US20170038139A1 - Method for the production of liquefied natural gas - Google Patents

Method for the production of liquefied natural gas Download PDF

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Publication number
US20170038139A1
US20170038139A1 US15/230,034 US201615230034A US2017038139A1 US 20170038139 A1 US20170038139 A1 US 20170038139A1 US 201615230034 A US201615230034 A US 201615230034A US 2017038139 A1 US2017038139 A1 US 2017038139A1
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Prior art keywords
natural gas
heat exchanger
lng
stream
pressure
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Abandoned
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US15/230,034
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English (en)
Inventor
Michael A. Turney
Alain Guillard
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LAir Liquide SA pour lEtude et lExploitation des Procedes Georges Claude
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LAir Liquide SA pour lEtude et lExploitation des Procedes Georges Claude
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Application filed by LAir Liquide SA pour lEtude et lExploitation des Procedes Georges Claude filed Critical LAir Liquide SA pour lEtude et lExploitation des Procedes Georges Claude
Priority to US15/230,034 priority Critical patent/US20170038139A1/en
Publication of US20170038139A1 publication Critical patent/US20170038139A1/en
Abandoned legal-status Critical Current

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    • 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
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    • 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
    • F25J1/0012—Primary atmospheric gases, e.g. air
    • F25J1/0015—Nitrogen
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    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J1/00—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
    • F25J1/003—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures characterised by the kind of cold generation within the liquefaction unit for compensating heat leaks and liquid production
    • F25J1/0032—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures characterised by the kind of cold generation within the liquefaction unit for compensating heat leaks and liquid production using the feed stream itself or separated fractions from it, i.e. "internal refrigeration"
    • F25J1/0035—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures characterised by the kind of cold generation within the liquefaction unit for compensating heat leaks and liquid production using the feed stream itself or separated fractions from it, i.e. "internal refrigeration" by gas expansion with extraction of work
    • F25J1/0037—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures characterised by the kind of cold generation within the liquefaction unit for compensating heat leaks and liquid production using the feed stream itself or separated fractions from it, i.e. "internal refrigeration" by gas expansion with extraction of work of a return stream
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    • F25J2205/60—Processes or apparatus using other separation and/or other processing means using adsorption on solid adsorbents, e.g. by temperature-swing adsorption [TSA] at the hot or cold end
    • F25J2205/66—Regenerating the adsorption vessel, e.g. kind of reactivation gas
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    • F25J2290/70—Processing device is mobile or transportable, e.g. by hand, car, ship, rocket engine etc.

Definitions

  • the present invention generally relates to a method and apparatus for producing liquefied natural gas (LNG) in a packaged unit without any rotating machinery.
  • LNG liquefied natural gas
  • Liquid gases can be stored in suitably designed cryogenic containers and dispensed into vehicle tanks using techniques that have been in use for many years in the industrial cryogenic gas industries.
  • LNG liquefied natural gas
  • the cascade process produces liquefied gases by employing several closed-loop cooling circuits, each utilizing a single pure refrigerant and collectively configured in order of progressively lower temperatures.
  • the first cooling circuit commonly utilizes propane or propylene as the refrigerant; the second circuit may utilize ethane or ethylene, while the third circuit generally utilizes methane as the refrigerant.
  • the single mixed refrigerant process produces LNG by employing a single closed-loop cooling circuit utilizing a multi-component refrigerant consisting of components such as nitrogen, methane, ethane, propane, butanes and pentanes.
  • the mixed refrigerant undergoes the steps of condensation, expansion and recompression to reduce the temperature of natural gas by employing a unitary collection of heat exchangers known as a “cold box.”
  • the propane pre-cooled mixed refrigerant process produces LNG by employing an initial series of propane-cooled heat exchangers in addition to a single closed-loop cooling circuit, which utilizes a multi-component refrigerant consisting of components such as nitrogen, methane, ethane and propane. Natural gas initially passes through one or more propane-cooled heat exchangers, proceeds to a main exchanger cooled by the multi-component refrigerant, and is thereafter expanded to produce LNG.
  • One of the distinguishing features of a conventional liquefaction plant in the prior art is the large capital investment required.
  • the equipment used to liquefy cryogenic gases in high volumes is large, complex and very expensive.
