US20100132405A1 - Method and system for producing LNG - Google Patents

Method and system for producing LNG Download PDF

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Publication number
US20100132405A1
US20100132405A1 US12/665,329 US66532908A US2010132405A1 US 20100132405 A1 US20100132405 A1 US 20100132405A1 US 66532908 A US66532908 A US 66532908A US 2010132405 A1 US2010132405 A1 US 2010132405A1
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gas
cooling
fractionation column
heat exchanger
hydrocarbons
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Inge Sverre Lund Nilsen
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Aragon AS
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Kanfa Aragon AS
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Assigned to KANFA ARAGON AS reassignment KANFA ARAGON AS ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: NILSEN, INGE SVERRE LUND
Publication of US20100132405A1 publication Critical patent/US20100132405A1/en
Assigned to ARAGON AS reassignment ARAGON AS CHANGE OF NAME (SEE DOCUMENT FOR DETAILS). Assignors: KANFA ARAGON AS
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    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
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    • F25J1/0243—Start-up or control of the process; Details of the apparatus used; Details of the refrigerant compression system used
    • F25J1/0279—Compression of refrigerant or internal recycle fluid, e.g. kind of compressor, accumulator, suction drum etc.
    • F25J1/0285—Combination of different types of drivers mechanically coupled to the same refrigerant compressor, possibly split on multiple compressor casings
    • F25J1/0288—Combination of different types of drivers mechanically coupled to the same refrigerant compressor, possibly split on multiple compressor casings using work extraction by mechanical coupling of compression and expansion of the refrigerant, so-called companders
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    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D3/00—Distillation or related exchange processes in which liquids are contacted with gaseous media, e.g. stripping
    • B01D3/14—Fractional distillation or use of a fractionation or rectification column
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10L—FUELS NOT OTHERWISE PROVIDED FOR; NATURAL GAS; SYNTHETIC NATURAL GAS OBTAINED BY PROCESSES NOT COVERED BY SUBCLASSES C10G, C10K; LIQUEFIED PETROLEUM GAS; ADDING MATERIALS TO FUELS OR FIRES TO REDUCE SMOKE OR UNDESIRABLE DEPOSITS OR TO FACILITATE SOOT REMOVAL; FIRELIGHTERS
    • C10L3/00—Gaseous fuels; Natural gas; Synthetic natural gas obtained by processes not covered by subclass C10G, C10K; Liquefied petroleum gas
    • C10L3/06—Natural gas; Synthetic natural gas obtained by processes not covered by C10G, C10K3/02 or C10K3/04
    • C10L3/08—Production of synthetic natural gas
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    • 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
    • F25J1/0235—Heat exchange integration
    • F25J1/0237—Heat exchange integration integrating refrigeration provided for liquefaction and purification/treatment of the gas to be liquefied, e.g. heavy hydrocarbon removal from natural gas
    • F25J1/0238—Purification or treatment step is integrated within one refrigeration cycle only, i.e. the same or single refrigeration cycle provides feed gas cooling (if present) and overhead gas cooling
    • 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
    • F25J1/0235—Heat exchange integration
    • F25J1/0237—Heat exchange integration integrating refrigeration provided for liquefaction and purification/treatment of the gas to be liquefied, e.g. heavy hydrocarbon removal from natural gas
    • F25J1/0239—Purification or treatment step being integrated between two refrigeration cycles of a refrigeration cascade, i.e. first cycle providing feed gas cooling and second cycle providing overhead gas cooling
    • F25J1/0241—Purification or treatment step being integrated between two refrigeration cycles of a refrigeration cascade, i.e. first cycle providing feed gas cooling and second cycle providing overhead gas cooling wherein the overhead cooling comprises providing reflux for a fractionation step
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • 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
    • 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
    • F25J1/0279—Compression of refrigerant or internal recycle fluid, e.g. kind of compressor, accumulator, suction drum etc.
