[go: up one dir, main page]

CN111447986A - Pretreatment equipment for natural gas - Google Patents

Pretreatment equipment for natural gas Download PDF

Info

Publication number
CN111447986A
CN111447986A CN201880078105.5A CN201880078105A CN111447986A CN 111447986 A CN111447986 A CN 111447986A CN 201880078105 A CN201880078105 A CN 201880078105A CN 111447986 A CN111447986 A CN 111447986A
Authority
CN
China
Prior art keywords
natural gas
gas
pretreatment
liquefaction
cooler
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Pending
Application number
CN201880078105.5A
Other languages
Chinese (zh)
Inventor
中山彻
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Nikkei Global Co ltd
JGC Corp
Original Assignee
Nikkei Global Co ltd
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Nikkei Global Co ltd filed Critical Nikkei Global Co ltd
Publication of CN111447986A publication Critical patent/CN111447986A/en
Pending legal-status Critical Current

Links

Images

Classifications

    • 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

Landscapes

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

Abstract

The present invention provides the following technology: in a pre-treatment plant for removing impurities contained in natural gas, the natural gas is cooled to a temperature suitable for pre-treatment. The invention is composed of: the natural gas supplied to an adsorption tower that removes moisture contained in the natural gas is cooled by a first cooler through heat exchange with cooling water, and the cooling water is cooled by a second cooler through heat exchange with a non-hydrocarbon refrigerant cooled to 0 ℃ to 10 ℃. Therefore, direct heat exchange with the non-hydrocarbon refrigerant can be avoided, and the natural gas can be cooled appropriately.

