WO2020157830A1 - 二酸化炭素ガス分離方法及び二酸化炭素ガス分離装置 - Google Patents
二酸化炭素ガス分離方法及び二酸化炭素ガス分離装置 Download PDFInfo
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- WO2020157830A1 WO2020157830A1 PCT/JP2019/002985 JP2019002985W WO2020157830A1 WO 2020157830 A1 WO2020157830 A1 WO 2020157830A1 JP 2019002985 W JP2019002985 W JP 2019002985W WO 2020157830 A1 WO2020157830 A1 WO 2020157830A1
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- Prior art keywords
- gas
- carbon dioxide
- pressure
- separation membrane
- dioxide gas
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- 238000000926 separation method Methods 0.000 title claims abstract description 168
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 title claims abstract description 166
- 229910002092 carbon dioxide Inorganic materials 0.000 title claims abstract description 86
- 239000001569 carbon dioxide Substances 0.000 title claims abstract description 74
- 239000007789 gas Substances 0.000 claims abstract description 278
- 239000012528 membrane Substances 0.000 claims abstract description 120
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 claims abstract description 106
- 238000010438 heat treatment Methods 0.000 claims description 43
- 238000009833 condensation Methods 0.000 claims description 21
- 230000005494 condensation Effects 0.000 claims description 21
- 238000007711 solidification Methods 0.000 claims description 12
- 230000008023 solidification Effects 0.000 claims description 12
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 claims description 4
- 239000001307 helium Substances 0.000 claims description 4
- 229910052734 helium Inorganic materials 0.000 claims description 4
- SWQJXJOGLNCZEY-UHFFFAOYSA-N helium atom Chemical compound [He] SWQJXJOGLNCZEY-UHFFFAOYSA-N 0.000 claims description 4
- 229910001873 dinitrogen Inorganic materials 0.000 claims description 3
- 239000003345 natural gas Substances 0.000 abstract description 49
- 235000011089 carbon dioxide Nutrition 0.000 description 8
- 238000000034 method Methods 0.000 description 7
- 238000011144 upstream manufacturing Methods 0.000 description 5
- 238000010586 diagram Methods 0.000 description 4
- 230000000694 effects Effects 0.000 description 4
- 229910021536 Zeolite Inorganic materials 0.000 description 3
- HNPSIPDUKPIQMN-UHFFFAOYSA-N dioxosilane;oxo(oxoalumanyloxy)alumane Chemical compound O=[Si]=O.O=[Al]O[Al]=O HNPSIPDUKPIQMN-UHFFFAOYSA-N 0.000 description 3
- 230000014509 gene expression Effects 0.000 description 3
- 229930195733 hydrocarbon Natural products 0.000 description 3
- 150000002430 hydrocarbons Chemical class 0.000 description 3
- 239000012535 impurity Substances 0.000 description 3
- 239000000047 product Substances 0.000 description 3
- 239000010457 zeolite Substances 0.000 description 3
- 239000004215 Carbon black (E152) Substances 0.000 description 2
- 238000004364 calculation method Methods 0.000 description 2
- 230000006866 deterioration Effects 0.000 description 2
- 239000003949 liquefied natural gas Substances 0.000 description 2
- 239000012466 permeate Substances 0.000 description 2
- 238000004088 simulation Methods 0.000 description 2
- 238000011282 treatment Methods 0.000 description 2
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 2
- 239000000919 ceramic Substances 0.000 description 1
- 230000000052 comparative effect Effects 0.000 description 1
- 239000010779 crude oil Substances 0.000 description 1
- 230000003247 decreasing effect Effects 0.000 description 1
- 238000007599 discharging Methods 0.000 description 1
- 239000012530 fluid Substances 0.000 description 1
- 238000009472 formulation Methods 0.000 description 1
- 239000007924 injection Substances 0.000 description 1
- 238000002347 injection Methods 0.000 description 1
- 229910010272 inorganic material Inorganic materials 0.000 description 1
- 239000011147 inorganic material Substances 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
- 238000012423 maintenance Methods 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 239000002184 metal Substances 0.000 description 1
- 239000000203 mixture Substances 0.000 description 1
- 238000011328 necessary treatment Methods 0.000 description 1
- 239000002994 raw material Substances 0.000 description 1
- 238000000638 solvent extraction Methods 0.000 description 1
- 238000000859 sublimation Methods 0.000 description 1
- 230000008022 sublimation Effects 0.000 description 1
- 239000000758 substrate Substances 0.000 description 1
Images
Classifications
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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
- B01D53/22—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 diffusion
- B01D53/228—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 diffusion characterised by specific membranes
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D71/00—Semi-permeable membranes for separation processes or apparatus characterised by the material; Manufacturing processes specially adapted therefor
- B01D71/02—Inorganic material
- B01D71/028—Molecular sieves