  • the plant is typically made up of several basic systems, including a gas treatment system (to remove impurities from the initial feed stream), and liquefaction, refrigeration, power, storage and loading facilities. Materials required in conventional liquefaction plants also contribute greatly to the plants' cost.
  • Containers, long runs of piping, and multiple-level tiers of other equipment are principally constructed from aluminum, stainless steel or high nickel content steel to provide the necessary strength and fracture toughness at low temperatures. It would therefore be beneficial to decrease the initial amount of capital investment needed to form a liquefaction plant.
  • U.S. Pat. No. 5,755,114 to Foglietta discloses a hybrid liquefaction cycle for the production of LNG.
  • the Foglietta process passes a pressurized natural gas feed stream into heat exchange contact with a closed-loop propane or propylene refrigeration cycle prior to directing the natural gas feed stream through a turboexpander cycle to provide auxiliary refrigeration.
  • the Foglietta process requires at least one external closed-loop refrigeration cycle comprising propane or propylene, both of which are explosive.
  • U.S. Pat. No. 3,616,652 to Engel discloses a process for producing LNG in a single stage by compressing a natural gas feed stream, cooling the compressed natural gas feed stream to form a liquefied stream, dramatically expanding the liquefied stream to an intermediate-pressure liquid, and then flashing and separating the intermediate-pressure liquid in a single separation step to produce LNG and a low-pressure flash gas.
  • the low-pressure flash gas is recirculated, substantially compressed and reintroduced into the intermediate pressure liquid. While the Engel process produces LNG without the use of external refrigerants, the process yields a small volume of LNG compared to the amount of work required for its production, thus limiting the economic viability of the process.
  • the present invention is directed to a method and apparatus that satisfies at least one of these needs.
  • the invention can provide a lower cost, more efficient and flexible method to produce LNG using a transportable apparatus.
  • the invention utilizes a natural gas letdown to produce LNG in a packaged unit, without the need for electrically powered compressors or the use of rotating machinery.
  • a transportable apparatus for the production of liquefied natural gas (“LNG”) is provided.
  • the apparatus can include a housing, a natural gas feed inlet, a heat exchanger, a phase separator, a liquid outlet disposed on the cold end of the heat exchanger, an LNG product outlet disposed on the cold end of the heat exchanger, a first refrigeration supply, a second refrigeration supply, and wherein the heat exchanger, the phase separator, the first expansion valve, the first refrigeration supply, and the second refrigeration supply are all disposed within the housing.
  • the natural gas feed inlet configured to accept a stream of pressurized natural gas originating from outside the housing.
  • the heat exchanger is in fluid communication with the natural gas feed inlet, such that the heat exchanger is configured to receive the stream of pressurized natural gas from the natural gas feed inlet, wherein the heat exchanger has a warm end, a cold end, and an intermediate section.
  • the phase separator has a fluid inlet, a gaseous outlet, and a liquid outlet, wherein the fluid inlet is in fluid communication with a first intermediate fluid outlet located in the intermediate section of the heat exchanger, such that the phase separator is configured to receive a partially cooled fluid from the heat exchanger, wherein the liquid outlet of the phase separator is in fluid communication with a first intermediate fluid inlet of the intermediate section of the heat exchanger, wherein the gaseous outlet of the phase separator is in fluid communication with a second intermediate fluid inlet of the intermediate section of the heat exchanger, such that the second intermediate fluid inlet of the intermediate section of the heat exchanger is configured to receive at least a first portion of gas coming from the phase separator.
  • the liquid outlet is disposed on the cold end of the heat exchanger and in fluid communication with the second intermediate fluid inlet of the intermediate section of the heat exchanger.
  • the LNG product outlet is in fluid communication with the liquid outlet disposed on the cold end of the heat exchanger.
  • the first refrigeration supply comprises a first expansion valve, a first LNG inlet disposed on the cold end of the heat exchanger, and a first natural gas outlet disposed on the warm end of the heat exchanger, wherein the first refrigeration supply is in fluid communication with the liquid outlet disposed on the cold end of the heat exchanger, wherein the heat exchanger is configured to indirectly exchange heat between a first LNG stream and a natural gas stream when the first LNG stream flows from the first LNG inlet to first natural gas outlet.