Description

Pretreatment equipment for natural gas
Technical Field
The present invention relates to a pretreatment apparatus that performs pretreatment for liquefaction of natural gas before liquefaction.
Background
A Natural Gas liquefaction apparatus for liquefying Natural Gas, which is hydrocarbon Gas produced from a wellhead, includes a pretreatment facility for performing pretreatment for removing various impurities from Natural Gas before liquefaction, and a liquefaction facility for liquefying the pretreated Natural Gas to obtain liquefied Natural Gas (L required Natural Gas, L NG).
In the pretreatment facility, in order to prevent clogging of the natural gas cooled to-150 ℃ or lower in the liquefaction facility, removal of hydrogen sulfide and the like are performed in addition to removal of moisture and carbon dioxide.
As an example of the pretreatment equipment, patent document 1 describes a technology of, when liquefied natural gas (L NG) is produced from natural gas or Coal bed gas (CSG), bringing the natural gas before liquefaction into contact with N-Methyldiethanolamine (MDEA) to absorb and remove hydrogen sulfide or carbon dioxide, and then passing the natural gas through a dehydration equipment (adsorption tower) including a molecular sieve (adsorbent) vessel to adsorb moisture or the like and reduce the moisture content to 1 ppm.
As with general gases, the saturated steam amount of natural gas tends to increase as the temperature thereof increases. Therefore, as described in patent document 1, when natural gas is circulated through an adsorbent that adsorbs moisture and the moisture in the natural gas is adsorbed and removed, if the temperature of the natural gas to be treated is high, the amount of moisture introduced into the adsorption tower may increase. As a result, the adsorbent filling amount of the adsorption tower tends to increase as compared with the case where natural gas is supplied at a lower temperature.
Regarding the above-mentioned aspect, patent document 1 describes a technique of: the gas before pretreatment is cooled to about 15 ℃ by using a mixed refrigerant containing nitrogen and a hydrocarbon such as methane or ethane, and most of the moisture contained in the gas is removed. Patent document 2 describes a technique of: the gas before pretreatment is cooled by cooling water cooled by using a mixed refrigerant. However, these patent documents do not disclose a technique for cooling natural gas in consideration of occurrence of a failure such as stop of supply of natural gas or leakage of refrigerant.
Documents of the prior art
Patent document
Patent document 1: japanese patent application publication No. 2010-532796
Patent document 2: U.S. patent publication No. 2017/0067684
Disclosure of Invention
Problems to be solved by the invention
The present invention has been accomplished in view of the above-mentioned background, and provides a technique for cooling natural gas to a temperature suitable for pretreatment in a pretreatment apparatus for removing impurities contained in the natural gas.
Means for solving the problems
The pretreatment facility for natural gas according to the present invention is a pretreatment facility for performing pretreatment for removing impurities contained in natural gas, the pretreatment facility being provided with an iron structure around the pretreatment facility, and is characterized by comprising:
an adsorption tower connected to a process gas line for supplying natural gas containing moisture, the adsorption tower being filled with an adsorbent for adsorbing and removing moisture in the natural gas supplied from the process gas line;
a first cooler which is provided in the process gas line on the inlet side of the adsorption tower and cools the natural gas supplied to the adsorption tower by heat exchange with cooling water; and
and a second cooler for cooling the cooling water by heat exchange with a non-hydrocarbon refrigerant cooled to a temperature in the range of 0 ℃ to 10 ℃.
The natural gas pretreatment plant may also include the following features.
(a) The pretreatment equipment is arranged in a natural gas liquefaction device, and the natural gas liquefaction device comprises liquefaction equipment for liquefying the pretreated natural gas.
(b) In the case where an iron structure coated with cold resistance is provided around the liquefaction facility, the iron structure around the pretreatment facility is not coated with cold resistance.
(c) The liquefaction plant is used for liquefaction of the natural gas, and includes a compressor driven by a gas turbine that compresses a liquefaction refrigerant that becomes a gas, and the non-hydrocarbon refrigerant is also used for cooling air for combustion of the fuel gas that is introduced into the gas turbine.
(d) The natural gas liquefaction device is arranged on a floating body floating on the ocean.
(e) The natural gas pretreatment equipment comprises: an absorption tower provided upstream of the adsorption tower, for bringing natural gas into contact with an absorption liquid and removing acid gas contained in the natural gas by allowing the absorption liquid to absorb the acid gas,
the process gas line is connected to the absorption column instead of the adsorption column, and the first cooler cools the natural gas supplied to the absorption column.
(f) The non-hydrocarbon refrigerant is cooled by an external cooling mechanism.
(g) The non-hydrocarbon refrigerant is glycol water or water.
ADVANTAGEOUS EFFECTS OF INVENTION
The present invention uses a first cooler to cool natural gas supplied to a pretreatment apparatus that removes impurities contained in the natural gas by heat exchange with cooling water. Further, the cooling water is cooled by heat exchange with a non-hydrocarbon refrigerant cooled to 0 to 10 ℃ by using a second cooler. Thus, direct heat exchange with the non-hydrocarbon refrigerant may be avoided and the natural gas is cooled to a temperature suitable for pretreatment.
Drawings
FIG. 1 is a process diagram showing various treatment steps performed by a natural gas liquefaction apparatus.
FIG. 2 is a schematic diagram of a water removal device provided in the natural gas liquefaction plant.
Fig. 3 is a graph showing the correspondence between the temperature of saturated natural gas and the treatment flow rate at its limit.
Fig. 4 is a configuration diagram of a natural gas liquefaction device provided in a hull as a floating body.
Fig. 5 is a process diagram corresponding to the natural gas pretreatment apparatus according to the other embodiment.