- B01D71/0281—Zeolites
-
- 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
- C10L3/104—Carbon dioxide
-
- 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
- B01D53/22—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 diffusion
- B01D2053/221—Devices
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D2256/00—Main component in the product gas stream after treatment
- B01D2256/24—Hydrocarbons
- B01D2256/245—Methane
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D2257/00—Components to be removed
- B01D2257/50—Carbon oxides
- B01D2257/504—Carbon dioxide
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D63/00—Apparatus in general for separation processes using semi-permeable membranes
- B01D63/06—Tubular membrane modules
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D71/00—Semi-permeable membranes for separation processes or apparatus characterised by the material; Manufacturing processes specially adapted therefor
- B01D71/02—Inorganic material
- B01D71/028—Molecular sieves
-
- 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
- C10L2290/548—Membrane- or permeation-treatment for separating fractions, components or impurities during preparation or upgrading of a fuel
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02C—CAPTURE, STORAGE, SEQUESTRATION OR DISPOSAL OF GREENHOUSE GASES [GHG]
- Y02C20/00—Capture or disposal of greenhouse gases
- Y02C20/40—Capture or disposal of greenhouse gases of CO2
Definitions
- the present invention relates to a carbon dioxide gas separation method and a carbon dioxide gas separation device for separating carbon dioxide gas in a gas to be treated.
- Natural gas which is a hydrocarbon gas produced from the wellhead, is subjected to a pretreatment for removing impurities using various kinds of treatment equipment.
- the natural gas from which impurities have been removed may be shipped as it is via a pipeline, or may be liquefied by a liquefaction treatment facility at a subsequent stage to obtain LNG (Liquidized Natural Gas).
- the impurities contained in natural gas include, for example, those containing a relatively large amount of carbon dioxide (CO 2 ) gas, and in order to obtain product gas as a raw material for pipeline gas and liquefied natural gas, CO 2 gas is used. Need to be removed.
- a CO 2 gas separation device that separates CO 2 gas from natural gas includes a CO 2 gas separation module including an inorganic separation membrane composed of zeolite or the like as shown in Patent Document 1, for example. Then, a natural gas as a gas to be processed is supplied to the CO 2 gas separation module to allow CO 2 to pass through the inorganic separation membrane, thereby separating the hydrocarbon gas that cannot pass through the inorganic separation membrane.
- the present invention has been made under such a background, and an object thereof is to provide a technique for stably separating carbon dioxide gas in a high-pressure gas to be processed by using a separation membrane.
- Carbon dioxide gas separation method of the present invention carbon dioxide gas in the gas to be treated is permeated from the primary side to the secondary side of the separation membrane provided in the separation membrane module, and the carbon dioxide gas in the gas to be treated is In the carbon dioxide gas separation method for reducing To the separation membrane module in a state of standby pressure lower than the operating pressure when permeating carbon dioxide gas to the separation membrane, before supplying the gas to be treated at a supply pressure higher than the standby pressure, In order to maintain the temperature of the gas to be treated where the pressure drop occurs at a temperature higher than the condensation temperature of carbon dioxide gas or the solidification temperature of carbon dioxide gas, the standby pressure is supplied by supplying a preliminary boosted gas to the primary side of the separation membrane.
- a step of supplying a gas to be treated to the separation membrane module to raise the pressure of the separation membrane module to the operating pressure to reduce carbon dioxide gas in the gas to be treated is included. ..
- the carbon dioxide gas separation method may have the following features.
- the separation membrane is an inorganic separation membrane.
- the gas to be treated is supplied to the separation membrane module after being heated by a heating unit.
- the pressure difference between the operating pressure and the standby pressure is 0.5 MPa or more.
- the concentration of carbon dioxide gas in the gas to be treated is 30% or more and less than 100% in terms of molar ratio.
- E When the operating pressure is P Ope , the vapor pressure of carbon dioxide gas at 20° C. is P Vap , and the concentration (molar ratio) of carbon dioxide gas in the gas to be treated is C CO2 ,
- the pressure should be equal to or higher than P Pre defined by the following formulas (1) to (3).
- the preliminary boosted gas is at least one gas selected from nitrogen gas, helium gas, and methane gas.
