WO2019224951A1 - Installation de prétraitement de gaz naturel - Google Patents

Installation de prétraitement de gaz naturel Download PDF

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Publication number
WO2019224951A1
WO2019224951A1 PCT/JP2018/019869 JP2018019869W WO2019224951A1 WO 2019224951 A1 WO2019224951 A1 WO 2019224951A1 JP 2018019869 W JP2018019869 W JP 2018019869W WO 2019224951 A1 WO2019224951 A1 WO 2019224951A1
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Prior art keywords
natural gas
gas
pretreatment
facility
cooler
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PCT/JP2018/019869
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English (en)
Japanese (ja)
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徹 中山
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日揮グローバル株式会社
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Application filed by 日揮グローバル株式会社 filed Critical 日揮グローバル株式会社
Priority to PCT/JP2018/019869 priority Critical patent/WO2019224951A1/fr
Priority to CN201880078105.5A priority patent/CN111447986A/zh
Priority to KR1020207016561A priority patent/KR102248010B1/ko
Publication of WO2019224951A1 publication Critical patent/WO2019224951A1/fr

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    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/26—Drying gases or vapours
    • B01D53/261—Drying gases or vapours by adsorption
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/02—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols by adsorption, e.g. preparative gas chromatography
    • B01D53/04—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols by adsorption, e.g. preparative gas chromatography with stationary adsorbents
    • B01D53/0407—Constructional details of adsorbing systems
    • B01D53/0438—Cooling or heating systems
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/14—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols by absorption
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/26—Drying gases or vapours
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10L—FUELS NOT OTHERWISE PROVIDED FOR; NATURAL GAS; SYNTHETIC NATURAL GAS OBTAINED BY PROCESSES NOT COVERED BY SUBCLASSES C10G, C10K; LIQUEFIED PETROLEUM GAS; ADDING MATERIALS TO FUELS OR FIRES TO REDUCE SMOKE OR UNDESIRABLE DEPOSITS OR TO FACILITATE SOOT REMOVAL; FIRELIGHTERS
    • C10L3/00—Gaseous fuels; Natural gas; Synthetic natural gas obtained by processes not covered by subclass C10G, C10K; Liquefied petroleum gas
    • C10L3/06—Natural gas; Synthetic natural gas obtained by processes not covered by C10G, C10K3/02 or C10K3/04
    • C10L3/10—Working-up natural gas or synthetic natural gas
    • C10L3/101—Removal of contaminants
    • C10L3/102—Removal of contaminants of acid contaminants
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10L—FUELS NOT OTHERWISE PROVIDED FOR; NATURAL GAS; SYNTHETIC NATURAL GAS OBTAINED BY PROCESSES NOT COVERED BY SUBCLASSES C10G, C10K; LIQUEFIED PETROLEUM GAS; ADDING MATERIALS TO FUELS OR FIRES TO REDUCE SMOKE OR UNDESIRABLE DEPOSITS OR TO FACILITATE SOOT REMOVAL; FIRELIGHTERS
    • C10L3/00—Gaseous fuels; Natural gas; Synthetic natural gas obtained by processes not covered by subclass C10G, C10K; Liquefied petroleum gas
    • C10L3/06—Natural gas; Synthetic natural gas obtained by processes not covered by C10G, C10K3/02 or C10K3/04
    • C10L3/10—Working-up natural gas or synthetic natural gas
    • C10L3/101—Removal of contaminants
    • C10L3/106—Removal of contaminants of water
    • 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
    • F25J1/0236—Heat exchange integration providing refrigeration for different processes treating not the same feed 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
    • F25J1/02—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
    • F25J1/0259—Modularity and arrangement of parts of the liquefaction unit and in particular of the cold box, e.g. pre-fabrication, assembling and erection, dimensions, horizontal layout "plot"
    • 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.