    • F25J1/0294—Multiple compressor casings/strings in parallel, e.g. split arrangement
    • 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
    • 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
    • F25J2220/00—Processes or apparatus involving steps for the removal of impurities
    • F25J2220/60—Separating impurities from natural gas, e.g. mercury, cyclic hydrocarbons
    • F25J2220/64—Separating heavy hydrocarbons, e.g. NGL, LPG, C4+ hydrocarbons or heavy condensates in general
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2270/00—Refrigeration techniques used
    • F25J2270/14—External refrigeration with work-producing gas expansion loop
    • F25J2270/16—External refrigeration with work-producing gas expansion loop with mutliple gas expansion loops of the same refrigerant
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2270/00—Refrigeration techniques used
    • F25J2270/90—External refrigeration, e.g. conventional closed-loop mechanical refrigeration unit using Freon or NH3, unspecified external refrigeration

Definitions

  • the present invention relates to a method for optimal production of LNG on a fixed or floating offshore installation, as can be seen in the preamble of the independent claim 1 .
  • the invention also relates to a system for implementing the method comprising a fractionation column for feeding feed gas, a heat exchanger system for cooling down and partially condensing the overhead gas stream from the fractionation column, a separator for separation of the two-phase stream from the heat exchanger system, a device for return of liquid from the separator to the fractionation column and feeding this liquid to the upper part of the column as reflux, and a device for routing the gas from the separator back to the heat exchanger system for further cooling and liquefaction to LNG.
  • the invention aims to use a closed gas expansion process to liquefy the natural gas, and in that the gas is first fed through a fractionation column where the gas is cooled and separated into an overhead fraction with reduced content of pentane (C5) and heavier components, and a bottom fraction enriched with the heavier hydrocarbons, furthermore, in that the fractionation column reflux is generated as an integrated part of the system for liquefaction in that the overhead gas is partially condensed.
  • the invention comprises a method and a system for liquefaction of natural gas or other hydrocarbon gas from a gas field or from a gas/oil field, where it is appropriate to liquefy the gas to facilitate transportation of the gas from the source to the market. This is particularly relevant for offshore oil/gas fields.
  • natural gas means a mixture of hydrocarbons where an essential part consists of methane. Natural gas is normally liquefied by considerably cooling down the gas such that it condenses and becomes a liquid. With LPG is meant liquid petroleum gas that encompasses propane and butanes (C4, C4 components).
  • the aim of the invention is to render liquefaction of gas energy efficient at the same time as the process is kept simple so that the equipment can be used offshore, and then especially on floating installations.
  • By-production of condensate during the liquefaction is minimised and the efficiency is maximised (the need for fuel gas is minimised).
  • the system according to the invention is characterised in that the cooling system which is used for cooling, condensing and liquefaction of the gas in the heat exchanger system comprises an open or closed gas expansion process with at least one gas expansion step.
  • the system is preferably designed and configured to separate the feed gas so that the overhead gas stream of the system will be enriched with the majority of the butane (C4) and hydrocarbons with a lower normal boiling point than butane, and the bottom product of the fractionation column will be enriched with most of C6 and components with a normal boiling point higher than C6.
  • Liquefaction of natural gas can be carried out with the use of a gas expansion process, where a cooling medium goes through a processing circuit based on compression, cooling, expansion and thereafter heat exchange with the fluid that is to be cooled down.
  • a gas expansion process where a cooling medium goes through a processing circuit based on compression, cooling, expansion and thereafter heat exchange with the fluid that is to be cooled down.
  • a compressed cooling medium in gas phase normally nitrogen or methane
  • the gas expansion generates very cold gas, or a mixture of gas and liquid, which is then used for liquefaction of natural gas and to pre-cool the compressed cooling medium gas.
  • the gas expansion processes are relatively simple and therefore very well suited to offshore installation. However, the processes have a somewhat lower efficiency than the more advanced processes, such as, for example, mixed refrigerant cycle processes, and thus require much compression equipment and much energy.
  • the gas In order to produce LNG it is normally required that the gas has a relatively high content of methane. However, most of the feed gases will also contain some heavier hydrocarbons such as ethane, propane, butane, pentane, etc. Some requirements with respect to the content of heavier hydrocarbons in the liquid gas are normally present:
  • the specific energy content per cubic meter of liquefied gas must normally not exceed given sales specifications.
  • the simplest way to limit the content of heavier hydrocarbons in the liquid gas is to partially condense the gas and then separate the condensed liquid from the gas, which is further cooled for liquefaction.
  • the separation is normally carried out as an integrated part of the cool down process, typically at a temperature between 0° C. and ⁇ 60° C. Separated condensate can be heated up again as a part of the cooling process to utilise the refrigeration potential.