- the carbon dioxide gas separation device of the present invention is a carbon dioxide gas separation device for separating carbon dioxide gas contained in a gas to be treated, A separation membrane module comprising a separation membrane, by permeating carbon dioxide gas from the primary side to the secondary side of the separation membrane, a separation membrane module for reducing carbon dioxide gas in the gas to be treated, A processed gas supply path which is connected to the space on the primary side in the separation membrane module and supplies a processed gas containing carbon dioxide gas, A carbon dioxide gas flow path, which is connected to the space on the secondary side in the separation membrane module and through which the carbon dioxide gas that has permeated the separation membrane flows out, A non-permeable gas channel connected to the space on the primary side and outflowing the non-permeable gas after the carbon dioxide gas is separated, A pre-pressurized gas supply path for supplying a pre-pressurized gas to the primary side of the separation membrane in the separation membrane module, To the separation membrane module in a state of standby pressure lower than the operating pressure when permeating carbon dioxide gas to the separation membrane, before
- the pressure on the primary side of the separation membrane is raised to the preliminary pressure before the supply of the gas to be treated is started. Therefore, when the high-pressure gas to be processed is supplied, it is possible to suppress a rapid temperature decrease of the gas to be processed and to maintain the condensation temperature of the carbon dioxide gas or the temperature above the solidification temperature.
- natural gas gas to be treated
- pretreatment 101 for example, gas-liquid separation and water removal.
- CO 2 gas separation 102 for removing carbon dioxide (CO 2 ) is performed.
- the natural gas from which the CO 2 gas has been removed may be supplied to a consumer, for example, via a pipeline, or may be liquefied 103 to become liquefied natural gas (LNG) and shipped via a storage 104.
- LNG liquefied natural gas
- FIG. 2 is a configuration diagram showing a CO 2 gas separation device used for the CO 2 gas separation 102.
- the CO 2 gas separation device includes a separation membrane module 1, and in the separation membrane module 1, for example, an inorganic separation membrane 100 that is a separation membrane that permeates and separates CO 2 gas is provided.
- an inorganic separation membrane 100 for example, an inorganic material having high resistance to heavy hydrocarbons, for example, a DDR type zeolite membrane is adopted.
- the specific structure of the inorganic separation membrane 100 is not limited to a specific type, but an example of using a tubular member having a DDR type zeolite membrane formed on the surface of a pipe-shaped substrate made of, for example, porous ceramics is used. Can be mentioned. Then, a large number of tubular members on which the inorganic separation membrane 100 is formed are housed in a metal body, and the primary space through which natural gas flows and the CO 2 gas separated from the natural gas flow through.
- the separation membrane module 1 is configured by partitioning the secondary side space.
- the separation membrane module 1 is connected to a natural gas supply path (process gas supply path) 10 for supplying natural gas to the space on the primary side of the inorganic separation membrane 100.
- Reference numeral 21 provided in the natural gas supply passage 10 is a heating unit.
- a product gas discharge path (non-permeable gas flow path) for discharging natural gas (non-permeable gas) after the CO 2 gas has been separated, which flows through the space on the primary side. 11 is connected.
- the separation membrane module 1 also includes a CO 2 gas discharge passage (permeation gas passage) 12 that discharges a permeated gas (for example, CO 2 gas) that has permeated to the secondary side of the inorganic separation membrane 100.
- V0 is an opening/closing valve
- V1 is a flow rate adjusting valve
- V2 and V3 are pressure adjusting valves.
- Such a CO 2 gas separation device may be stopped for maintenance or the like, the fluid inside may be discharged, and after the necessary treatment is performed, the inside may stand by at atmospheric pressure.
- the natural gas supplied from the well side is supplied at a high pressure of about 15 MPa, for example.
- the gas to be treated is a gas having a pressure higher than the standby pressure
- the natural gas passes through the flow rate control valve V1 and suddenly enters a low-pressure atmosphere. Is released.
- the temperature drops according to the pressure difference due to the Joule-Thomson effect.
- high-pressure natural gas with a pressure of about 15 MPaG is released into the atmosphere (pressure ⁇ 0.1 MPa)
- the temperature may drop to a temperature at which the CO 2 gas contained in the natural gas liquefies or solidifies.
- the separation membrane module 1 for example, liquefied CO 2 or dry ice adheres to the inorganic separation membrane 100, and the permeation performance of the inorganic separation membrane 100 deteriorates.
- a method of heating the natural gas to a high temperature using the heating unit 21 and supplying the natural gas to the separation membrane module 1 can be considered.
- the heating unit 21 is provided for controlling the dew point of water contained in natural gas
- the heating temperature required for suppressing liquefaction and solidification of CO 2 gas is the heating temperature for dew point control.