    • F25J1/0281—Compression of refrigerant or internal recycle fluid, e.g. kind of compressor, accumulator, suction drum etc. characterised by the type of prime driver, e.g. hot gas expander
    • F25J1/0283—Gas turbine as the prime mechanical driver
    • 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
    • C10L2290/00—Fuel preparation or upgrading, processes or apparatus therefore, comprising specific process steps or apparatus units
    • C10L2290/06—Heat exchange, direct or indirect
    • 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
    • C10L2290/00—Fuel preparation or upgrading, processes or apparatus therefore, comprising specific process steps or apparatus units
    • C10L2290/54—Specific separation steps for separating fractions, components or impurities during preparation or upgrading of a fuel
    • C10L2290/541—Absorption of impurities during preparation or upgrading of a fuel
    • 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
    • C10L2290/00—Fuel preparation or upgrading, processes or apparatus therefore, comprising specific process steps or apparatus units
    • C10L2290/54—Specific separation steps for separating fractions, components or impurities during preparation or upgrading of a fuel
    • C10L2290/542—Adsorption of impurities during preparation or upgrading of a fuel
    • 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
    • C10L2290/00—Fuel preparation or upgrading, processes or apparatus therefore, comprising specific process steps or apparatus units
    • C10L2290/56—Specific details of the apparatus for preparation or upgrading of a fuel
    • C10L2290/567—Mobile or displaceable apparatus
    • 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
    • F25J2205/50—Processes or apparatus using other separation and/or other processing means using absorption, i.e. with selective solvents or lean oil, heavier CnHm and including generally a regeneration step for the solvent or lean oil
    • 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
    • F25J2205/60—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
    • 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
    • F25J2220/00—Processes or apparatus involving steps for the removal of impurities
    • F25J2220/60—Separating impurities from natural gas, e.g. mercury, cyclic hydrocarbons
    • F25J2220/66—Separating acid gases, e.g. CO2, SO2, H2S or RSH
    • 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
    • F25J2220/68—Separating water or hydrates
    • 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 pretreatment facility for performing pretreatment of liquefaction of natural gas before liquefaction.
  • the natural gas liquefying device for liquefying natural gas which is hydrocarbon gas produced from the well source, includes pretreatment equipment that performs pretreatment to remove various impurities from natural gas before liquefaction, and after pretreatment And a liquefaction facility for liquefying natural gas to obtain LNG (Liquidized Natural Gas).
  • pretreatment facility in order to prevent clogging in the liquefaction facility of natural gas cooled to ⁇ 150 ° C. or less, moisture and carbon dioxide are removed and hydrogen sulfide is removed.
  • Patent Document 1 discloses that when liquefied natural gas (LNG) is produced from natural gas or CSG (coal bed gas), the natural gas before liquefaction is brought into contact with MDEA (N-methyldiethanolamine). Absorbs and removes hydrogen sulfide and carbon dioxide, then passes natural gas through a dehydration plant (adsorption tower) equipped with a molecular sieve (adsorbent) container to adsorb moisture, etc. A technique for reducing the content to 1 ppm is described.
  • LNG liquefied natural gas
  • CSG coal bed gas
  • MDEA N-methyldiethanolamine
  • Patent Document 1 discloses that most of the moisture contained in the gas by cooling the gas before pretreatment to about 15 ° C. using a mixed refrigerant containing nitrogen and a hydrocarbon such as methane or ethane. The technology to remove is described.
  • Patent Document 2 describes a technique for cooling a gas before pretreatment with cooling water cooled using a mixed refrigerant.
  • these patent documents do not disclose a natural gas cooling technique that takes into account the occurrence of troubles such as stopping the supply of natural gas or leakage of refrigerant.
  • the present invention has been made under such a background, and provides a technology for cooling natural gas to a temperature suitable for pretreatment in a pretreatment facility for removing impurities contained in natural gas. .
  • the natural gas pretreatment facility of the present invention is a pretreatment facility in which an iron structure is provided around and performs pretreatment to remove impurities contained in natural gas,
  • An adsorption tower connected to a processing gas line for supplying a natural gas containing moisture and filled with an adsorbent for adsorbing and removing moisture in the natural gas supplied from the processing gas line;
  • a first cooler that is provided in the processing gas line on the inlet side of the adsorption tower and cools natural gas supplied to the adsorption tower by heat exchange with cooling water;
  • a second cooler that cools the cooling water by heat exchange with a non-hydrocarbon refrigerant cooled to a temperature in the range of 0 ° C. to 10 ° C.
  • the natural gas pretreatment facility may have the following characteristics.
