WO2009073029A1 - Procédé pour un fonctionnement de membrane sans risque - Google Patents

Procédé pour un fonctionnement de membrane sans risque Download PDF

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Publication number
WO2009073029A1
WO2009073029A1 PCT/US2007/086597 US2007086597W WO2009073029A1 WO 2009073029 A1 WO2009073029 A1 WO 2009073029A1 US 2007086597 W US2007086597 W US 2007086597W WO 2009073029 A1 WO2009073029 A1 WO 2009073029A1
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WIPO (PCT)
Prior art keywords
permeate
stream
membrane
pressure
gas
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Ceased
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PCT/US2007/086597
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English (en)
Inventor
David R. Koch
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Honeywell UOP LLC
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UOP LLC
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Filing date
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Priority to PCT/US2007/086597 priority Critical patent/WO2009073029A1/fr
Publication of WO2009073029A1 publication Critical patent/WO2009073029A1/fr
Anticipated expiration legal-status Critical
Ceased legal-status Critical Current

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Classifications

    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D65/00—Accessories or auxiliary operations, in general, for separation processes or apparatus using semi-permeable membranes
    • 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
    • B01D53/229—Integrated processes (Diffusion and at least one other process, e.g. adsorption, absorption)
    • 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 OR C10K; LIQUIFIED PETROLEUM GAS; USE OF ADDITIVES TO FUELS OR FIRES; FIRE-LIGHTERS
    • 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
    • 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 OR C10K; LIQUIFIED PETROLEUM GAS; USE OF ADDITIVES TO FUELS OR FIRES; FIRE-LIGHTERS
    • 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
    • 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
    • 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
    • B01D2258/00—Sources of waste gases
    • B01D2258/06—Polluted air
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2311/00—Details relating to membrane separation process operations and control
    • B01D2311/13—Use of sweep gas
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2311/00—Details relating to membrane separation process operations and control
    • B01D2311/14—Pressure control
    • 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