- the temperature is too high compared to. For this reason, it becomes necessary to prepare a heating unit 21 having an over-specification heating capacity that is not necessary during normal operation, because of the high-temperature heating operation that is performed only at startup.
- the pre-pressurized gas is supplied to the separation membrane module 1 before the natural gas is supplied. Then, preliminary boosting is performed to make the internal pressure higher than the standby pressure. As a result, the pressure difference between the supplied natural gas and the separation membrane module 1 is reduced, and a rapid decrease in the temperature of the natural gas is suppressed.
- a preliminary boosted gas supply passage 13 is connected to the natural gas supply passage 10 downstream of the flow rate control valve V1.
- the valve V4 provided in the preliminary boosted gas supply passage 13 is a pressure reducing valve.
- the valve V4 may be a pressure control valve.
- the pre-pressurized gas for example, nitrogen (N 2 ) gas can be used.
- the connection position of the pre-pressurized gas supply passage 13 is on the downstream side of the on-off valve V0, which is closed at the time of pre-pressurization described later, and may be the primary side of the inorganic separation membrane 100. As shown, it may be on the upstream side of the flow rate control valve V1.
- FIGS. 3 and 4 a state in which the valve is opened is shown in white and is denoted by a symbol O, and a state in which the valve is closed is denoted by diagonal lines and is denoted by a symbol S.
- the valve closed state means a state in which the open/close valve V0, the pressure control valves V2, V3 and the pressure reducing valve V4 are completely closed
- the open state means a state in which the open/close valve V0 is open, the pressure control valve V2, It shows a state in which the pressure is adjusted by opening V3 and the pressure reducing valve V4.
- N 2 gas pre-pressurized gas
- a preliminary pressure between the standby pressure and the operating pressure for permeating CO 2 gas through the inorganic separation membrane for example, a preliminary pressure, for example, It is adjusted to 8 MPaG.
- the separation membrane module 1 when the separation membrane module 1 is started up without performing pre-pressurization, it is required to keep the temperature inside the separation membrane module 1 below the condensation temperature of CO 2 gas at the operating pressure.
- the heating energy [MW] of the heating unit 21 for heating the preliminary pressure that can reduce the heating energy of the heating unit 21 by 20% is set as a target. The target may be increased or decreased according to need, and the following examination may be performed.
- the gas to be treated was a mixed gas of CO 2 gas and CH 4 gas, and the supply temperature of each gas was 20° C. Further, it is assumed that there is no pressure loss in the flow rate control valve V1, and the pressure P1 of the gas to be treated and the pressure P2 in the separation membrane module 1 are equal with the open/close valve V0 open. Further, under conditions where P1 and P2 are below the critical pressure of CO 2 gas, the condensation temperature at P1 and P2 is the condensation point of CO 2 gas, and above the critical pressure, the critical temperature is the condensation point of CO 2 gas. did. Under the pressure conditions where P1 and P2 are equal to or lower than the triple point pressure of CO 2 , the condensation point and the condensation temperature are to be read as the sublimation point and the solidification temperature, respectively.
- the partial pressure (molar ratio) of the CO 2 gas is set to 40, 50, 60, 70, 80, 90 and 100%, and the operating pressure is adjusted in the range of 8 MPaG to 31 MPG for each gas to be treated.
- the preliminary pressure required to reduce the heating energy by 20% was calculated by simulation using the process simulator PRO/II (manufactured by Aveva).
- FIG. 6 shows the above-mentioned simulation results, and is a characteristic diagram showing the operating pressure P Ope when performing the separation process in the separation membrane module 1 on the horizontal axis and the preliminary pressure P Pre on the vertical axis.
- FIG. 7 is a graph in which the vertical axis represents the natural logarithm of the preliminary pressure P Pre .
- the horizontal axis is 1/[(P Ope /P Vap ) 2 +(P Ope /P Vap ) 3 ](P Vap : CO 2 vapor pressure at 20° C.).
- step S11 it is determined whether the set operating pressure is 0.5 MPaG or more (step S11).
- step S11; Yes the preliminary pressure is calculated by the above equation (1) (step S12).
- step S13; Yes the preliminary pressure and the operating pressure are compared, and when the preliminary pressure is less than the operating pressure (step S14; Yes). ) To the preliminary pressure.
- step S11; No When the operating pressure is less than 0.5 MPaG (step S11; No), when the preliminary pressure is less than 0.5 MPaG (step S13; No), the preliminary pressure and the operating pressure are compared, and the preliminary pressure is equal to or more than the operating pressure. In this case (step S14; No), preliminary boosting is not required. By determining whether or not the preliminary boosting is necessary according to this flowchart, the preliminary boosting can be executed only when necessary.