  • the second refrigeration supply is configured to provide refrigeration within the heat exchanger.
  • the flow of first and second LNG stream combined can account for less than 10% of the flow of the natural gas flowing through the natural gas feed inlet.
  • the expanded second portion of top gas can constitute a third refrigeration supply.
  • the expanded heavy hydrocarbons can constitute a fourth refrigeration supply.
  • a method for the production of liquefied natural gas (“LNG”) using a transportable apparatus can include the steps of: providing a transportable apparatus, wherein the transportable apparatus comprises a housing, a heat exchanger, a phase separator, a first refrigeration supply, and a second refrigeration supply, wherein the first refrigeration supply and the second refrigeration supply are configured to provide refrigeration within the heat exchanger; introducing a natural gas stream into the transportable apparatus at a first pressure under conditions effective for producing an LNG stream; withdrawing the LNG stream from the transportable apparatus; and withdrawing a warm natural gas stream from the transportable apparatus, wherein the warm natural gas stream is at a second pressure, wherein the second pressure is lower than the first pressure.
  • LNG liquefied natural gas
  • FIG. 1 provides an embodiment of the present invention.
  • FIG. 2 provides an embodiment of the present invention, wherein the second refrigeration supply includes expanding a portion of the liquefied natural gas.
  • FIG. 3 provides an embodiment of the present invention, wherein the second refrigeration supply includes liquid nitrogen.
  • FIG. 4 provides another embodiment of the present invention having an expansion turbine.
  • FIG. 5 provides an embodiment of the present invention having an expansion turbine driving a gas booster.
  • the present invention proposes a solution for liquefaction of natural gas (LNG) which can be packaged (within size of truck trailer, barge, etc. . . . ) and preferably requires “zero energy” consumption and contains no rotating machinery equipment. This saves on setup of electrical equipment and operating maintenance.
  • LNG natural gas
  • the apparatus can effectively achieve the goal of liquefaction of LNG with no rotating machinery by utilizing the letdown energy of available letdown stations.
  • one potential location that could benefit from an embodiment of the present invention would include city gates where high pressure natural gas from transmission lines are letdown to low pressure distribution lines. This available letdown energy can be converted to refrigeration energy with a combination of pressure letdown valves described herein.
  • Purified natural gas from a high pressure transmission pipeline can be fed to a main exchanger (such as brazed aluminum), where it can be cooled to an intermediate temperature (e.g., to between ⁇ 40° C. to ⁇ 70° C.) where heavy hydrocarbons (HHCs) are liquefied and separated in a separator.
  • the HHCs can be re-warmed in the exchanger and sent to a medium pressure tail gas header or distribution pipeline (e.g., typically between 4 to 10 bara).
  • Vapor from the separator can be split into two streams. The first can be reduced in pressure through a control valve, re-warmed in the main exchanger and also sent to the medium pressure natural gas header (distribution header). In one embodiment, this expanded stream can provide a majority source of refrigeration for the system.
  • the second vapor stream from the separator can be further cooled and liquefied in the main exchanger to form the LNG product at the cold end.
  • the separation of the vapor stream occurs at the same temperature as the HHC separator.
  • the impact is a small ( ⁇ 5%) loss in thermal efficiency, which is justified by the small scale and simplified design.
  • this HHC stream at the separator outlet can be processed as NGLs, or sent to the LNG production (depending on product constraints of HHC freezing).
  • the re-warmed medium pressure vapor from the separator can be used as a regenerating stream to remove impurities such as water and CO 2 from the adsorption unit.
  • the re-warmed low pressure vapor is mixed with the vaporized HHC stream.
  • the LNG leaving the cold end of the main exchanger can be split into three streams.
  • the first stream can be reduced in pressure and sent to the LNG storage tank.
  • the second can be reduced in pressure, vaporized and warmed against the natural gas being liquefied in the main exchanger and sent to the MP header (e.g., 4-10 bara).
  • the third can be reduced to a lower pressure (e.g., 1.1 to 2 bara) (to provide the required final cold end cooling).
  • the Low Pressure natural gas return stream can be sent to a pretreatment unit where it is burned as fuel to heat a regeneration stream.
  • the pretreatment unit removes water and CO 2 from the natural gas feed for cryogenic processing.