FIG. 6 is a schematic diagram of an apparatus for removing an acid gas.
Detailed Description
First, a flow of natural gas treatment in the natural gas liquefaction system of this example will be described with reference to fig. 1.
The natural gas (also referred to as NG in the figures) in this example contains at least hydrogen sulfide or carbon dioxide, and also contains moisture, mercury, or oxygen.
As shown in fig. 1, in the natural gas, after the liquid contained in the natural gas is separated in the gas-liquid separation step 11, carbon dioxide, hydrogen sulfide, or the like (these may be collectively referred to as "acid gas") is removed in the subsequent acid gas removal step 12.
The natural gas treated in the acid gas removal step 12 is further subjected to moisture removal in a moisture removal step 13. In fig. 1, reference numeral 31 denotes a first cooler for cooling the natural gas before the natural gas is sent to the moisture removal step 13, and reference numeral 32 denotes a second cooler for cooling the refrigerant used in the first cooler 31. The first cooler 31 and the second cooler 32 will be described in detail below together with a description of the facility for performing the moisture removal step 13. Further, the natural gas treated in the moisture removal step 13 is subjected to mercury removal in a mercury removal step 14.
The gas-liquid separation step 11, the acid gas removal step 12, the water removal step 13, and the mercury removal step 14 are performed by the pretreatment facility 101 before liquefaction.
Here, the liquid component obtained by gas-liquid separation from NG in the gas-liquid separation step 11 is delivered as a condensate (condensate) after being subjected to the vapor pressure adjustment step 108, through the storage step 109. 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 into the atmosphere.
Further, the acid gas may be subjected to a sulfur recovery step of recovering sulfur contained in the acid gas and a sulfur solidification step to generate sulfur, and then subjected to a sulfur storage step to deliver the sulfur as product sulfur.
The natural gas from which various impurities have been removed by the pretreatment facility 101 is liquefied in the liquefaction step 15 to become liquefied natural gas (L NG). the liquefaction step 15 is performed by the liquefaction facility 102. the liquefaction facility 102 includes a natural gas distillation unit that cools and liquefies a part of the natural gas to remove heavy components, and a main heat exchange unit that cools and liquefies the natural gas from which the heavy components have been removed to, for example, -145 ℃ to-155 ℃ using a main refrigerant (a refrigerant for liquefaction; a mixed refrigerant containing methane, ethane, propane, butane, nitrogen, and the like, or a nitrogen refrigerant).
Further, the liquefaction facility 102 is also provided with a refrigerant cooling facility 105 for cooling the main refrigerant. The refrigerant cooling device 105 includes a compressor 43 for compressing the refrigerant, and the compressor 43 is configured to be driven by a gas turbine.
The L NG liquefied in the liquefaction process 15 is shipped to a L NG tanker (tanker) through, for example, an end flash process 16 in an end flash facility 103 and a storage process 17 in a L NG storage tank (storage facility) 104.
On the other hand, the heavy components removed from the natural gas in the natural gas distillation unit are fractionated into ethane, propane, butane, and a condensate in the rectification step 106, and the ethane is returned to the liquefaction step 15 (liquefaction facility 102). Further, propane and butane may be returned to the liquefaction step 15 (liquefaction facility 102) or shipped as products, similarly to ethane.
The condensate is mixed with the condensate discharged from the vapor pressure adjustment step 108 and then delivered as a product (fig. 1 shows only the flow of delivering the condensate). Further, a part of ethane, propane, and butane is sent to a refrigerant storage step 107 for a refrigerant such as a main refrigerant. The gas generated in the acid gas removal step 12, the end flash step 16, and the storage step 17 is used, for example, as a combustion gas.
Next, the apparatus for performing the water removal step 13 included in the pretreatment apparatus 101 will be described in detail.
As shown in fig. 2, the natural gas containing moisture from which the acid gas is removed in the acid gas removal step 12 is supplied to the adsorption towers 21 to 23 from which moisture is adsorbed and removed, via a supply line (process gas line) 201 provided with a separation drum 29 and a cooling unit 3 described later. The adsorption columns 21 to 23 are filled with, for example, an adsorbent containing moisture of a molecular sieve (molecular sieve). The example shown in fig. 2 has the following configuration: while the adsorption and removal of moisture is performed by one adsorption tower 21 to 23 (moisture removal step 13), the regeneration of the adsorbent by the other adsorption tower 21 to 23 (adsorption tower regeneration step) can be performed by using three adsorption towers 21 to 23. As shown in FIG. 2, a supply line 201 for natural gas branches off from the outlet side of the separation drum 29 and is connected to the inlets of the adsorption towers 21 to 23.
On the other hand, a dry natural gas discharge line 202 is connected to the outlet portion of each of the adsorption towers 21 to 23. These discharge lines 202 join at the downstream side and are connected to the equipment for performing the mercury removal step 14.
Further, a regeneration gas line 203 branches from the discharge line 202 on the downstream side of the merging position, and the regeneration gas line 203 supplies dry natural gas as regeneration gas for performing the regeneration step of the adsorption tower to the outlet side of the adsorption towers 21 to 23. According to the above configuration, the dry natural gas from which moisture has been removed by the adsorption towers 21 to 23 can be used as the regeneration gas.
A regeneration gas line 203 branched from the discharge line 202 is provided with a heating unit 27 including a heat exchanger and the like to heat the regeneration gas (dry natural gas). The heating unit 27 may include a heating furnace, for example.