  • stabilised condensate will, in the main, consist of C6+ with a relatively low content of pentane and lighter components. Hydrocarbons lighter than C6 can generally not be stored or transported safely without being cooled down or being under pressure. Some separated hydrocarbons or condensate can be used as fuel, but beyond that it is desirable to retain these components in the LNG product. Due to smaller LNG volumes and the possibility for later blending into large LNG volumes, it can be appropriate offshore to produce a liquid natural gas with a considerably higher, and preferably a maximum, content of heavier hydrocarbons.
  • the present invention represents a considerable optimisation for application offshore, and especially on a floating unit, in that a relatively simple and robust gas expansion process is used for liquefaction of natural gas, and in that the energy efficiency of this process is increased at the same time as the amount of liquid gas is maximised by maximising the content of ethane and LPG, at the same time as the amount of hydrocarbons heavier than methane which is separated out as bi-products in the liquefaction process is minimised.
  • An installation which comprises the system according to the invention can thereby simply be adapted and be installed, for example, on board floating offshore installations where space is often a limiting factor.
  • EP-1.715.267 describes a method which includes natural gas being cooled and being led through a fractionation column where it is separated into an overhead fraction and a bottom fraction.
  • the bottom fraction is enriched with heavier hydrocarbons and is exported out of the system.
  • the overhead fraction is cooled and forms a two-phase fluid which is separated in a separator.
  • the liquid phase is re-circulated to the fractionation column whilst the gas phase is fed further to a heat exchanger system. Cooling of the overhead fraction is carried out with a free standing cooler.
  • the EP patent consequently describes a classical and well-known distillation process.
  • the set-up is standard practice in so-called “base load” LNG installations, where both cooler 5 and cooler 11 (ref. figures in the EP patent) are parts of the pre-cooling installation of the plant, which is normally carried out as a multistep propane cooling installation.
  • the set up in the EP patent does not integrate a fractionation column and a downstream LNG condensation process as one aims with the present invention. Integration is here meant that two systems are tightly connected together and function as one system and that material streams and/or energy streams are flowing both ways between the systems.
  • Patent publications US2006/0260355 A1 and U.S. Pat. No. 6,662,589 describe systems which apparently are similar to the present invention, but which in reality are considerably different from the present invention.
  • the systems in the referred publications comprise processes for simultaneous liquefaction of natural gas and recovery/separation of components heavier than methane, i.e. ethane and heavier components, where ethane, LPG and heavier components are fractionated into sales products and where the liquid gas has a considerably reduced content of ethane and heavier components.
  • the ethane rich reflux is generated in that the gas from the fractionation column is partially condensed, and in addition by cooling down and condensing a stream rich in ethane which is re-circulated from a fractionation train for fractionation of the bottom fraction from the fractionation column.
  • Patent publications U.S. Pat. No. 6,401,486, U.S. Pat. No. 6,742,358 and WO02006/115597 A2 describe systems for simultaneous liquefaction of natural gas and recovery/separation of components heavier than methane, i.e. ethane and heavier components.
  • the processes themselves are also considerably different from and more complex than the present invention in that the feed gas is first cooled down in, amongst others, the heat exchanger(s) for liquefaction of gas, and also by heat exchange with a flash expanded separated liquid and with fluid from the bottom of the column.
  • the whole or part of the feed gas stream is expanded through a turboexpander or a Joule-Thompson expansion valve before it is led to the fractionation column.
  • a process is described in DE patent 10205366 for simultaneous liquefaction of natural gas and recovery/separation of components heavier than ethane, and where separated LPG and heavier components are fractionated to sales products. This is achieved by first partially cooling down the feed gas in the condensation installation for liquefaction of natural gas and then by leading the cooled down feed gas to a fractionation column where it comes into contact with a reflux rich in ethane so that the fractionation column separates the feed into an overheard gas fraction with a considerably reduced content of components heavier than ethane, and a liquid stream from the bottom considerably enriched with components heavier than ethane.
  • the reflux rich in ethane is generated in that the gas from the fractionation column is partially condensed and thereafter brought into contact with a C4/C5 stream in a second fractionation column, and where the C4/C5 fraction is re-circulated from a fractionation train for fractionation of the bottom product from the first fractionation column.
  • DE patent 10.205.366 comprises, in other words, a process to minimise the content of LPG of the liquid gas, and also the heavier hydrocarbons, while the present invention comprises a system and a method to maximise the content of LPG in the liquid gas.