  • the pretreatment facility is provided in a natural gas liquefaction apparatus including a liquefaction facility for liquefying natural gas after the pretreatment is performed.
  • B When an iron structure that is cold-resistant coated is provided around the liquefaction facility, the iron structure around the pretreatment facility is not cold-resistant coated.
  • the liquefaction facility includes a gas turbine-driven compressor that compresses the liquefied refrigerant that has been used to liquefy the natural gas, and the non-hydrocarbon refrigerant is taken into the gas turbine. It must also be used for cooling air for gas combustion.
  • the natural gas liquefying apparatus is provided on a floating body floating on the ocean.
  • (E) provided on the upstream side of the adsorption tower, provided with an absorption tower for contacting and removing the natural gas and the absorbing liquid to absorb the acidic gas contained in the natural gas in the absorbing liquid;
  • the processing gas line is connected to the absorption tower instead of the adsorption tower, and the first cooler cools natural gas supplied to the absorption tower.
  • the non-hydrocarbon refrigerant is cooled by an external cooling mechanism.
  • the non-hydrocarbon refrigerant is glycol water or water.
  • the present invention uses the first cooler to cool the natural gas supplied to the pretreatment facility for removing impurities contained in the natural gas by heat exchange with the cooling water. Further, a second cooler is used to cool the cooling water by heat exchange with a non-hydrocarbon refrigerant cooled to 0 ° C. to 10 ° C. Therefore, natural gas can be cooled to a temperature suitable for pretreatment while avoiding direct heat exchange with the non-hydrocarbon refrigerant.
  • the natural gas of this example (also indicated as NG in each figure) contains at least hydrogen sulfide or carbon dioxide, and further contains moisture, mercury, and oxygen.
  • the natural gas is separated from the liquid contained in the natural gas in the gas-liquid separation step 11, and then in the subsequent acidic gas removal step 12, carbon dioxide, hydrogen sulfide, etc. (Sometimes referred to as “acid gas”).
  • the natural gas treated in the acid gas removal step 12 is further removed in a moisture removal step 13.
  • Reference numeral 31 in FIG. 1 is a first cooler that cools the natural gas before being sent to the moisture removing step 13, and reference numeral 32 is for cooling the refrigerant used in the first cooler 31.
  • a second cooler is for cooling the refrigerant used in the first cooler 31.
  • the first cooler 31 and the second cooler 32 will be described in detail later together with the description of the equipment that performs the moisture removal step 13.
  • mercury is removed from the natural gas treated in the moisture removing step 13 in the mercury removing step 14.
  • the gas-liquid separation step 11, the acid gas removal step 12, the moisture removal step 13 and the mercury removal step 14 are performed in the pretreatment facility 101 before the liquefaction treatment is performed.
  • the liquid component separated from NG in the gas-liquid separation step 11 is shipped as a condensate through the storage step 109 after the vapor pressure adjustment step 108 is performed.
  • the acid gas removed from the natural gas in the acid gas removal step 12 is detoxified by thermal decomposition in an incinerator and then released to the atmosphere.
  • about acidic gas for example, you may make it produce
  • the natural gas from which various impurities are removed by the pretreatment facility 101 is liquefied in the liquefaction step 15 to become liquefied natural gas (LNG).
  • the liquefaction step 15 is performed in the liquefaction facility 102.
  • the liquefaction facility 102 is a natural gas distillation section that cools and liquefies a part of natural gas to remove heavy components, or a natural refrigerant from which heavy components have been removed (maintenant refrigerant (liquefaction refrigerant; methane, ethane, propane).
  • main heat exchanging section that cools and liquefies, for example, from ⁇ 145 ° C. to ⁇ 155 ° C.
  • the liquefaction facility 102 is also provided with a refrigerant cooling facility 105 for cooling the main refrigerant.
  • the refrigerant cooling facility 105 includes a compressor 43 for compressing the refrigerant, and the compressor 43 is configured to be driven by a gas turbine.
  • the LNG liquefied in the liquefaction step 15 is shipped to the LNG tanker through the end flash step 16 in the end flash facility 103 and the storage step 17 in the LNG tank (storage facility) 104, for example.
  • the heavy fraction removed from the natural gas in the natural gas distillation section is fractionated into ethane, propane, butane, and condensate in the rectification step 106, and the ethane goes to the liquefaction step 15 (liquefaction facility 102). Returned.