In addition to these, a recovery/reuse gas line 204 is connected to the inlet of each of the adsorption columns 21 to 23, and the recovery/reuse gas line 204 is used to return the regeneration gas after regeneration of the adsorbent to the upstream side of the adsorption columns 21 to 23. These recovery/reuse gas lines 204 merge at the downstream side, pass through a cooling unit 25 including, for example, an air fin cooler (air fin cooler) for cooling the regeneration gas, and are connected to a separation drum 26 for separating the condensed water and the like from the regeneration gas. The moisture separated from the exhaust gas by the separator drum 26 is discharged to the outside after being subjected to a necessary drainage treatment. On the other hand, the regeneration gas (natural gas) from which the free moisture has been removed is compressed by the compressor 28 and then returned to the upstream side of the first cooler 31. The recovery/reuse gas line 204 may merge the fuel gas.
The branched supply lines 201 connected to the adsorption towers 21 to 23 are provided with on-off valves V1 to V3, and the branched recovery/reuse gas line 204 is provided with on-off valves V1a to V3 a. Further, the discharge lines 202 connected to the adsorption towers 21 to 23 are provided with an on-off valve V4 to an on-off valve V6, and the regeneration gas line 203 is similarly provided with an on-off valve V4a to an on-off valve V6 a.
According to the above configuration, 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 recovery/reuse gas line 204. Further, the piping lines connected to the outlet portion may be switched between the discharge line 202 and the regeneration gas line 203. In fig. 2, the flow of the natural gas in the case where the adsorption tower 21 and the adsorption tower 22 adsorb and remove moisture and the adsorption tower 23 regenerates the adsorbent is shown by a thick line.
In the facility including the moisture removal step 13 having the above-described configuration, the moisture is removed by passing the natural gas containing moisture through the adsorption towers 21 to 23 filled with the moisture adsorbent, as described above. At this time, 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 by the adsorption towers 21 to 23 will be described. In fig. 3, the horizontal axis represents the temperature of the natural gas flowing through the packed bed of the adsorbent, and the vertical axis represents the relative limit treatment flow rate when the treatment flow rate at which the adsorbent per unit volume can be used to reduce the moisture content in the saturated natural gas at 25 ℃ to the limit of 1ppm by weight is defined as 100%. As shown in fig. 3, it is understood that the limit process flow rate decreases as the temperature of the natural gas supplied to the adsorbent becomes higher. Therefore, by lowering the supply temperature of the natural gas supplied to the adsorption columns 21 to 23, the limit treatment flow rate per unit capacity increases, and the filling amount of the adsorbent can be reduced.
In this viewpoint, as shown in fig. 2, the cooling unit 3 is provided in the supply line 201 on the inlet side of the adsorption towers 21 to 23. The cooling section 3 includes: a first cooler 31 for cooling the natural gas by heat exchange with cooling water; and a second cooler 32 for cooling the cooling water used in the first cooler 31 by heat exchange with ethylene glycol water as a non-hydrocarbon refrigerant. The glycol water used in the second cooler 32 is cooled by a cooling mechanism 33 provided outside the cooling unit 3, for example. The cooling mechanism 33 cools ethylene glycol water to 0 to 10 ℃ using Hydrofluorocarbon (HFC) as a fluorine refrigerant, for example.
The natural gas cooled by the cooling unit 3 is separated from the free water by the above-described separation drum 29, and then sent to the predetermined adsorption towers 21 to 23.
The non-hydrocarbon refrigerant used in the second cooler 32 may be water containing pressurized water or pure water, in addition to ethylene glycol water.
The pretreatment facility 101 having the above-described configuration reduces the temperature of the natural gas by the cooling unit 3 before supplying the natural gas to the adsorption towers 21 to 23. The dew point of the cooled natural gas is lowered, and condensed moisture is separated by the separation drum 29 disposed on the inlet side of the adsorption towers 21 to 23. Therefore, the temperature of the natural gas supplied to the adsorption towers 21 to 23 is lowered to reduce the moisture content, and the filling amount of the adsorbent filled in the adsorption towers 21 to 23 can be reduced.
In the natural gas liquefaction apparatus 100 of the present example, the glycol water cooled by the cooling mechanism 33 is also used for cooling the combustion air introduced into the gas turbine 41 that drives the compressor 43 using the refrigerant described with reference to fig. 1. That is, as shown in fig. 2, the glycol water cooled by the HFC in the cooling mechanism 33 is supplied to an air cooler 34 provided together with the gas turbine 41 and used as air for combustion of the fuel gas.
Next, the operation of the apparatus for performing the moisture removal step 13 will be described.
The natural gas which is removed by the acid gas removal step 12 and flows out to the supply line 201 has a temperature in the range of, for example, 40 to 60 ℃. The natural gas is cooled to a temperature in the range of, for example, 20 to 25 ℃ by a first cooler 31 provided on the upstream side of the adsorption towers 21 to 23. As a result, the saturated steam amount of the natural gas decreases, and the remaining water condenses as free water. Free water is removed from the natural gas by a knock out drum 29.
When the natural gas is cooled as described above, even in the case where the natural gas is directly cooled using the glycol water (non-hydrocarbon refrigerant) cooled by the cooling mechanism 33, it is not necessary to provide two coolers (the first cooler 31 and the second cooler 32), and the cooling efficiency is also improved. However, when the natural gas is directly cooled by a low-temperature refrigerant having a temperature range of about 0 to 10 ℃, there are cases where: the natural gas in the cooler is in a supercooled state during the unloading operation of the natural gas or when a failure such as a stop of supply of the gas occurs. As a result, methane or ethane and moisture contained in the natural gas may form hydrates, which may cause clogging of the supply line 201 including the cooler.