- the separation membrane module 1 when separating CO 2 gas in high-pressure natural gas using the separation membrane module 1 provided with the inorganic separation membrane 100, the separation membrane module 1 before starting the supply of natural gas.
- the preliminary boosted gas is supplied to the primary side of the inorganic separation membrane 100 to boost the preliminary pressure between the standby pressure and the operating pressure. Therefore, it is possible to suppress the sudden temperature decrease of the natural gas when the pressure of the separation membrane module 1 is raised to the operating pressure by starting the supply of the high-pressure natural gas. Therefore, it is possible to suppress the condensation and solidification of CO 2 gas in the separation membrane module 1, and to suppress the deterioration of the performance of the separation membrane module 1.
- the pre-pressurized gas may be supplied to the primary side of the inorganic separation membrane 100 when performing pre-pressurization, and may be upstream of the flow rate control valve V1 or upstream of the heating unit 21.
- this pre-pressurization pressure can be easily set to an appropriate value by using the above-mentioned formula (1).
- the pressure difference between the operating pressure and the standby pressure is 0.5 MPa or more, CO 2 gas is likely to be condensed and solidified. Therefore, the present invention can be applied to obtain a great effect.
- the concentration of CO 2 gas in the gas to be treated is preferably 30% or more and less than 100% in terms of molar ratio, and more preferably 40% or more and less than 100% in terms of molar ratio.
- the pre-pressurized gas is a non-condensable gas as long as it does not affect the membrane performance of the inorganic separation membrane 100, and for example, helium gas or methane gas can be used.
- the present invention may be applied to a CO 2 gas separation device that separates CO 2 gas using an organic separation membrane instead of the inorganic separation membrane.
- the pressure of pre-pressurization for maintaining the temperature of the gas at a temperature higher than the condensation temperature was calculated by PRO/II (manufactured by Aveva).
- the gas to be treated is a mixed gas in which CO 2 gas and CH 4 gas are mixed at a molar ratio of 9:1 and is supplied to the CO 2 gas separation device at a flow rate of 50 Kg-mol/hour at 60° C. and 15 MPaG. Shall be done.
- the upstream side of the on-off valve V0, the downstream side of the heating unit 21 and the upstream side of the flow rate control valve V1, and the inside of the separation membrane module 1 are respectively St. 1, St. 2 and St. 3 (see FIG. 2).
- the atmospheric pressure is 0 MPaG.
- the temperature change of the gas to be treated was calculated when the gas to be treated was not heated by the heating unit and the startup of the CO 2 gas separation device was performed without supplying the pre-pressurized gas.
- Table 1 shows points St. 1, St. 2 and St. 3 shows the temperature, pressure and flow rate of the gas to be treated at each point of 3.
- Table 1 As shown in Table 1, when the gas to be treated supplied at 60° C. and 15 MPaG is supplied into the separation membrane module 1, it is cooled to ⁇ 90° C. due to the Joule-Thomson effect. This temperature, CO 2 gas condensation temperature (for example CO 2 gas 30%, CH 4 70% gas; - 46 ° C.) below the, CO 2 gas will condense.
- CO 2 gas condensation temperature for example CO 2 gas 30%, CH 4 70% gas; - 46 ° C.
- the thermal energy required in the heating unit 21 was calculated in the case of suppressing the condensation of the CO 2 gas at the point P3 by heating the gas to be processed in the heating unit 21 without performing pre-pressurization.
- the temperature at which condensation can be prevented at the point P3 was set at the condensation point +10K (46.2950° C.) at the operating pressure of 10 MPaG.
- Table 2 shows the point St. when the condensation of the CO 2 gas is suppressed by heating the gas to be processed in the heating unit 21.
- St. 2 and St. 3 shows the temperature, pressure and flow rate of the gas to be treated at each point of 3.
- Example 3 shows the points St. 3 when the preliminary pressure is set to 8 MPaG. 1, St. 2 and St. 3 shows changes in pressure and temperature. [Table 3] As shown in Table 3, when the preliminary pressure is set to 8 MPaG, in order to maintain the temperature of the point P3 at 46.250° C. when the gas to be processed is supplied, the gas to be processed is heated by the heating unit 21. It needs to be heated to 83.049°C.