  • propane and butane can be returned to the liquefaction step 15 (liquefaction equipment 102) or shipped as a product.
  • the condensate is mixed with the condensate discharged from the vapor pressure adjustment step 108 and then shipped as a product (FIG. 1 shows only the flow of condensate shipment). Further, a part of ethane, propane, and butane is sent to a refrigerant storage step 107 for use as a refrigerant such as a main refrigerant. Further, the gas generated in the acid gas removal step 12, the end flash step 16 and the storage step 17 is used as, for example, combustion gas.
  • the natural gas containing water from which the acid gas has been removed in the acid gas removal step 12 is supplied to a supply line (processing gas line) 201 provided with a cooling unit 3 and a separation drum 29 described later. And are supplied to adsorption towers 21 to 23 that perform moisture adsorption removal.
  • the adsorption towers 21 to 23 are filled with a moisture adsorbent made of, for example, a molecular sieve.
  • the natural gas supply line 201 branches off at the outlet side of the separation drum 29 and is connected to the inlet portions of the adsorption towers 21 to 23.
  • a dry natural gas discharge line 202 is connected to the outlets of the adsorption towers 21 to 23. These payout lines 202 are connected to equipment for joining the downstream side and performing the mercury removal step 14. Further, a regeneration gas line 203 for supplying dry natural gas to the outlet side of the adsorption towers 21 to 23 as a regeneration gas for executing the adsorption tower regeneration process from the discharge line 202 on the downstream side of the joining position. Is branched. With this configuration, it is possible to use the dried natural gas after removing moisture in the adsorption towers 21 to 23 as the regeneration gas.
  • a regeneration gas line 203 branched from the payout line 202 is provided with a heating unit 27 that includes a heat exchanger or the like and heats the regeneration gas (dry natural gas).
  • the heating unit 27 may be constituted by a heating furnace, for example.
  • a recycling gas line 204 for returning the regeneration gas after regeneration of the adsorbent to the upstream side of the adsorption towers 21 to 23 is connected to the inlet portions of the adsorption towers 21 to 23.
  • These recycle gas lines 204 are connected to a separation drum 26 that separates the condensed water and the regenerative gas through a cooling unit 25 composed of, for example, an air fin cooler for joining the downstream side to cool the regenerative gas.
  • the water separated from the exhaust gas by the separation drum 26 is discharged to the outside after performing a necessary drainage treatment.
  • the regeneration gas naturally gas
  • the recycle gas line 204 may be joined to the fuel gas.
  • the supply lines 201 after branching connected to the adsorption towers 21 to 23 are provided with opening / closing valves V1 to V3, while the recycling gas line 204 after branching is provided with opening / closing valves V1a to V3a. .
  • the discharge line 202 connected to each of the adsorption towers 21 to 23 is provided with opening / closing valves V4 to V6, and the regeneration gas line 203 is also provided with opening / closing valves V4a to V6a.
  • each of the adsorption towers 21 to 23 can switch the piping line connected to the inlet portion between the supply line 201 and the recycle gas line 204.
  • the piping line connected to the outlet can be switched between the discharge line 202 and the regeneration gas line 203.
  • the flow of natural gas when moisture is removed by adsorption in the adsorption towers 21 and 22 and the adsorbent is regenerated in the adsorption tower 23 is indicated by a thick line.
  • the moisture is removed by passing the natural gas containing moisture through the adsorption towers 21 to 23 filled with the moisture adsorbent.
  • the relationship between the temperature at which the natural gas containing saturated moisture is supplied to the adsorption towers 21 to 23 and the flow rate of the natural gas that can be processed in the adsorption towers 21 to 23 will be described.
  • the horizontal axis of FIG. 3 shows the temperature of the natural gas flowing through the packed bed of the adsorbent, and the vertical axis shows the moisture contained in the saturated natural gas at 25 ° C. up to 1 ppm by weight using a unit volume of the adsorbent.
  • the relative limit process flow is shown when the limit process flow that can be reduced is 100%. As shown in FIG. 3, it can be seen that the critical process flow rate decreases as the temperature of the natural gas supplied to the adsorbent increases. Therefore, it can be said that by reducing the supply temperature of the natural gas supplied to the adsorption towers 21 to 23, the limit processing flow rate per unit capacity can be increased and the adsorbent filling amount can be reduced.