Therefore, the cooling unit 3 of the present embodiment adopts an indirect cooling system, that is: the cooling water used for cooling of the natural gas by the first cooler 31 is pre-cooled by the second cooler 32. By such indirect cooling, the temperature of the cooling water used in the first cooler 31 is adjusted to a temperature in the range of, for example, 15 to 20 ℃, and therefore, even when a failure such as a stop of the supply of the natural gas occurs, the natural gas flowing through the supply line 201 can be maintained at a temperature at which clogging does not easily occur without excessively cooling the natural gas.
As described with reference to fig. 2, when the glycol water cooled by the cooling mechanism 33 is also used for cooling the combustion air of the gas turbine 41, the glycol water flows in the vicinity of the gas turbine 41 where combustion is performed at a high temperature. Therefore, the air cooler 34 of the present example cools the combustion air using ethylene glycol water, which is a non-hydrocarbon refrigerant safe even when used in the vicinity of a high-temperature machine.
In this case, if the glycol water is used for direct cooling of the natural gas, a phenomenon may occur in which a part of the natural gas flowing through the supply line 201 leaks to the glycol water side due to aged deterioration of the facility or the like. In this case, the glycol water containing hydrocarbons derived from natural gas may join the glycol water on the air cooler 34 side via the cooling mechanism 33, and safety may be reduced when the system is used in the vicinity of a high-temperature device.
In contrast, the cooling unit 3 of the present example separates the natural gas flowing through the first cooler 31 from the ethylene glycol water flowing through the second cooler 32, and thus leakage of the natural gas component (hydrocarbon component) to the ethylene glycol water side is less likely to occur. As a result, even when ethylene glycol water, which is a non-hydrocarbon refrigerant, is used in the vicinity of a high-temperature apparatus, the safety state can be maintained.
Returning to the description of the treatment of the natural gas, the adsorption tower 21 in which the moisture removal step 13 is performed, the on-off valve V1, the on-off valve V2, the on-off valve V4, and the on-off valve V5 before and after the adsorption tower 22 are in the open state. The natural gas from which the free water has been removed by the separation drum 29 flows into the adsorption towers 21 and 22, comes into contact with the adsorbent to adsorb and remove the water, and then flows out to the discharge line 202.
During the execution of the adsorption tower regeneration step, the regeneration gas line 203 connected to the adsorption tower 23 to be subjected to the step and the on-off valves V6a and V3a of the recovery/reuse gas line 204 are opened. As a result, a part of the dried natural gas from which moisture has been adsorbed and removed is heated by the heating unit 27 and then supplied to the adsorption tower 23. Releasing moisture from the adsorbent in contact with the heated dry natural gas, thereby regenerating the adsorbent. The natural gas containing the moisture desorbed from the adsorbent is cooled by the cooling unit 25, and after the free water is removed by the separation drum 26, the natural gas is pressurized by the compressor 28 and merged with the natural gas flowing through the supply line 201.
According to the natural gas pretreatment facility 101 of the present embodiment, the natural gas supplied to the adsorption towers 21 to 23 is cooled by heat exchange with the cooling water using the first cooler 31, and the adsorption towers 21 to 23 remove moisture contained in the natural gas. The cooling water is cooled by heat exchange with ethylene glycol water, which is a non-hydrocarbon refrigerant cooled to 0 to 10 ℃, using the second cooler 32. Therefore, direct heat exchange with the non-hydrocarbon refrigerant can be avoided, and the natural gas can be cooled appropriately. As a result, even when compared with the case where the natural gas is not cooled, and also compared with the case where the natural gas is cooled only by the cooling water, the filling amount of the adsorbent filled in the adsorption towers 21 to 23 can be reduced.
The cooling unit 3 described with reference to fig. 2 is also suitable for a natural gas liquefaction apparatus 100 provided in a hull 90, and the hull 90 is a floating body floating on the ocean (either the ocean or the lake ocean). Fig. 4 schematically shows an example in which the natural gas liquefaction apparatus 100 described using fig. 1 is provided to a hull 90. For convenience of illustration, the description of the equipment for performing the steam pressure adjustment step 108 and the like, the acid gas incinerator 110, and the like is appropriately omitted.
The natural gas liquefaction apparatus 100 shown in fig. 4 is configured as, for example, a tanker ship in which a mooring facility (turret) 91, a pretreatment facility 101, and a liquefaction facility 102 are provided on a deck of a hull 90, and a storage facility 104 for liquefied natural gas or the like is formed inside the hull 90. For example, the pretreatment facility 101 is provided with facilities for performing the respective steps 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. 1. In the pretreatment facility 101, these facilities are provided so as to be surrounded by an iron structure such as a deck of the hull 90 or a frame 80 supporting the facilities. Reference numeral 81 in fig. 4 denotes a pipe for transporting natural gas between the respective facilities.
Since the liquefaction facility 102 provided in the natural gas liquefaction plant 100 including the above-described configuration handles L NG which is a very low temperature liquid or a liquefaction refrigerant (for example, the above-described main refrigerant), if a failure occurs in which a very low temperature liquid leaks, and the liquid comes into contact with a surrounding iron structure such as a deck or a frame, damage associated with low temperature brittleness may occur.
On the other hand, since the temperature of the natural gas to be treated in the pretreatment facility 101 is about 20 to 60 ℃, even if the natural gas leakage failure occurs, there is no problem of damage to the surrounding iron structure due to low-temperature brittleness.
As illustrated in fig. 2, the pretreatment facility 101 uses cooling water and ethylene glycol water as a non-hydrocarbon refrigerant of 0 to 10 ℃. Thus, extremely low temperature fluids are not processed within the pre-treatment apparatus 101. Therefore, it is not necessary to perform cold-resistant coating on the iron structure surrounding the pretreatment equipment.