  • the final cold end cooling can be provided by vaporizing liquid nitrogen at the cold end of the main exchanger.
  • LIN can be vaporized at approximately 6 bara and can be utilized as a utility or instrument gas or vented to atmosphere. This is an alternative to vaporizing a portion of the low pressure natural gas (e.g., 1.1 to 2 bara) if there is no demand for this fuel gas and if LIN is available.
  • the product package shown in FIG. 1 describes both the low pressure natural gas stream as well as the LIN injection at the cold end.
  • embodiments of the invention may be practiced with only one of the refrigeration sources present.
  • the invention can be designed as a standard product to accommodate a site with either resource, such that the apparatus will be enabled to work with either of the refrigeration sources (e.g., LIN or LP NG as fuel).
  • the LIN demand can be on the order of 1 to 1.5 mtd continuous.
  • the source of the liquid nitrogen may be trucked in by batch from external source, stored in a LIN tank inside the insulated cold box package. As such, the typical external expensive double walled vacuumed insulated storage tank is not required.
  • This cold box package which can include the main exchanger, separator, valves and LIN tank, can be packaged into the size and shape of a standard shipping container.
  • the first vapor stream from the HHC separator described in the “warm split” above can be replaced by a natural gas stream letdown through a turbine.
  • This turbine creates a cold vapor stream which can be warmed by heat exchange with the natural gas stream being liquefied in the main exchanger. This significantly reduces the flow rate of natural gas required to be letdown. While this turbine adds a rotating machinery component, there is still no refrigeration compressor needed, thereby requiring no electrical system and resulting in “zero energy” LNG production.
  • this natural gas turbine can be connected to an oil brake, or connected to a booster brake to recover additional refrigeration, or connected to a generator brake.
  • HP natural gas 4 can be withdrawn from high pressure natural gas pipeline 2 and sent to purification unit 10 for purification of impurities such as water and CO 2 to form purified natural gas 12 .
  • purification unit 10 can be located within housing 20 .
  • Purified natural gas 12 can then be introduced to housing 20 via natural gas feed inlet 13 , and then introduced to warm end of heat exchanger 30 , where purified natural gas 12 is then partially cooled to a temperature effective for condensing heavy hydrocarbons.
  • Partially cooled natural gas 32 is then removed from an intermediate portion of heat exchanger 30 and fed to phase separator 40 under conditions effective for separating the natural gas from the heavy hydrocarbons.
  • Top gas 42 is then withdrawn from the top of phase separator 40 and preferably split into two portions: first portion of top gas 44 and second portion of top gas 46 .
  • First portion of top gas 44 can be then introduced into cold split 30 b (see FIG. 2 ), and fully cooled and liquefied to form liquefied natural gas 50 .
  • liquefied natural gas 50 can then be split into two or three streams: LNG product 64 , first LNG stream 52 and optionally second LNG stream 54 .
  • LNG product 64 can be removed from housing 20 and then expanded across LNG expansion valve 62 and stored in LNG storage tank 60 .
  • first LNG stream 52 One portion of the refrigeration for the apparatus can be provided by expansion of first LNG stream 52 across first expansion valve 51 .
  • first LNG stream 52 is then warmed in heat exchanger 30 (or in the embodiment shown in other figures cold split 30 b and warm split 30 a ), wherein it is withdrawn from the warm end of heat exchanger 30 at first natural gas outlet 55 , and then from housing 20 and optionally split into two streams, with first portion of warmed first natural gas stream 82 optionally being used to regenerate purification unit 10 , while the remaining portion is expanded across warm expansion valve 84 and combined with first portion of warmed first natural gas stream 82 to form medium pressure natural gas 86 , before being introduced to medium pressure natural gas pipeline 90 .
  • second refrigeration supply can be created by expanding second LNG stream 54 across second expansion valve 53 and warming second LNG stream 54 within heat exchanger 30 , wherein it can be withdrawn from heat exchanger 30 at second natural gas outlet 57 as warmed natural gas 76 .
  • second refrigeration supply is accomplished with warming of liquid nitrogen, and in certain embodiments, vaporizing the liquid nitrogen within heat exchanger 30 .
  • LIN delivery truck 100 can input liquid nitrogen feed 68 to LIN storage tank 70 by connecting to housing 20 via liquid nitrogen feed inlet 67 .