  • the cooling line 3 is provided in the supply line 201 on the inlet side of the adsorption towers 21 to 23.
  • the cooling unit 3 includes a first cooler 31 that cools natural gas by heat exchange with the coolant, and a coolant that is used in the first cooler 31 with glycol water that is a non-hydrocarbon refrigerant. And a second cooler 32 that cools by heat exchange.
  • the glycol water used in the second cooler 32 is configured to be cooled by, for example, a cooling mechanism 33 provided outside the cooling unit 3.
  • the cooling mechanism 33 cools the glycol water to 0 ° C. to 10 ° C.
  • HFC Hydrofluoro-Fluorocarbon
  • the natural gas cooled by the cooling unit 3 is sent to predetermined adsorption towers 21 to 23 after free water is separated by the separation drum 29 described above.
  • the non-hydrocarbon refrigerant used for the second cooler 32 may be water containing pressurized water and pure water in addition to glycol water.
  • the temperature of the natural gas is lowered by the cooling unit 3 before the natural gas is supplied to the adsorption towers 21 to 23.
  • the dew point of the cooled natural gas is lowered, and the condensed moisture is separated by the separation drum 29 disposed on the inlet side of the adsorption towers 21 to 23. Accordingly, the temperature of the natural gas supplied to the adsorption towers 21 to 23 is low, the water content is reduced, and the amount of adsorbent charged in the adsorption towers 21 to 23 can be reduced.
  • the glycol water cooled by the cooling mechanism 33 is used for cooling the combustion air taken into the gas turbine 41 that drives the refrigerant compressor 43 described with reference to FIG. Also used for. That is, as shown in FIG. 2, the glycol water cooled by using the HFC in the cooling mechanism 33 is supplied to the air cooler 34 provided in the gas turbine 41 and used as fuel gas combustion air. .
  • the acid gas is removed in the acid gas removing step 12, and the natural gas flowing out to the supply line 201 is in a state containing a saturated amount of water at a temperature in the range of 40 to 60 ° C., for example.
  • This natural gas is cooled to a temperature in the range of 20 to 25 ° C., for example, in the first cooler 31 provided upstream of the adsorption towers 21 to 23.
  • the saturated water vapor amount of the natural gas is reduced, and excess water is condensed as free water.
  • the free water is removed from the natural gas by the separation drum 29.
  • the natural gas directly cooled using the glycol water (non-hydrocarbon refrigerant) cooled by the cooling mechanism 33 has two coolers (the first cooler). There is no need to provide the cooler 31 and the second cooler 32), and the cooling efficiency seems to be good.
  • natural gas is directly cooled by a low-temperature refrigerant in the temperature range of 0 ° C to 10 ° C, it will be cooled when natural gas is unloaded or when troubles such as air supply stop occur. In some cases, the natural gas in the vessel is supercooled. As a result, methane or ethane contained in the natural gas and moisture generate hydrate, which may cause the supply line 201 including the cooler to be blocked thereafter.
  • the cooling unit 3 of this example employs an indirect cooling method in which cooling water used for cooling natural gas by the first cooler 31 is cooled in advance by the second cooler 32.
  • indirectly cooling in this way, the temperature of the cooling water used in the first cooler 31 is adjusted to a temperature within the range of, for example, 15 to 20 ° C. Even when this occurs, the natural gas flowing through the supply line 201 can be maintained at a temperature at which blockage is unlikely to occur without excessive cooling.
  • the air cooler 34 of this example cools the combustion air using glycol water, which is a non-hydrocarbon refrigerant that is safe even when used in the vicinity of high-temperature equipment.
  • glycol water is used for direct cooling of the natural gas
  • an event may occur in which part of the natural gas flowing through the supply line 201 leaks to the glycol water side due to deterioration of the facilities over time.
  • glycol water containing hydrocarbons derived from natural gas merges with glycol water on the air cooler 34 side via the cooling mechanism 33, reducing safety when used in the vicinity of high-temperature equipment. There is also a risk.