- the thermal energy added to the gas to be processed by the heating unit 21 is 1.2196 M ⁇ KJ/hour, and the thermal energy required by the heating unit 21 is approximately It was reduced by 60%. Therefore, it can be said that by applying the present invention, it is possible to suppress a rapid temperature decrease of natural gas when the pressure of the separation membrane module 1 is raised to the operating pressure. Furthermore, even in the CO 2 gas separation device that heats and supplies the gas to be treated, the required thermal energy is reduced as compared with the case where the condensation and solidification of the CO 2 gas is suppressed only by heating using the heating unit 21. You can say that you can.
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Abstract
Description
前記分離膜に二酸化炭素ガスを透過させる際の運転圧力よりも低圧の待機圧力の状態にある前記分離膜モジュールに対して、当該待機圧力よりも高い供給圧力で被処理ガスを供給する前に、圧力低下が生じる被処理ガスの温度を二酸化炭素ガスの凝縮温度、又は二酸化炭素ガスの固化温度よりも高い温度に維持するため、前記分離膜の一次側に予備昇圧ガスを供給して前記待機圧力と運転圧力との間の予備圧力まで昇圧する工程と、
その後、前記分離膜モジュールに被処理ガスを供給して当該分離膜モジュールの圧力を前記運転圧力まで上昇させ、前記被処理ガス中の二酸化炭素ガスを低減する工程と、を含むことを特徴とする。
(a)前記分離膜は無機分離膜であること。
(b)前記被処理ガスは、加熱部にて加熱された後、前記分離膜モジュールに供給されること。
(c) 前記運転圧力と待機圧力との圧力差は、0.5MPa以上であること。
(d) 前記被処理ガス中の二酸化炭素ガスの濃度は、モル比で30%以上、100%未満であること。
(e) 前記予備圧力は、前記運転圧力をPOpe、20℃における二酸化炭素ガスの蒸気圧をPVap、被処理ガス中の二酸化炭素ガスの濃度(モル比)をCCO2としたときに、下記の式(1)~式(3)で規定されるPPre以上の圧力であること。
ln(PPre)=a×[1/〔(POpe/PVap)2+(POpe/PVap)3〕]+b 式(1)
a=0.1318×(CCO2)-13.63 式(2)
b=0.8886×ln(CCO2)-2.372 式(3)
(f) 前記予備昇圧ガスは、窒素ガス、ヘリウムガス及びメタンガスから選ばれる少なくとも一つのガスであること。
分離膜を備え、前記分離膜の一次側から二次側に二酸化炭素ガスを透過させることにより、前記被処理ガス中の二酸化炭素ガスを低減する分離膜モジュールと、
前記分離膜モジュール内の前記一次側の空間に接続され、二酸化炭素ガスを含む被処理ガスを供給する被処理ガス供給路と、
前記分離膜モジュール内の前記二次側の空間に接続され、前記分離膜を透過した二酸化炭素ガスが流出する二酸化炭素ガス流路と、
前記一次側の空間に接続され、前記二酸化炭素ガスが分離された後の非透過ガスが流出する非透過ガス流路と、
前記分離膜モジュールにおける分離膜の一次側に予備昇圧ガスを供給する予備昇圧ガス供給路と、を備え、
前記分離膜に二酸化炭素ガスを透過させる際の運転圧力よりも低圧の待機圧力の状態にある前記分離膜モジュールに対して、当該待機圧力よりも高い供給圧力で被処理ガスを供給する前に、圧力低下が生じる被処理ガスの温度を二酸化炭素ガスの凝縮温度、又は二酸化炭素ガスの固化温度よりも高い温度に維持するため、前記予備昇圧ガス供給路から予備昇圧ガスを供給して、前記一次側の空間の圧力を前記待機圧力と運転圧力との間の予備圧力まで昇圧することを特徴とする。