  • This invention relates to a process for safe membrane operation and more particularly relates to a procedure for operating a continuous membrane separation process wherein membrane degradation may be prevented during membrane shut-down, particularly during sudden or unexpected shut-down of the membrane separation zone, and most specifically the invention relates to a method for safe membrane shut-down within a process for the removal of carbon dioxide from light hydrocarbon gases.
  • Permeable membrane processes and systems are known in the art and have been employed or considered for a wide variety of gas and liquid separations.
  • a feed stream is brought into contact with the surface of a membrane, and the more readily permeable component of the feed stream is recovered as a permeate stream, with the less- readily permeable component being withdrawn from the membrane system as a non-permeate stream.
  • Membrane separation modules are maintained at operating conditions which result in a non-permeate side pressure at which the feed gas is introduced and the non-permeate stream is withdrawn, and a permeate side pressure at which the permeate stream is withdrawn.
  • the pressure on the non-permeate side of the membrane is higher than the pressure on the permeate side, and the pressure differential between the non-permeate and the permeate sides of the membrane generally determines the degree of separation attained by the membrane separation.
  • Membranes are widely used to separate permeable components from gaseous feed streams. Examples of such process applications include removal of acid gases from natural gas streams, removal of water vapor from air and light hydrocarbon streams, and removal of hydrogen from heavier hydrocarbon streams. Membranes are also employed in gas processing applications to remove permeable components from a process gas stream. Natural gas as produced from a gas well presents a separations challenge. Often the natural gas is found together with other components such as sulfur compounds, water, and associated gases. The associated gases found in natural gas streams typically include carbon dioxide, hydrogen sulfide, nitrogen, helium, and argon. Generally, these other gas components are separated from the natural gas by bulk methods employing membrane systems.
  • the feed gas is introduced at separation conditions which include a separation pressure and temperature which retains the components of the feed gas stream in the vapor phase, well above the dew point of the gas stream, or the temperature and pressure condition at which condensation of one of the components might occur.
  • separation conditions include a separation pressure and temperature which retains the components of the feed gas stream in the vapor phase, well above the dew point of the gas stream, or the temperature and pressure condition at which condensation of one of the components might occur.
  • the feed gas stream fed to the gas separation membrane may contain a substantial amount of moisture and this moisture and other impurities may cause corrosion, condensation or other damage to instrumentation, piping, pneumatic tools, ventilators and other equipment associated with the gas separation membrane, hi certain instances, it may also lead to inferior performance of the gas separation membrane or other equipment, such as adsorption traps.
  • US 5,030,251 to Rice et al. relates to the operation of a membrane separator which removes water vapor from a moist air feed to produce a drier air product.
  • a membrane separator which removes water vapor from a moist air feed to produce a drier air product.
  • some residual water vapor remains in the membrane separator and when the feed flow is resumed , the residual water vapor flows out with the non-permeate stream. This results in a less dry product produced during restarts than during the steady-state operation of the membrane separator.
  • a portion of the non-permeate product is saved in a storage tank and supplied to the membrane separation at a time when the feed is not being supplied to the separator to purge the residual water vapor between cycles.
  • the invention provides a process for the safe shut-down of a membrane separation system which minimizes the risk of damage to the membrane.
  • Membranes that process hydrocarbon streams that comprise less-readily permeable, condensible components such as Cg + hydrocarbons in an environment in which condensing of such hydrocarbons may occur can be subject to catastrophic failure when such hydrocarbon condensation is followed by conventional shut-down procedures such as depressurization of the non-permeate side. Depressurization of the membrane upon shut-down is desirable when it occurs simultaneously with purging of the non-permeate zone of the membrane unit.
  • a reduction in pressure of the sales gas producing a significant reduction in temperature of the gas followed by the use of a gas/liquid separator can provide an effective means to produce a purge gas to sweep the membrane of residual gas before the undesirable components can condense on the membrane.
  • An additional degree of protection can be provided to the system by injecting nitrogen gas into the purge gas flow. It has been found that this procedure avoids degradation of the membrane and maintains selectivity and permeability of the membrane through multiple shut-downs of the membrane separation system.
  • a process for the safe shut-down of a membrane separation zone for the removal of a readily permeable component from a feed gas mixture comprising the readily permeable component, a non-permeable component, and a less-readily permeable, condensible component.
  • the process comprises intermittently passing the feed gas mixture at separation conditions to a membrane separation zone to provide a non-permeate stream and a permeate stream.
  • the membrane separation zone has a non- permeate side and a permeate side.
  • the non-permeate stream is withdrawn from the non- permeate side of the membrane separation zone and a permeate stream at a permeate pressure is withdrawn from the permeate side of the membrane separation zone.
  • a portion of the gas mixture preferably a sales gas flow that is depleted in carbon dioxide, is sent through a valve to reduce the pressure of the as and subsequently cool the gas into a two phase (gas/liquid) stream to be separated in a gas liquid separator with de-mister pads or other separation means known to one skilled in the art.
  • the remaining gas becomes a purge gas stream.
  • this purge stream reduced in the less-readily permeable, condensible component is passed at a pressure greater than the permeate pressure to the non-permeate side of the membrane separation zone to remove at least a portion of a residual gas remaining in the non-permeate side of the membrane separation zone before the residual gas condenses in the membrane separation zone.
  • the invention relates to a process used intermittently for the removal of carbon dioxide from a hydrocarbon gas feed stream to produce a sales gas stream.
  • the hydrocarbon gas feed mixture comprises Ci to Cg hydrocarbons, carbon dioxide and Cg + hydrocarbons.
  • the Cg + hydrocarbons are less-readily permeable and condensible.
  • the hydrocarbon gas feed mixture is passed to a membrane separation zone having a non-permeate zone and a permeate zone at separation conditions to provide a non-permeate stream withdrawn from the non-permeate zone and a permeate stream at a permeate pressure withdrawn from the permeate zone.