  • the publication DE 10.205.366 does not describe an increase in energy efficiency which can be achieved in a gas expansion process with the integrated separation column which receives a reflux rich in C3-C5 from the liquefaction heat exchanger(s) for production of LNG.
  • U.S. Pat. No. 7,010,937 shows a system for simultaneous liquefaction of natural gas and recovery / separation of components heavier than methane.
  • the gas feed is pre-cooled and partially condensed so that a liquid stream can be separated in a separator and where this liquid stream is fractionated in a first fractionation column to generate an overhead gas which is cooled down to produce a reflux for a second fractionation column.
  • the gas flow from the separator is expanded across a gas expander and fed to the second fractionation column. Therefore this US patent has little in common with the present invention as it is defined in the subsequent claims.
  • FIG. 1 shows a principal embodiment with main components and main functionality.
  • FIG. 2 shows the invention with an alternative embodiment.
  • FIG. 3 shows the invention with an alternative embodiment that includes further stabilisation of the heavier hydrocarbons that are separated out (condensate).
  • FIG. 4 shows the invention in detail carried out by using a double gas expansion process.
  • FIG. 5 shows the invention carried out by using a hybrid cooling circuit with a gas expansion loop and a liquid expansion loop.
  • FIG. 6 shows an example of a hot temperature curve and a cold temperature curve (composite curve) for a conventional nitrogen expansion cycle.
  • FIG. 7 shows an example of a hot temperature curve and a cold temperature curve (composite curve) for a nitrogen expansion cycle obtained by using the present invention.
  • FIG. 8 shows a comparison of the curves shown in the FIGS. 6 and 7 .
  • the system for optimised liquefaction of gas comprises, as a minimum, the following principle components:
  • Incoming and cleaned feed-gas 1 for example, a methane rich hydrocarbon gas
  • a fractionation column 150 where the gas is cooled down in contact with a colder reflux fluid.
  • the feed gas is separated into an overhead fraction 2 with a reduced content of the hydrocarbons that have a molecular weight higher than pentane (C5), and a bottom fraction 3 enriched with C6 and hydrocarbons that have a higher molecular weight than C6.
  • the overhead fraction 2 from the fractionation column is then led to the heat exchanger system 110 , where the gas is cooled down and partially condensed so that the resulting two-phase fluid 4 can be separated in a suitable separator 160 .
  • the reflux liquid 5 will have a lower temperature than the feed gas 1 .
  • the gas 6 from the separator 160 has now further reduced its content of C5 hydrocarbons and hydrocarbons higher than C5. This gas is then led back to the heat exchanger system 110 for further cooling, condensation and sub cooling.
  • the liquefied gas 11 is alternatively led through a control valve 140 that controls the operating pressure and flow through the system.
  • the gas feed stream 1 is pre-cooled by a suitable external cooling medium such as available air, water, seawater or a separate suitable refrigeration system/pre-cooling system.
  • a suitable external cooling medium such as available air, water, seawater or a separate suitable refrigeration system/pre-cooling system.
  • a separate closed mechanical refrigeration system with propane, ammonia or other appropriate refrigerant is often used.
  • the fractionation column 150 and the separator 160 are operated at pressures and temperatures such that the complete system (the fractionation column 150 and reflux separator 160 ) generate a component split/separation point in the normal boiling point area (NBP) between ⁇ 120° C. and 60 C.
  • NBP normal boiling point area
  • This can, for example, correspond to the light key component for the separation being butane (C4) with a normal boiling point between ⁇ 12° C. and 0° C., and the heavy key component being a C6 component with a boiling point between 50° C. and 70° C.
  • the overhead gas stream 6 of the system will then be enriched with most of the butane (C4) and hydrocarbons with a lower normal boiling point than butane.
  • Cooling and condensation of the feed gas in the heat exchanger system 110 is provided by a closed or open gas expansion process.
  • the cooling process starts in that a cooling medium 21 comprising a gas or a mixture of gases (such as pure nitrogen, methane, a hydrocarbon mixture, or a mixture of nitrogen and hydrocarbons), at a higher pressure, preferably between 3 and 10 MPa, is fed to the heat exchanger system 110 and cooled to a temperature between 0° C. and ⁇ 120° C., but such that the cooling medium stream is mainly a gas at the prevailing pressure and temperature 31 .