  • the open / close valves V1, V2, V4, and V5 before and after the adsorption towers 21 and 22 that perform the moisture removal step 13 are in an open state.
  • the open / close valves V6a and V3a of the regeneration gas line 203 and the recycle gas line 204 connected to the adsorption tower 23 to be subjected to the process are opened.
  • a part of the dried natural gas from which moisture has been removed by adsorption passes through the heating unit 27 and is heated and then supplied to the adsorption tower 23.
  • the adsorbent is regenerated by releasing moisture from the adsorbent in contact with the heated dry natural gas.
  • the natural gas containing moisture released from the adsorbent is cooled by the cooling unit 25, and after free water is removed by the separation drum 26, the natural gas is pressurized using the compressor 28 and merged with the natural gas flowing through the supply line 201. To do.
  • the natural gas supplied to the adsorption towers 21 to 23 for removing the water contained in the natural gas using the first cooler 31 is used as the cooling water. It is cooled by heat exchange with. Further, the second cooler 32 is used to cool the cooling water by heat exchange with glycol water which is a non-hydrocarbon refrigerant cooled to 0 ° C. to 10 ° C. Therefore, natural gas can be appropriately cooled while avoiding direct heat exchange with the non-hydrocarbon refrigerant. As a result, compared with the case where natural gas is not cooled, the amount of adsorbent charged in the adsorption towers 21 to 23 can be reduced even when natural gas is cooled only with cooling water. Can be reduced.
  • the cooling unit 3 described with reference to FIG. 2 is also suitable for the natural gas liquefying apparatus 100 provided in the hull 90 which is a floating body floating on the ocean (may be the ocean or the lake). is there.
  • FIG. 4 schematically shows an example in which the natural gas liquefying apparatus 100 described with reference to FIG. For convenience of illustration, description of equipment for performing the vapor pressure adjustment step 108, the acid gas incinerator 110, and the like is omitted as appropriate.
  • the natural gas liquefying apparatus 100 shown in FIG. 4 includes a mooring facility (turret) 91, a pretreatment facility 101, and a liquefying facility 102 on a deck of a hull 90, for example, and the inside of the hull 90 is made of liquefied natural gas or the like. It is configured as a tanker constituting the storage facility 104.
  • the pretreatment facility 101 is provided with facilities for performing each of the gas-liquid separation step 11, the acid gas removal step 12, the water removal step 13, and the mercury removal step 14 described with reference to FIG. .
  • these facilities are provided so as to be surrounded by a steel structure such as a deck of the hull 90 and a frame 80 that supports each facility.
  • symbol 81 in FIG. 4 is a pipe for conveying natural gas between each installation.
  • the liquefaction facility 102 provided in the natural gas liquefaction apparatus 100 having the above-described configuration handles LNG and a liquefaction refrigerant (for example, the main refrigerant described above) that are cryogenic liquids. Therefore, in the unlikely event that a cryogenic liquid leaks out and the liquid comes into contact with surrounding iron structures such as a deck or a frame, damage due to low temperature brittleness may occur.
  • the iron structure around the liquefaction facility 102 is coated with a cold-resistant coating such as coating with a cold-resistant coating agent in order to prevent damage due to leakage of the cryogenic liquid.
  • FIG. 4 hatching is given to the range where the cold-resistant coating of the iron structure is performed.
  • the temperature of the natural gas processed in the pretreatment facility 101 is about 20 to 60 ° C., even if a trouble that the natural gas leaks occurs, the surrounding iron structure accompanying the low temperature brittleness The problem of damage does not occur.
  • cooling water and glycol water which is a non-hydrocarbon refrigerant at 0 ° C. to 10 ° C. are used as the refrigerant. Therefore, the cryogenic fluid is not handled in the pretreatment facility 101. For this reason, it is not necessary to cold-protect the iron structure surrounding the pretreatment facility.
  • the liquefaction refrigerant is supplied from the liquefaction facility 102 to the natural gas cooler. Piping to be routed must be routed to the pretreatment facility 101 side. As a result, a cold-resistant coating of the surrounding iron structure is newly required over a wide range in which the liquefying refrigerant flows, which may increase the construction cost of the natural gas liquefying apparatus 100.