In this respect, if it is assumed that the natural gas is cooled using a liquefaction refrigerant such as a main refrigerant used on the liquefaction facility 102 side, it is necessary to pull a pipe for supplying the liquefaction refrigerant from the liquefaction facility 102 to a cooler of the natural gas to the pretreatment facility 101 side. As a result, a cold-resistant coating of a surrounding iron structure is newly required over a wide range of the flow of the liquefaction refrigerant, and this may cause an increase in the construction cost of the natural gas liquefaction apparatus 100. In this respect, according to the natural gas pretreatment facility 101 of the present embodiment, since the natural gas is not cooled by the refrigerant of an extremely low temperature, there is an effect that the range of the cold-resistant coating is limited to the liquefaction facility 102.
Further, even when the natural gas liquefaction plant 100 is installed on land, the cold-resistant coating is not required for the iron structure installed so as to surround the pretreatment plant 101 among the iron structures installed so as to surround the respective plants, and thus the same effect can be obtained.
Further, when the natural gas in the pretreatment facility 101 is cooled using the main refrigerant used on the liquefaction facility 102 side, the following operational restrictions may occur: it is necessary to start the operation of the liquefaction facility 102 as a subsequent facility before the pretreatment facility 101, or to perform the unloading operation when only the pretreatment facility 101 is started without waiting for the liquefaction facility 102 as a subsequent facility.
In this respect, according to the cooling method of the present embodiment, the cooling mechanism 33 for cooling the glycol water can be independently operated without depending on the operating conditions of any other processing equipment, and therefore, there is an effect of avoiding the operating limitation.
In addition, when the cooling unit 3 that cools the supply line 201 is configured only as the first cooler 31, the temperature of the cooling water varies depending on the season, date and time, and installation location, and accordingly, the temperature of the gas flowing through the supply line 201 also varies. As a result, the operation of the equipment may need to be adjusted according to the temperature of the cooling water. In this regard, according to the cooling method of the present embodiment, the temperature of the supply water to the first cooler 31 can be kept constant by the second cooler 32, which has the effect of reducing the adjustment of the operation of the plant.
Further, the cooling of the natural gas using the cooling section 3 including the first cooler 31 and the second cooler 32 is not limited to the case where: is adapted to cool the natural gas supplied to the moisture removal process 13. For example, as shown in fig. 5, the natural gas supplied to the acid gas removal step 12 may be cooled.
Hereinafter, an example in which the cooling unit 3 is provided in the supply line 201 to the absorber 51, and the absorber 51 absorbs and removes the acid gas will be described with reference to fig. 6.
In the example shown in fig. 6, a cooling unit 3 having the same configuration as that of the example shown in fig. 2 is provided for a supply line 201 through which natural gas flows which has passed through a gas-liquid separation step 11, and in the cooling unit 3, an absorption tower 51 for performing an acid gas removal step 12 is provided in place of the absorption tower 21 to the absorption tower 23 which adsorb and remove moisture, and in the absorption tower 51, an absorption liquid containing an amine compound is dispersedly supplied from the tower top side, while cooled natural gas is supplied from the tower bottom side, and as a result, the absorption liquid and the natural gas are brought into convective contact in the absorption tower 51, and carbon dioxide or hydrogen sulfide which is an acid gas that may be solidified in L NG at the time of liquefaction is absorbed and removed from the natural gas into the absorption liquid.
Further, by selecting a predetermined amine absorbent to be used as the absorbent, adjusting the liquid load (the amount of absorbent supplied to the absorber 51 per unit time) and the number of stages of the absorber 51, not only carbon dioxide but also acidic gases such as hydrogen sulfide can be absorbed and removed.
The absorption liquid having absorbed carbon dioxide, hydrogen sulfide, or the like in the absorption tower 51 is transferred to the regeneration tower 52 by a pressure difference, and the absorption liquid in the tower is heated by a reboiler (reboiler)55, whereby the acidic gas absorbed in the absorption liquid is diffused and regenerated. The regenerated absorption liquid is supplied again to the absorption tower 51 by the liquid feeding pump 56.
On the other hand, the various acid gases released from the absorbing liquid are cooled by the cooler 54, subjected to gas-liquid separation by the separation drum 58, and used as combustion gas. The liquid separated from the acid gas by knock-out drum 58 is returned to the regeneration column 52 by pump 57.
By cooling the natural gas to be treated before the acid gas removal step 12, thereby condensing and separating and removing heavy components, the dissolution of heavy components into the absorbent when the natural gas is brought into contact with the absorbent can be reduced, and as a result, the absorption of acid gas in the natural gas into the absorbent in the absorption tower 51 can be stabilized.
By using the cooling water and the glycol water as the refrigerant to the cooling unit 3 instead of using the main refrigerant used on the side of the liquefaction facility 102, the application range of the cold-resistant coating can be made out of the same range as described above, the operation can be performed without depending on the operation state of the liquefaction facility 102, and the supply line 201 can be prevented from being clogged by the generated hydrate.
The cooling unit 3 may be provided on the inlet sides of the adsorption columns 21 to 23 and the adsorption column 51.
As the non-hydrocarbon refrigerant used in the second cooler 32, pressurized water or pure water may be used instead of the above-described glycol water.
Description of the symbols
100: natural gas liquefaction device
101: pretreatment apparatus
102: liquefaction plant
21-23: adsorption tower
31: first cooler
32: second cooler
33: cooling mechanism
34: air cooler
41: turbine wheel
201: supply line