  • a cooling medium 21 comprising a gas or a mixture of gases (such as pure nitrogen, methane, a hydrocarbon mixture, or a mixture of nitrogen and hydrocarbons)
  • a higher pressure preferably between 3 and 10 MPa
  • the pre-cooled cooling medium 31 is then led into a gas expander 121 where the gas is expanded to a lower pressure between 5%-40% of the inlet pressure, but preferably to between 10% and 30% of the inlet pressure, and such that the cooling agent mainly is in the gas phase.
  • the gas expander is normally an expansion turbine, also called turboexpander, but other types of expansion equipment for gas can be used, such as a valve.
  • the flow of pre-cooled cooling agent is expanded in the gas expander 121 at a high isentropic efficiency, such that the temperature drops considerably. In certain embodiments of the invention, some liquid can be separated out in this expansion, but this is not a requirement for the process.
  • the cold stream of cooling agent 32 is then led back to the heat exchangers 110 where it is used for cooling and alternatively condensing of the other incoming warm cooling medium streams and the gas that shall be cooled, condensed and sub cooled.
  • the cooling medium will exist as the gas stream 51 , which in a closed loop embodiment is recompressed in an appropriate way for recycle, and is cooled with an external cooling medium, such as air, water, seawater or an appropriate refrigeration unit.
  • an external cooling medium such as air, water, seawater or an appropriate refrigeration unit.
  • the cooling system in an open embodiment will use a cooling medium 21 consisting of a gas or a mixture of gases at a higher pressure received from an appropriate source, for example, from the feed gas that is to be treated and cooled down.
  • the open embodiment comprises that the low pressure cooling medium stream 51 is used for other purposes or, in an appropriate way, is recompressed to be mixed with the feed gas that is to be treated and cooled down.
  • the returning cooling medium stream 51 is led from the heat exchanger 110 to a separate compressor 101 driven by the expansion turbine 121 .
  • the cooling agent is cooled further in a heat exchanger 131 , before the stream is further compressed in the cycle compressors 100 .
  • the cycle compressors 100 can be one or more units, alternatively one or more stages per unit.
  • the cycle compressor can also be equipped with inter cooling 132 between the compressor stages.
  • the compressed cooling medium 20 is then cooled by heat exchange in an aftercooler 130 with the help of an appropriate external cooling medium, such as air, water, seawater or a suitable separate refrigeration cycle, to be re-used as a compressed cooling medium 21 in a closed loop.
  • the system of heat exchangers 110 is one heat exchanger which comprises many different “warm” and “cold” streams in the same unit (a so-called multi-stream heat exchanger).
  • FIG. 2 shows an alternative embodiment where several multi-stream heat exchangers are connected together in such a way that the necessary heat transfer between the cold and warm streams can be accomplished.
  • FIG. 2 shows a heat exchanger system 110 comprising several heat exchangers in series.
  • the invention is not related to a specific type of heat exchanger or number of exchangers, but can be carried out in several different types of heat exchanger systems that can handle the necessary number of hot and cold process streams.
  • FIG. 3 shows an alternative embodiment where the fractionation column 150 is equipped with a reboiler 135 to further improve the separation (a sharper split between light and heavy components), and also to reduce the volatility of the bottom fraction in the column. This can be used to directly produce condensate which is stable at ambient temperature and atmospheric pressure.
  • FIG. 4 shows in details the invention applied in a more advanced embodiment where a double gas expansion process is used.
  • the compressed cooling medium stream 21 is first cooled down to an intermediate temperature.
  • the cooling agent stream is divided into two parts, where one part 31 is taken out of the heat exchanger and is expanded in the gas expander 121 to a low pressure gas stream 32 .
  • the other part 41 is pre-cooled further to be expanded in the gas expander 122 to a pressure essentially equal to the pressure in stream 32 .
  • the expanded cold cooling agent streams 32 , 42 are returned to different inlet locations on the heat exchanger system 110 and are combined to one stream in this exchanger. Heated cooling agent 51 is then returned to recompression.
  • the compressed cooling agent stream 20 in the double gas expansion circuit can be split into two streams before the heat exchanger 110 to be cooled down to different temperatures in separate flow channels in the heat exchanger 110 .
  • the embodiment is otherwise in accordance with FIG. 3 .