  • the flow of nitrogen is started by opening LIN control valve 71 and flowing liquid nitrogen fluid 72 into cold split 30 b via liquid nitrogen inlet 73 .
  • Liquid nitrogen fluid 72 can then be withdrawn from warm split 30 a of heat exchanger 30 via nitrogen outlet 59 as warmed nitrogen 74 .
  • second portion of top gas 46 can be expanded across third expansion valve 47 to produce additional refrigeration (i.e., third refrigeration supply).
  • third refrigeration supply is configured to provide the predominant portion of cooling within warm split 30 a .
  • second portion of top gas 46 is introduced into intermediate portion of heat exchanger 30 , and preferably combined with first LNG stream 52 within heat exchanger 30 . While FIG. 1 shows second portion of top gas 46 combining with first LNG stream 52 , those of ordinary skill in the art will recognize that the two streams could be within separate flow paths of heat exchanger 30 .
  • heavy hydrocarbons 48 can be withdrawn from the bottom of phase separator 40 , expanded across liquid expansion valve 49 to create additional refrigeration for warm split 30 a (i.e., fourth refrigeration supply).
  • heavy hydrocarbons 48 can be introduced into intermediate section of heat exchanger 30 and warmed within heat exchanger 30 , wherein it can be combined with first LNG stream 52 and second portion of top gas 46 prior to exiting housing 20 .
  • heavy hydrocarbons 48 can be combined with first LNG stream 52 and second portion of top gas 46 within heat exchanger 30 .
  • first portion of top gas 44 , second portion of top gas 46 , and heavy hydrocarbons 48 are all preferably expanded to the substantially same pressure.
  • a portion of stream 46 following expansion in third expansion valve 47 can be sent to storage tank 60 without being rewarmed in heat exchanger 30 .
  • the portion of stream 46 can be further cooled in heat exchanger prior to being sent to storage tank 60 .
  • FIG. 2 a process flow diagram of an embodiment of the current invention is shown, wherein the second refrigeration supply is accomplished using expansion of LNG.
  • 156 tpd of high pressure natural gas is withdrawn at 40 bara from the high pressure natural gas pipeline. As shown in FIG. 1 , it is cooled and then separated in phase separator.
  • 9 tpd of heavy hydrocarbons are expanded and warmed in warm split 30 a
  • 139 tpd of second portion of top gas 46 are expanded and warmed in warm split 30 a.
  • 8 tpd of first portion of top gas 44 are then cooled in cold split 30 b with 5 tpd of LNG being stored at 3 bara.
  • first LNG stream 52 is expanded and warmed in cold split 30 b and warm split 30 a
  • approximately 0.8 tpd of second LNG stream 54 is expanded to 1.9 bara and then warmed in cold split 30 b and warm split 30 a , wherein it can be used as fuel gas.
  • FIG. 3 a process flow diagram of an embodiment of the current invention is shown, wherein the second refrigeration supply is accomplished using expansion of LIN.
  • the second refrigeration supply is accomplished using expansion of LIN.
  • LNG i.e., 5 tpd at 3 bara
  • only 140 tpd of high pressure gas is needed from the pipeline.
  • approximately 1.5 tpd of LIN which can be stored at a temperature ⁇ 176° C. can be expanded from 6.3 bara to approximately 6 bar, and warmed in cold split 30 b and warm split 30 a before being introduced to a nitrogen pipeline.
  • purified natural gas 12 can be split, outside or within heat exchanger 30 into first portion of purified natural gas 15 and second portion of purified natural gas 16 , with first portion of purified natural gas 15 going to form LNG and first/second refrigeration supply.
  • second portion of purified natural gas 16 is preferably partially cooled in warm split 30 a and then expanded in natural gas expansion turbine 110 to form expanded natural gas 112 , which is then fed into cold split 30 b and warmed therein.
  • a portion of expanded natural gas 112 can be direct either directly to LNG storage tank 60 or cooled in heat exchanger 30 before being sent to LNG storage tank 60 .
  • top gas 46 and second expansion valve 53 While the embodiment shown in FIG. 4 does not include second portion of top gas 46 and second expansion valve 53 , those of ordinary skill in the art will recognize that second portion of top gas 46 and second expansion valve 53 could be included in this embodiment. While this embodiment includes rotating equipment, the embodiment can still produce LNG without the need for any externally provided electricity for the process equipment.