Claims (8)

1. A pretreatment facility for natural gas, which is a pretreatment facility provided with an iron structure around the natural gas and which performs pretreatment for removing impurities contained in the natural gas, characterized by comprising:
an adsorption tower connected to a process gas line for supplying natural gas containing moisture, the adsorption tower being filled with an adsorbent for adsorbing and removing moisture in the natural gas supplied from the process gas line;
a first cooler which is provided in the process gas line on the inlet side of the adsorption tower and cools the natural gas supplied to the adsorption tower by heat exchange with cooling water; and
and a second cooler for cooling the cooling water by heat exchange with a non-hydrocarbon refrigerant cooled to a temperature in the range of 0 ℃ to 10 ℃.
2. The plant for the pretreatment of natural gas according to claim 1,
the pretreatment equipment is arranged in a natural gas liquefaction device, and the natural gas liquefaction device comprises liquefaction equipment for liquefying the pretreated natural gas.
3. The plant for the pretreatment of natural gas according to claim 2,
in the case where an iron structure coated with cold resistance is provided around the liquefaction facility, the iron structure around the pretreatment facility is not coated with cold resistance.
4. The plant for the pretreatment of natural gas according to claim 2,
the liquefaction plant is used for liquefaction of the natural gas, and includes a compressor driven by a gas turbine that compresses a liquefaction refrigerant that becomes a gas, and the non-hydrocarbon refrigerant is also used for cooling air for combustion of the fuel gas introduced into the gas turbine.
5. The plant for the pretreatment of natural gas according to claim 2,
the natural gas liquefaction device is arranged on a floating body floating on the ocean.
6. The natural gas pretreatment device according to claim 1, characterized by comprising:
an absorption tower provided upstream of the adsorption tower, for bringing the natural gas into contact with an absorption liquid, absorbing the acidic gas contained in the natural gas with the absorption liquid, and removing the acidic gas
The process gas line is connected to the absorption column instead of the adsorption column, and the first cooler cools the natural gas supplied to the absorption column.
7. The plant for the pretreatment of natural gas according to claim 1,
the non-hydrocarbon refrigerant is cooled by an external cooling mechanism.
8. The plant for the pretreatment of natural gas according to claim 1,
the non-hydrocarbon refrigerant is glycol water or water.
CN201880078105.5A 2018-05-23 2018-05-23 Pretreatment equipment for natural gas Pending CN111447986A (en)