圧力の高いガスが圧力の低い雰囲気中に放出されると、ジュールトムソン効果により、圧力差に応じて温度が低下する。例えば圧力15MPaG程度の高圧の天然ガスを大気雰囲気(圧力≒0.1MPa)に放出したときには、天然ガス中に含まれるCO2ガスが液化したり固化してしまう温度まで低下することがある。その結果、分離膜モジュール1内において、例えば液化したCO2やドライアイスが無機分離膜100に付着してしまい、無機分離膜100の透過性能が低下してしまう。
ln(PPre)=a×[1/〔(POpe/PVap)2+(POpe/PVap)3〕]+b 式(1)
a=0.1318×(CCO2)-13.63 式(2)
b=0.8886×ln(CCO2)-2.372 式(3)
予備昇圧ガスは、予備昇圧を行うときに無機分離膜100の一次側に供給されればよく、流量調節バルブV1の上流側であってもよく、加熱部21の上流側であってもよい。
また本発明は、無機分離膜に代えて有機分離膜によりCO2ガスを分離するCO2ガス分離装置に適用してもよい。
図2に示すCO2ガス分離装置にて被処理ガス中のCO2ガスを分離したときのCO2ガス分離装置内の被処理ガスの温度変化や、圧力変化、分離膜モジュール1内の被処理ガスの温度を凝縮温度より高い温度に維持するための予備昇圧の圧力をPRO/II(アヴェバ社製)により計算した。なお被処理ガスは、CO2ガスとCH4ガスとが9:1のモル比で混合された混合ガスであり、60℃、15MPaGで50Kg-モル/時の流量でCO2ガス分離装置に供給されるものとする。CO2ガス分離装置における開閉バルブV0よりも上流側、加熱部21よりも下流側で流量調節バルブV1よりも上流側、及び分離膜モジュール1内を夫々地点St.1、St.2、及びSt.3とする(図2参照)。また大気圧を0MPaGとしている。
まず被処理ガスを加熱部にて加熱せず、予備昇圧ガスを供給せずにCO2ガス分離装置のスタートアップを行った場合の被処理ガスの温度変化を計算した。表1は、地点St.1、St.2、及びSt.3の各地点の被処理ガスの温度、圧力及び流量を示す。
[表1]
表1に示すように60℃、15MPaGで供給された被処理ガスは分離膜モジュール1中に供給されるとジュールトムソン効果に伴い-90℃まで冷却されてしまう。この温度は、CO2ガスの凝縮温度(例えばCO2ガス30%、CH4ガス70%;-46℃)を下回り、CO2ガスが凝縮してしまう。
次いで予備昇圧を行わず、加熱部21にて被処理ガスを加熱することで地点P3におけるCO2ガスの凝縮を抑制する場合において加熱部21にて必要な熱エネルギーを計算した。なお地点P3にて凝縮を防ぐことができる温度は、運転圧力10MPaGにおける凝縮点+10K(46.2950℃)とした。表2に加熱部21にて被処理ガスを加熱することでCO2ガスの凝縮を抑制する場合の地点St.1、St.2、及びSt.3の各地点の被処理ガスの温度、圧力及び流量を示す。
[表2]
表2に示すように地点P2の温度が132.337℃になるように加熱することで、大気圧における地点P3の温度を46.295℃にすることができると計算された。この時加熱部21にて被処理ガスに加えられる熱エネルギーは、3.0520M・KJ/時であった。
さらに予備圧力を8MPaGとしたときの加熱部21の熱エネルギーの削減量を計算した。表3は、予備圧力を8MPaGに設定したときの地点St.1、St.2、及びSt.3における圧力、温度変化を示す。
[表3]
表3に示すように、予備圧力を8MPaGに設定したときに、被処理ガスを供給したときに地点P3の温度を46.250℃に維持するためには、加熱部21にて被処理ガスを83.049℃に加熱する必要がある。そして被処理ガスを83.049℃に加熱ときに加熱部21にて被処理ガスに加えられる熱エネルギーは、1.2196M・KJ/時であり、加熱部21にて要求される熱エネルギーは約60%削減されていた。
従って本発明を適用することで分離膜モジュール1の圧力を運転圧力に上昇させたときの天然ガスの急激な温度低下を抑制することができると言える。さらには、被処理ガスを加熱して供給するCO2ガス分離装置においても、加熱部21を用いた加熱のみによりCO2ガスの凝縮、固化を抑える場合と比較して必要な熱エネルギーを削減することができると言える。
10 天然ガス供給路
11 製品ガス排出路
12 CO2ガス排出路
13 予備昇圧ガス供給路
21 加熱部
100 無機分離膜
Claims (14)
- 被処理ガス中の二酸化炭素ガスを、分離膜モジュールに設けられた分離膜の一次側から二次側に透過させて、前記被処理ガス中の二酸化炭素ガスを低減する二酸化炭素ガス分離方法において、