  • natural gas expansion turbine 110 also can include oil brake B. While not shown, brake B may be replaced by an electrical generator.
  • FIG. 5 a process flow diagram of an embodiment of the current invention is shown, which includes a supplemental refrigeration supply that includes natural gas expansion turbine 110 and natural gas booster 120 .
  • purified natural gas 12 is again split into first portion of purified natural gas 15 and second portion of purified natural gas 16 , but instead of second portion of purified natural gas 16 being first expanded, in this embodiment, second portion of purified natural gas 16 can be compressed by natural gas booster 120 , cooled in aftercooler, partially cooled in warm split 30 a and then expanded in natural gas expansion turbine 110 to form expanded natural gas 112 , which is then fed into cold split 30 b and warmed therein. While the embodiment shown in FIG.
  • top gas 46 and second expansion valve 53 does not include second portion of top gas 46 and second expansion valve 53 , those of ordinary skill in the art will recognize that second portion of top gas 46 and second expansion valve 53 could be included in this embodiment. While this embodiment includes rotating equipment, including both a compressor and turbine, the embodiment can still produce LNG without the need for any externally provided electricity, since natural gas expansion turbine 110 powers natural gas booster 120 via a common shaft.
  • ambient temperature refers to the temperature of the air surrounding an object.
  • outdoor ambient temperature is generally between about 0 to 110° F. ( ⁇ 18 to 43° C.).
  • FIG. 2 FIG. 3 FIG. 4 FIG. 5 (no turbine) (no turbine with LIN assist) 1 Turbine/oil brake 1 Turbine/booster INLET NG FEED tpd 156.3 139.6 35.5 26.2 bara 40 40 40 40 OUTLET LIN ASSIST tpd — 1.5 — — NG PRODUCT tpd 150.4 134.5 29.6 20.3 (TAIL GAS) bara 6 6 6 6 6 NG PRODUCT tpd 0.8 0 0.8 0.8 (E.G., FUEL GAS) bara 1.9 — 1.9 1.9 LNG PRODUCT tpd 5 5 5 5 bara 3 3 3 3 3 ° C. sat sat sat sat TURBINE BRAKE kW — — 38 32
  • cryogenic gas if used herein refers to a substance which is normally a gas at ambient temperature that can be converted to a liquid by pressure and/or cooling.
  • a cryogenic gas typically has a boiling point of equal to or less than about ⁇ 130° F. ( ⁇ 90° C.) at atmospheric pressure.
  • liquefied natural gas or “LNG” as used herein refers to natural gas that is reduced to a liquefied state at or near atmospheric pressure.
  • Natural gas refers to raw natural gas or treated natural gas.
  • Raw natural gas is primarily comprised of light hydrocarbons such as methane, ethane, propane, butanes, pentanes, hexanes and impurities like benzene, but may also contain small amounts of non-hydrocarbon impurities, such as nitrogen, hydrogen sulfide, carbon dioxide, and traces of helium, carbonyl sulfide, various mercaptans or water.
  • Treated natural gas is primarily comprised of methane and ethane, but may also contain small percentages of heavier hydrocarbons, such as propane, butanes and pentanes, as well as small percentages of nitrogen and carbon dioxide.
  • “Comprising” in a claim is an open transitional term which means the subsequently identified claim elements are a nonexclusive listing (i.e., anything else may be additionally included and remain within the scope of “comprising”). “Comprising” as used herein may be replaced by the more limited transitional terms “consisting essentially of” and “consisting of” unless otherwise indicated herein.
  • Providing in a claim is defined to mean furnishing, supplying, making available, or preparing something. The step may be performed by any actor in the absence of express language in the claim to the contrary.
  • Optional or optionally means that the subsequently described event or circumstances may or may not occur.
  • the description includes instances where the event or circumstance occurs and instances where it does not occur.
  • Ranges may be expressed herein as from about one particular value, and/or to about another particular value. When such a range is expressed, it is to be understood that another embodiment is from the one particular value and/or to the other particular value, along with all combinations within said range.

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RU2018106658A (ru) 2019-08-22

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