Upstream Research Company Reliquefaction of boil-off from liquefied natural gas
US7147124B2 (en) 2002-03-27 2006-12-12 Exxon Mobil Upstream Research Company Containers and methods for containing pressurized fluids using reinforced fibers and methods for making such containers
WO2007032842A3 (fr) * 2005-09-12 2007-05-31 Chevron Usa Inc Système utilisant un conduit flexible à caténaire permettant de transférer un fluide cryogénique
US7644676B2 (en) 2008-02-11 2010-01-12 Daewoo Shipbuilding & Marine Engineering Co., Ltd. Storage tank containing liquefied natural gas with butane
WO2011073931A1 (fr) * 2009-12-18 2011-06-23 Total S.A. Procede de production de gaz naturel liquefie ayant un pouvoir calorifique superieur ajuste
US8156758B2 (en) 2004-09-14 2012-04-17 Exxonmobil Upstream Research Company Method of extracting ethane from liquefied natural gas
US20120180502A1 (en) * 2010-10-12 2012-07-19 Seaone Maritime Corp. Methods for storage and transportation of natural gas in liquid solvents
US8286678B2 (en) 2010-08-13 2012-10-16 Chevron U.S.A. Inc. Process, apparatus and vessel for transferring fluids between two structures
US8607830B2 (en) 2007-03-02 2013-12-17 Enersea Transport Llc Apparatus and method for flowing compressed fluids into and out of containment
US8820096B2 (en) 2007-02-12 2014-09-02 Daewoo Shipbuilding & Marine Engineering Co., Ltd. LNG tank and operation of the same
US9086188B2 (en) 2008-04-10 2015-07-21 Daewoo Shipbuilding & Marine Engineering Co., Ltd. Method and system for reducing heating value of natural gas
CN105647606A (zh) * 2016-03-31 2016-06-08 四川九鼎智远知识产权运营有限公司 一种天然气气化稳定剂

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WO1998053032A1 (fr) * 1997-05-16 1998-11-26 Jl Energy Transportation Inc. Procede et produit de stockage du gaz
EP1019560A4 (fr) * 1997-06-20 2006-03-22 Exxonmobil Upstream Res Co Systeme ameliore pour le traitement, l'entreposage et le transport de gaz naturel liquefie
EP1019560A1 (fr) * 1997-06-20 2000-07-19 Exxon Mobil Upstream Research Company Systeme ameliore pour le traitement, l'entreposage et le transport de gaz naturel liquefie
EP1021675A2 (fr) * 1997-06-20 2000-07-26 Exxon Mobil Upstream Research Company Systemes pour la distribution par terre par vehicules de gaz naturel liquefie
EP1021675A4 (fr) * 1997-06-20 2005-08-17 Exxonmobil Upstream Res Co Systemes pour la distribution par terre par vehicules de gaz naturel liquefie
EP1040305A1 (fr) * 1997-12-19 2000-10-04 Exxonmobil Upstream Research Company Elements de processus, reservoirs et conduits servant a contenir et a transporter des fluides a des temperatures cryogeniques
EP1040305A4 (fr) * 1997-12-19 2005-05-18 Exxonmobil Upstream Res Co Elements de processus, reservoirs et conduits servant a contenir et a transporter des fluides a des temperatures cryogeniques
US6460721B2 (en) 1999-03-23 2002-10-08 Exxonmobil Upstream Research Company Systems and methods for producing and storing pressurized liquefied natural gas
US6539747B2 (en) 2001-01-31 2003-04-01 Exxonmobil Upstream Research Company Process of manufacturing pressurized liquid natural gas containing heavy hydrocarbons
US7147124B2 (en) 2002-03-27 2006-12-12 Exxon Mobil Upstream Research Company Containers and methods for containing pressurized fluids using reinforced fibers and methods for making such containers
US6672104B2 (en) 2002-03-28 2004-01-06 Exxonmobil Upstream Research Company Reliquefaction of boil-off from liquefied natural gas
US8156758B2 (en) 2004-09-14 2012-04-17 Exxonmobil Upstream Research Company Method of extracting ethane from liquefied natural gas
WO2007032842A3 (fr) * 2005-09-12 2007-05-31 Chevron Usa Inc Système utilisant un conduit flexible à caténaire permettant de transférer un fluide cryogénique
US7543613B2 (en) 2005-09-12 2009-06-09 Chevron U.S.A. Inc. System using a catenary flexible conduit for transferring a cryogenic fluid
US10352499B2 (en) 2007-02-12 2019-07-16 Daewoo Shipbuilding & Marine Engineering Co., Ltd. LNG tank and operation of the same
US11168837B2 (en) 2007-02-12 2021-11-09 Daewoo Shipbuilding & Marine Engineering Co., Ltd. LNG tank and operation of the same
US10508769B2 (en) 2007-02-12 2019-12-17 Daewoo Shipbuilding & Marine Engineering Co., Ltd. LNG tank and operation of the same
US8820096B2 (en) 2007-02-12 2014-09-02 Daewoo Shipbuilding & Marine Engineering Co., Ltd. LNG tank and operation of the same
US8943841B2 (en) 2007-02-12 2015-02-03 Daewoo Shipbuilding & Marine Engineering Co., Ltd. LNG tank ship having LNG circulating device
US8607830B2 (en) 2007-03-02 2013-12-17 Enersea Transport Llc Apparatus and method for flowing compressed fluids into and out of containment
US7841288B2 (en) 2008-02-11 2010-11-30 Daewoo Shipbuilding & Marine Engineering Co., Ltd. Storage tank containing liquefied natural gas with butane
US7644676B2 (en) 2008-02-11 2010-01-12 Daewoo Shipbuilding & Marine Engineering Co., Ltd. Storage tank containing liquefied natural gas with butane
US9086188B2 (en) 2008-04-10 2015-07-21 Daewoo Shipbuilding & Marine Engineering Co., Ltd. Method and system for reducing heating value of natural gas
FR2954345A1 (fr) * 2009-12-18 2011-06-24 Total Sa Procede de production de gaz naturel liquefie ayant un pouvoir calorifique superieur ajuste
WO2011073931A1 (fr) * 2009-12-18 2011-06-23 Total S.A. Procede de production de gaz naturel liquefie ayant un pouvoir calorifique superieur ajuste
US8286678B2 (en) 2010-08-13 2012-10-16 Chevron U.S.A. Inc. Process, apparatus and vessel for transferring fluids between two structures
US9182080B2 (en) * 2010-10-12 2015-11-10 Seaone Holdings, Llc Methods for storage and transportation of natural gas in liquid solvents
RU2589591C2 (ru) * 2010-10-12 2016-07-10 СИУАН ХОЛДИНГС, ЭлЭлСи Способы хранения и транспортировки природного газа в жидких растворителях
US20120180502A1 (en) * 2010-10-12 2012-07-19 Seaone Maritime Corp. Methods for storage and transportation of natural gas in liquid solvents
US10801672B2 (en) 2010-10-12 2020-10-13 Seaone Holdings, Llc Methods for storage and transportation of natural gas in liquid solvents
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CN105647606B (zh) * 2016-03-31 2019-06-18 大庆市中瑞燃气有限公司 一种天然气气化稳定剂

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