  • FIG. 5 shows in detail the invention carried out with the use of a hybrid cooling loop where one cooling medium is used both in a pure gas phase and in a pure liquid phase.
  • a closed cooling loop provides the cooling of the feed gas in the heat exchanger system 110 .
  • the Said cooling cycle starts by methane or a mixture of methane and nitrogen, where methane makes up at least 50% of the volume, being compressed and aftercooled to a compressed cooling medium stream 21 , and where this cooling medium stream is pre-cooled, and at least a part 31 of the cooling medium stream is used in the gas phase in that it is expanded across a gas expander 121 and that at least a part 41 of the cooling agent stream is condensed to liquid and is expanded across a valve or liquid expander 141 .
  • the embodiment of the invention is not limited to the cooling processes described above only, but can be used with any gas expansion cooling process for liquefaction of natural gas or other hydrocarbon gas, where the cooling is mainly achieved by using one or more expanding gas streams.
  • a product of liquefied gas which has a maximum content of methane, ethane and LPG, however, at the same time does not contain more than the permitted level of pentane and heavier hydrocarbons with a normal boiling point above 50-60° C.
  • the by-production of volatile hydrocarbons with considerable content of ethane, propane and butane is minimised or eliminated, where such will be difficult to handle on an offshore installation for LNG production.
  • more liquid natural gas will also be produced with lower energy consumption than for similar cooling cycles configured without the fractionation column which receives cold and LPG-rich reflux from the cooling down process.
  • the heavier hydrocarbons which are essential to separate out to prevent freezing during the liquefaction will be condensed and be separated at considerably higher temperatures than in conventional methods, in that much of the condensing takes place in the fractionation column. This reduces the energy loss in the cooling process in that cooling load is moved to a higher temperature range.
  • the heat exchanger system 100 of the cooling process receives the gas which is to be liquefied as stream 2 (the overhead gas stream in the fractionation column), which has a reduced temperature with respect to the actual gas feed stream 1 .
  • a gas expansion process is characterised in that the warm and cold cooling curves are dominated by the large amount of gas which is used as cooling medium. These gas streams form linear cooling curves.
  • the reduced feed temperature into the heat exchanger results in a “break point” on the warm cooling curve (the sum of the streams which are being cooled), so that it is possible to obtain a general reduction of the distance between the warm and cold cooling curves. This provides a better temperature adaption, reduced energy loss and thus a reduced energy consumption to drive the cooling process.
  • FIG. 6 shows warm and cold cooling curves (warm and cold composite curves, i.e. the sum of all warm streams that are to be cooled down and the sum of all cold streams that are to be heated up, respectively) for the heat exchanger system 110 carried out in accordance with the present invention, and with a double nitrogen expansion process as cooling system.
  • FIG. 7 shows corresponding warm and cold cooling curves for a corresponding cooling process with the same feed, but carried out in a conventional way without the fractionation column. The curves appear to look alike, but by considering FIG. 8 , which shows a section and both the systems in (Note: skrivefeil i originaltekst) the same curve, the “break point” and the better adaption can clearly be seen.
  • the example below shows natural gas with 90.4% methane by volume which is to be liquefied, where the invention is used to maximise the amount of liquid gas and at the same time minimise the by-production of unstable hydrocarbon liquid with a high content of ethane, propane and butane.
  • the stream data refer to FIG. 1 , 2 , 3 , 4 or 5 .