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
PCT/JP2018/019869 WO2019224951A1 (en) 2018-05-23 2018-05-23 Natural gas pre-processing facility

Publications (1)

Publication Number Publication Date
CN111447986A true CN111447986A (en) 2020-07-24

Family

ID=68616817

Family Applications (1)

Application Number Title Priority Date Filing Date
CN201880078105.5A Pending CN111447986A (en) 2018-05-23 2018-05-23 Pretreatment equipment for natural gas

Country Status (3)

Country Link
KR (1) KR102248010B1 (en)
CN (1) CN111447986A (en)
WO (1) WO2019224951A1 (en)

Families Citing this family (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN112922580B (en) * 2019-12-06 2023-04-07 中国石油天然气股份有限公司 Natural gas processing system, control method thereof and natural gas transmission system
CN117925289B (en) * 2024-03-25 2024-06-07 山西易高煤层气有限公司 Wet natural gas drying equipment for natural gas liquefaction pretreatment

Citations (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN202470622U (en) * 2012-02-09 2012-10-03 杭州杭氧股份有限公司 Purifying, separating and liquefying system for nitrogen-oxygen-containing coal-mine gas

Family Cites Families (13)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
FR2848218B1 (en) * 2002-12-10 2005-01-28 Inst Francais Du Petrole PROCESS FOR DEACIDIFYING AND DEHYDRATING A NATURAL GAS
EP1792130B1 (en) * 2004-08-06 2017-04-05 BP Corporation North America Inc. Natural gas liquefaction process
CN101796359B (en) 2007-07-09 2012-05-23 液化天然气技术有限公司 Method and system for producing liquid-phase natural gas
US8435325B2 (en) 2008-10-23 2013-05-07 Hitachi, Ltd. Method and device for removing CO2 and H2S
EP2381198B1 (en) * 2010-04-21 2017-03-15 General Electric Technology GmbH Method for separating carbon dioxide from flue gas of combustion plants
KR101295446B1 (en) * 2011-12-02 2013-08-16 에스티엑스조선해양 주식회사 Fuel gas supply system of LNG carrier
KR101535759B1 (en) 2014-12-15 2015-07-10 현대중공업 주식회사 A Fuel Gas Supply System of Liquefied Natural Gas
KR20160134348A (en) * 2015-05-15 2016-11-23 대우조선해양 주식회사 The System and Method for Carbon Dioxide Separation from Natural Gas before Gas Liquefaction Process
US10443927B2 (en) * 2015-09-09 2019-10-15 Black & Veatch Holding Company Mixed refrigerant distributed chilling scheme
US20170097189A1 (en) * 2015-10-06 2017-04-06 Ashley R. Guy Modularization Of A Hydrocarbon Processing Plant
US11224884B2 (en) 2015-11-12 2022-01-18 Cornell University Alternating current electrospray manufacturing and products thereof
US10781752B2 (en) * 2016-03-23 2020-09-22 Chiyoda Corporation Inlet air cooling system and inlet air cooling method for gas turbine
KR101883878B1 (en) * 2016-08-22 2018-08-01 한양대학교 산학협력단 Apparatus and method for removing acidic gas containing natural gas

Patent Citations (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN202470622U (en) * 2012-02-09 2012-10-03 杭州杭氧股份有限公司 Purifying, separating and liquefying system for nitrogen-oxygen-containing coal-mine gas

Also Published As

Publication number Publication date
KR102248010B1 (en) 2021-05-06
KR20200073290A (en) 2020-06-23
WO2019224951A1 (en) 2019-11-28

Similar Documents

Publication Publication Date Title
CA2498195C (en) Configurations and methods of acid gas removal
US9638019B2 (en) Offshore processing method and system
US7192468B2 (en) Configurations and method for improved gas removal
CA2482159C (en) Configurations and methods for improved acid gas removal
US20110296871A1 (en) Method and apparatus for separating nitrogen from a mixed stream comprising nitrogen and methane
EA009089B1 (en) Configurations and methods of acid gas removal
CN102438726B (en) Method for processing a natural load gas for obtaining a natural processed gas and a reduction in c5+ hydrocarbons, and associated installation
US9844751B2 (en) Method and apparatus for removing absorbable gases from pressurized industrial gases contaminated with absorbable gases, without supplying cooling energy
NO20160962A1 (en) Method and apparatus for dehydration of a hydrocarbon gas
KR101883878B1 (en) Apparatus and method for removing acidic gas containing natural gas
US9964034B2 (en) Methods for producing a fuel gas stream
US10619114B2 (en) Pretreatment equipment for hydrocarbon gas to be liquefied and shipping base equipment
CN111447986A (en) Pretreatment equipment for natural gas
JP6357155B2 (en) A method for optimizing condensable component removal from fluids
US11377401B2 (en) Efficiency of a gas conditioning system via hydrate inhibitor injection
US10393015B2 (en) Methods and systems for treating fuel gas
US9676629B2 (en) Helium enhanced heat transfer in adsorptive liquid or gas phase argon purification processes
KR102132073B1 (en) gas treatment system and offshore plant having the same
US20240350971A1 (en) Methods for optimizing gas and fluid processing
WO2020021633A1 (en) Natural gas treatment device and natural gas treatment method
KR20160062422A (en) Glycol Dehydration System
KR100873376B1 (en) Concentration device for neon and / or helium gas
WO2012131742A1 (en) Process for the reconcentration of gaseous mixtures deydrating liquids

Legal Events

Date Code Title Description
PB01 Publication
PB01 Publication
SE01 Entry into force of request for substantive examination
SE01 Entry into force of request for substantive examination