  • the natural gas pretreatment facility 101 since the natural gas is not cooled using the cryogenic refrigerant, the range of the cold-resistant coating is limited to the liquefaction facility 102. . Even when the natural gas liquefaction facility 100 is provided on land, it is not necessary to apply a cold-resistant coating to the iron structure provided so as to surround the pretreatment facility 101 among the iron structures provided so as to surround each facility. Therefore, the same effect can be obtained.
  • the cooling mechanism 33 that cools the glycol water can be operated independently regardless of the operation status of any other processing equipment. There is an effect to avoid.
  • the second cooler 32 can keep the supply water temperature to the first cooler 31 constant, and has the effect of reducing the operation adjustment of the equipment. is there.
  • the cooling of the natural gas using the cooling unit 3 including the first cooler 31 and the second cooler 32 is limited to the case where it is applied to the cooling of the natural gas supplied to the moisture removing step 13. Absent.
  • the natural gas supplied to the acid gas removal step 12 may be cooled.
  • the cooling unit 3 having the same configuration as that of the example illustrated in FIG. 2 is provided for the supply line 201 through which the natural gas that has passed through the gas-liquid separation step 11 flows.
  • an absorption tower 51 for performing the acid gas removal step 12 is provided in the subsequent stage of the first cooler 31 instead of the adsorption towers 21 to 23 that perform moisture adsorption removal.
  • an absorption liquid containing an amine compound is dispersedly supplied from the tower top side, and cooled natural gas is supplied from the tower bottom side.
  • the absorption liquid and the natural gas are in countercurrent contact in the absorption tower 51, and carbon dioxide and hydrogen sulfide, which are acid gases that may solidify in the LNG during liquefaction, are converted from the natural gas to the absorption liquid. Absorbed and removed.
  • the absorption liquid that has absorbed carbon dioxide, hydrogen sulfide, and the like in the absorption tower 51 is transferred to the regeneration tower 52 due to a pressure difference, and the absorption liquid in the tower is heated by the reboiler 55, thereby dissipating the acid gas absorbed in the absorption liquid.
  • the regenerated absorption liquid is supplied again to the absorption tower 51 by the liquid feed pump 56.
  • various acid gases diffused from the absorption liquid are cooled by the cooler 54 and separated into gas and liquid by the separation drum 58 and then used as combustion gas.
  • the liquid separated from the acid gas by the separation drum 58 is returned to the regeneration tower 52 by the pump 57.
  • the natural gas to be treated is cooled to condense and separate and remove the heavy components, so that the natural gas and the absorbent are brought into contact with each other.
  • the absorption tower 51 can stabilize the absorption of the acid gas in the natural gas into the absorption liquid.
  • cooling water and glycol water instead of the main refrigerant used on the liquefaction facility 102 side as the refrigerant to the cooling unit 3, it can be out of the application range of the cold resistant coating as described above. Operation that does not depend on the operating state of the liquefaction facility 102 can be performed, and blockage of the supply line 201 due to hydrate generation can be prevented.
  • the cooling unit 3 may be provided on the inlet side of both the adsorption towers 21 to 23 and the absorption tower 51. Further, as the non-hydrocarbon refrigerant used in the second cooler 32, pressurized water or pure water may be used instead of the glycol water described above.

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Abstract

Le problème décrit par la présente invention est de fournir une technologie pour refroidir un gaz naturel à une température appropriée pour un prétraitement dans une installation de prétraitement pour éliminer les impuretés contenues dans le gaz naturel. La solution selon la présente invention est configurée de telle sorte que le gaz naturel fourni à une colonne d'adsorption qui élimine l'humidité contenue dans le gaz naturel est refroidi par échange de chaleur avec de l'eau de refroidissement par un premier refroidisseur, et l'eau de refroidissement est refroidie par échange de chaleur avec un fluide frigorigène non hydrocarboné refroidi à 0°C à 10°C par un second refroidisseur. Par conséquent, le gaz naturel peut être refroidi à une température appropriée tout en évitant un échange de chaleur direct avec le fluide frigorigène non hydrocarboné.
PCT/JP2018/019869 2018-05-23 2018-05-23 Installation de prétraitement de gaz naturel WO2019224951A1 (fr)

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CN201880078105.5A CN111447986A (zh) 2018-05-23 2018-05-23 天然气的预处理设备
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