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  • Engineering & Computer Science (AREA)
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  • Mechanical Engineering (AREA)
  • Thermal Sciences (AREA)
  • General Engineering & Computer Science (AREA)
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  • Oil, Petroleum & Natural Gas (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • General Chemical & Material Sciences (AREA)
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  • Organic Chemistry (AREA)
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US12/665,329 2007-06-22 2008-06-20 Method and system for producing LNG Abandoned US20100132405A1 (en)

Applications Claiming Priority (3)

Application Number Priority Date Filing Date Title
NO20073245A NO329177B1 (no) 2007-06-22 2007-06-22 Fremgangsmåte og system til dannelse av flytende LNG
NO20073245 2007-06-22
PCT/NO2008/000229 WO2009017414A1 (en) 2007-06-22 2008-06-20 Method and system for producing lng

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US9243842B2 (en) 2008-02-15 2016-01-26 Black & Veatch Corporation Combined synthesis gas separation and LNG production method and system
US9423174B2 (en) 2009-04-20 2016-08-23 Exxonmobil Upstream Research Company Cryogenic system for removing acid gases from a hydrocarbon gas stream, and method of removing acid gases
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US9829247B2 (en) 2013-12-06 2017-11-28 Exxonmobil Upstream Reseach Company Method and device for separating a feed stream using radiation detectors
US9869511B2 (en) 2013-12-06 2018-01-16 Exxonmobil Upstream Research Company Method and device for separating hydrocarbons and contaminants with a spray assembly
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US10222121B2 (en) 2009-09-09 2019-03-05 Exxonmobil Upstream Research Company Cryogenic system for removing acid gases from a hydrocarbon gas stream
US10323495B2 (en) 2016-03-30 2019-06-18 Exxonmobil Upstream Research Company Self-sourced reservoir fluid for enhanced oil recovery
US10365037B2 (en) 2015-09-18 2019-07-30 Exxonmobil Upstream Research Company Heating component to reduce solidification in a cryogenic distillation system
US10495379B2 (en) 2015-02-27 2019-12-03 Exxonmobil Upstream Research Company Reducing refrigeration and dehydration load for a feed stream entering a cryogenic distillation process
US10563913B2 (en) 2013-11-15 2020-02-18 Black & Veatch Holding Company Systems and methods for hydrocarbon refrigeration with a mixed refrigerant cycle
US11255603B2 (en) 2015-09-24 2022-02-22 Exxonmobil Upstream Research Company Treatment plant for hydrocarbon gas having variable contaminant levels
US11306267B2 (en) 2018-06-29 2022-04-19 Exxonmobil Upstream Research Company Hybrid tray for introducing a low CO2 feed stream into a distillation tower
RU2775341C1 (ru) * 2022-02-16 2022-06-29 Публичное акционерное общество криогенного машиностроения (ПАО "Криогенмаш") Способ сжижения природного газа (варианты)
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Cited By (38)

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US20100018248A1 (en) * 2007-01-19 2010-01-28 Eleanor R Fieler Controlled Freeze Zone Tower
US8650906B2 (en) * 2007-04-25 2014-02-18 Black & Veatch Corporation System and method for recovering and liquefying boil-off gas
US20080264076A1 (en) * 2007-04-25 2008-10-30 Black & Veatch Corporation System and method for recovering and liquefying boil-off gas
US9243842B2 (en) 2008-02-15 2016-01-26 Black & Veatch Corporation Combined synthesis gas separation and LNG production method and system
US9746234B2 (en) * 2008-09-19 2017-08-29 Woodside Energy Ltd Mixed refrigerant compression circuit
US20120067080A1 (en) * 2008-09-19 2012-03-22 Woodside Energy Limited Mixed Refrigerant Compression Circuit
US9423174B2 (en) 2009-04-20 2016-08-23 Exxonmobil Upstream Research Company Cryogenic system for removing acid gases from a hydrocarbon gas stream, and method of removing acid gases
US10222121B2 (en) 2009-09-09 2019-03-05 Exxonmobil Upstream Research Company Cryogenic system for removing acid gases from a hydrocarbon gas stream
US9149761B2 (en) 2010-01-22 2015-10-06 Exxonmobil Upstream Research Company Removal of acid gases from a gas stream, with CO2 capture and sequestration
US10113127B2 (en) 2010-04-16 2018-10-30 Black & Veatch Holding Company Process for separating nitrogen from a natural gas stream with nitrogen stripping in the production of liquefied natural gas