前記分離膜に二酸化炭素ガスを透過させる際の運転圧力よりも低圧の待機圧力の状態にある前記分離膜モジュールに対して、当該待機圧力よりも高い供給圧力で被処理ガスを供給する前に、圧力低下が生じる被処理ガスの温度を二酸化炭素ガスの凝縮温度、又は二酸化炭素ガスの固化温度よりも高い温度に維持するため、前記無機分離膜の一次側に予備昇圧ガスを供給して前記待機圧力と運転圧力との間の予備圧力まで昇圧する工程と、
その後、前記分離膜モジュールに被処理ガスを供給して当該分離膜モジュールの圧力を前記運転圧力まで上昇させ、前記被処理ガス中の二酸化炭素ガスを低減する工程と、を含むことを特徴とする二酸化炭素ガス分離方法。 - 前記分離膜は、無機分離膜であることを特徴とする請求項1に記載の二酸化炭素ガス分離方法。
- 前記被処理ガスは、加熱部にて加熱された後、前記分離膜モジュールに供給されることを特徴とする請求項1に記載の二酸化炭素ガス分離方法。
- 前記運転圧力と待機圧力との圧力差は、0.5MPa以上であることを特徴とする請求項1に記載の二酸化炭素ガス分離方法
- 前記被処理ガス中の二酸化炭素ガスの濃度は、モル比で30%以上、100%未満であることを特徴とする請求項1に記載の二酸化炭素ガス分離方法。
- 前記予備圧力は、前記運転圧力をPOpe、20℃における二酸化炭素ガスの蒸気圧をPVap、被処理ガス中の二酸化炭素ガスの濃度(モル比)をCCO2としたときに、下記の式(1)~式(3)で規定されるPPre以上の圧力であることを特徴とする請求項1に記載の二酸化炭素ガス分離方法。
ln(PPre)=a×[1/〔(POpe/PVap)2+(POpe/PVap)3〕]+b 式(1)
a=0.1318×(CCO2)-13.63 式(2)
b=0.8886×ln(CCO2)-2.372 式(3) - 前記予備昇圧ガスは、窒素ガス、ヘリウムガス及びメタンガスから選ばれる少なくとも一つのガスであることを特徴とする請求項1に記載の二酸化炭素ガス分離方法。
- 被処理ガスに含まれる二酸化炭素ガスを分離する二酸化炭素ガス分離装置において、
分離膜を備え、前記分離膜の一次側から二次側に二酸化炭素ガスを透過させることにより、前記被処理ガス中の二酸化炭素ガスを低減する分離膜モジュールと、
前記分離膜モジュール内の前記一次側の空間に接続され、二酸化炭素ガスを含む被処理ガスを供給する被処理ガス供給路と、
前記分離膜モジュール内の前記二次側の空間に接続され、前記分離膜を透過した二酸化炭素ガスが流出する二酸化炭素ガス流路と、
前記一次側の空間に接続され、前記二酸化炭素ガスが分離された後の非透過ガスが流出する非透過ガス流路と、
前記分離膜モジュールにおける分離膜の一次側に予備昇圧ガスを供給する予備昇圧ガス供給路と、を備え、
前記分離膜に二酸化炭素ガスを透過させる際の運転圧力よりも低圧の待機圧力の状態にある前記分離膜モジュールに対して、当該待機圧力よりも高い供給圧力で被処理ガスを供給する前に、圧力低下が生じる被処理ガスの温度を二酸化炭素ガスの凝縮温度、又は二酸化炭素ガスの固化温度よりも高い温度に維持するため、前記予備昇圧ガス供給路から予備昇圧ガスを供給して、前記一次側の空間の圧力を前記待機圧力と運転圧力との間の予備圧力まで昇圧することを特徴とする二酸化炭素ガス分離装置。 - 前記分離膜は、無機分離膜であることを特徴とする請求項8に記載の二酸化炭素ガス分離装置。
- 前記被処理ガス供給路は、被処理ガスを加熱した後、前記分離膜モジュールに供給するための加熱部を備えることを特徴とする請求項8に記載の二酸化炭素ガス分離装置。
- 前記運転圧力と待機圧力との圧力差は、0.5MPa以上であることを特徴とする請求項8に記載の二酸化炭素ガス分離装置。
- 前記被処理ガス中の二酸化炭素ガス濃度は、モル比で30%以上100%未満であることを特徴とする請求項8に記載の二酸化炭素ガス分離装置。
- 前記予備圧力は、前記運転圧力をPOpe、20℃における二酸化炭素ガスの蒸気圧をPVap、被処理ガス中の二酸化炭素ガスの濃度(モル比)をCCO2としたときに、式(1)~式(3)で規定されるPPre以上の圧力であることを特徴とする請求項8に記載の二酸化炭素ガス分離装置。
ln(PPre)=a×[1/〔(POpe/PVap)2+(POpe/PVap)3〕]+b 式(1)
a=0.1318×(CCO2)-13.63 式(2)
b=0.8886×ln(CCO2)-2.372 式(3) - 前記予備昇圧ガスは、窒素ガス、ヘリウムガス及びメタンガスから選ばれる少なくとも一つのガスであることを特徴とする請求項8に記載の二酸化炭素ガス分離装置。
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