US8635885B2 (en) 2010-10-15 2014-01-28 Fluor Technologies Corporation Configurations and methods of heating value control in LNG liquefaction plant
US9777960B2 (en) 2010-12-01 2017-10-03 Black & Veatch Holding Company NGL recovery from natural gas using a mixed refrigerant
US9927170B2 (en) * 2011-03-29 2018-03-27 Linde Aktiengesellschaft Heat exchanger system
US20120247147A1 (en) * 2011-03-29 2012-10-04 Linde Aktiengesellschaft Heat exchanger system
WO2013015907A1 (en) * 2011-07-22 2013-01-31 Exxonmobil Upstream Research Company Helium recovery from natural gas streams
US10139157B2 (en) 2012-02-22 2018-11-27 Black & Veatch Holding Company NGL recovery from natural gas using a mixed refrigerant
US10323879B2 (en) 2012-03-21 2019-06-18 Exxonmobil Upstream Research Company Separating carbon dioxide and ethane from a mixed stream
US9964352B2 (en) 2012-03-21 2018-05-08 Exxonmobil Upstream Research Company Separating carbon dioxide and ethane from a mixed stream
US10563913B2 (en) 2013-11-15 2020-02-18 Black & Veatch Holding Company Systems and methods for hydrocarbon refrigeration with a mixed refrigerant cycle
US9823016B2 (en) 2013-12-06 2017-11-21 Exxonmobil Upstream Research Company Method and system of modifying a liquid level during start-up operations
US9562719B2 (en) 2013-12-06 2017-02-07 Exxonmobil Upstream Research Company Method of removing solids by modifying a liquid level in a distillation tower
US9874396B2 (en) 2013-12-06 2018-01-23 Exxonmobil Upstream Research Company Method and device for separating hydrocarbons and contaminants with a heating mechanism to destabilize and/or prevent adhesion of solids
US9874395B2 (en) 2013-12-06 2018-01-23 Exxonmobil Upstream Research Company Method and system for preventing accumulation of solids in a distillation tower
US9829247B2 (en) 2013-12-06 2017-11-28 Exxonmobil Upstream Reseach Company Method and device for separating a feed stream using radiation detectors
US9803918B2 (en) 2013-12-06 2017-10-31 Exxonmobil Upstream Research Company Method and system of dehydrating a feed stream processed in a distillation tower
US9752827B2 (en) 2013-12-06 2017-09-05 Exxonmobil Upstream Research Company Method and system of maintaining a liquid level in a distillation tower
US9869511B2 (en) 2013-12-06 2018-01-16 Exxonmobil Upstream Research Company Method and device for separating hydrocarbons and contaminants with a spray assembly
US10139158B2 (en) 2013-12-06 2018-11-27 Exxonmobil Upstream Research Company Method and system for separating a feed stream with a feed stream distribution mechanism
CN103865601B (zh) * 2014-03-13 2015-07-08 中国石油大学(华东) 丙烷预冷脱乙烷塔顶回流的重烃回收方法
CN103865601A (zh) * 2014-03-13 2014-06-18 中国石油大学(华东) 丙烷预冷脱乙烷塔顶回流的重烃回收方法
US9574822B2 (en) 2014-03-17 2017-02-21 Black & Veatch Corporation Liquefied natural gas facility employing an optimized mixed refrigerant system
US10495379B2 (en) 2015-02-27 2019-12-03 Exxonmobil Upstream Research Company Reducing refrigeration and dehydration load for a feed stream entering a cryogenic distillation process
US10365037B2 (en) 2015-09-18 2019-07-30 Exxonmobil Upstream Research Company Heating component to reduce solidification in a cryogenic distillation system
US11255603B2 (en) 2015-09-24 2022-02-22 Exxonmobil Upstream Research Company Treatment plant for hydrocarbon gas having variable contaminant levels
US10323495B2 (en) 2016-03-30 2019-06-18 Exxonmobil Upstream Research Company Self-sourced reservoir fluid for enhanced oil recovery
US11306267B2 (en) 2018-06-29 2022-04-19 Exxonmobil Upstream Research Company Hybrid tray for introducing a low CO2 feed stream into a distillation tower
US11378332B2 (en) 2018-06-29 2022-07-05 Exxonmobil Upstream Research Company Mixing and heat integration of melt tray liquids in a cryogenic distillation tower
RU2775341C1 (ru) * 2022-02-16 2022-06-29 Публичное акционерное общество криогенного машиностроения (ПАО "Криогенмаш") Способ сжижения природного газа (варианты)

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AU2008283102A1 (en) 2009-02-05
AU2008283102B2 (en) 2013-02-07
MY163902A (en) 2017-11-15
EP2165140A1 (en) 2010-03-24
KR20100039353A (ko) 2010-04-15
KR101568763B1 (ko) 2015-11-12
NO329177B1 (no) 2010-09-06
NO20073245L (no) 2008-12-23
CN101711335A (zh) 2010-05-19
BRPI0813297A2 (pt) 2014-12-30
CN101711335B (zh) 2014-10-15
WO2009017414A1 (en) 2009-02-05

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