  • the non-permeate stream comprises Cg + hydrocarbons and a reduced amount of carbon dioxide relative to the hydrocarbon gas feed mixture.
  • the permeate stream is enriched in carbon dioxide relative to the hydrocarbon gas feed mixture.
  • a purge stream reduced in Cg + hydrocarbons relative to the Cg + hydrocarbons in the non-permeate stream is intermittently passed at a pressure greater than the permeate pressure to the non-permeate zone to prevent condensation ofCg + hydrocarbons in the non-permeate stream remaining in the non-permeate zone.
  • a portion of the gas mixture preferably a sales gas flow that is depleted in carbon dioxide, is sent through a valve to reduce the pressure of the as and subsequently cool the gas into a two phase (gas/liquid) stream to be separated in a gas liquid separator with de-mister pads or other separation means known to one skilled in the art.
  • the remaining gas becomes a purge gas stream.
  • a quantity of nitrogen gas is added to the purge gas stream prior to contact with the residual gas in the non-permeate zone.
  • FIG. 1 is a schematic flow diagram of the process of the present invention showing the use of a purge stream to remove residual gas from a membrane module.
  • FIG. 2 is a phase envelope curve showing pressure temperature for streams treated in accordance with the present invention.
  • FIG. 3 is a phase envelope curve showing the conditions in which condensation will occur without treatment in accordance with the present invention.
  • the invention is useful in membrane systems for the rejection of carbon dioxide from a natural gas stream to provide a purified natural gas stream which can be subsequently processed in a natural gas process plant for the further removal of heavy hydrocarbons such as Cg + hydrocarbon to provide a sales gas stream or purified natural gas stream.
  • the gas feed stream may be passed to a membrane separation unit to provide a permeate gas stream comprising carbon dioxide and a non-permeate gas comprising light hydrocarbons.
  • the natural gas feed stream comprises methane as well as heavy hydrocarbons, as well as water and carbon dioxide.
  • enriched as utilized herein is meant to refer to the concentration of a component of a product stream in relation to the concentration of that component in the feed stream.
  • the permeate stream from the membrane separation zone will be enriched in the readily permeable component relative to the concentration of the readily permeable component in the feed.
  • membrane separation zone means one or more device having at least one membrane useful for permeating or separating readily permeable components from a feed gas mixture.
  • dew point means the temperature at a given pressure wherein a condensable vapor such as hydrocarbon or water begins to condense.
  • Permeable membranes capable of separating at least one selected component from a fluid mixture, either gas or liquids, are convenient, and potentially highly advantageous, means for achieving desirable fluid separation and/or concentration.
  • Membranes suitable for the present invention include composite membranes such as those membranes disclosed in US 4,822,382, which is hereby incorporated by reference.
  • the term "intermittently" refers to a continuous process which has periods of intermission, particularly unplanned or sudden intermissions or interruptions in the normal feed flow. During these periods, the membrane must be safely shut-down to prevent damage to the membrane. Applicant provides a process for the safe shut-down of a membrane that is particularly useful for such shut-downs with no or minimal damage to the membrane.
  • condensation in a membrane may result from a phenomenon known as "retrograde condensation.” For example, in a membrane when a mixture of gases is present, condensation may occur when the pressure is reduced.
  • a feed stream comprising a mixture of a permeable, non-condensible component and a less-readily permeable, condensible component is passed to a membrane unit.
  • the membrane comprises a non-permeate zone from which a non-permeate stream is withdrawn and a permeate zone from which a permeate stream is withdrawn.
  • the present invention acts to mitigate this retrograde condensation by purging the non-permeate zone of the membrane unit with a purge stream which maintains the partial pressure of the less- readily condensible component in the non-permeate zone above the dew point, or the point at which condensation will occur.
  • the invention comprises passing at an operating pressure a mixture of permeable, non- condensible light hydrocarbons such as C j to Cg hydrocarbons and carbon dioxide and less- readily permeable, condensible components such as Cg + or CjO + hydrocarbons to a membrane unit having a non-permeate zone and a permeate zone.
  • a non-permeate stream reduced in carbon dioxide is withdrawn from the non-permeate zone at a pressure essentially equai to the operating pressure, and a permeate stream enriched in carbon dioxide relative to the feed stream is withdrawn from the permeate zone at a low pressure.
  • a permeate stream enriched in carbon dioxide relative to the feed stream is withdrawn from the permeate zone at a low pressure.
  • the non-permeate zone upon interruption of the feed stream flow, the non-permeate zone is purged with a purge stream such that the partial pressure of the less-readily permeable, condensible component is maintained above the point of condensation.
  • the purge gas stream comprise less of the less-readily permeable, condensible component than the amount of less-readily permeable, condensible component in the non-permeate zone.
  • the purge gas stream reduced in the less- readily permeable, condensible component comprises less than 90 mol-% of the less-readily permeable, condensible component in the non-permeate stream, and more preferably, the purge gas stream comprises less than 10 mol-% of the less-readily permeable, condensible component in the non-permeate stream, and most preferably, the purge gas stream comprises less than 0.1 mol-% of the less-readily permeable, condensible component in the non- permeate stream.
  • the purge gas stream has been reduced in the less-readily permeable, condensible component through the passing of the gas stream through a Joules-Thompson valve, or otherwise reduced in pressure followed by condensation and removal of these condensible components.
  • Membrane operation is measured by the selectivity of the membrane and the permeability of a component through the membrane. These parameters depend upon the partial pressure driving forces between the non-permeate and permeate zones for each component.
  • the selectivity is the product of the ratio of the mole fractions of the components in the feed stream and the inverse ratio of the partial pressure driving force between the non-permeate and permeate zones, wherein the partial pressure driving force for a given component of a mixture is the difference between the partial pressure of the component in the feed less the partial pressure of the component in the permeate.
  • xj and X2 are the feed mole fractions of components 1 and 2; ppfj and pp£> are the partial pressures of the components 1 and 2 in the feed stream; and ppnj and ppp2 are the partial pressure of the components 1 and 2 in the permeate stream.
  • Permeability for a low molar flow ratio of permeate flow to feed flow is the flow of the component through the membrane divided by the product of the surface area of the membrane and the partial pressure driving force for that component between the feed stream and the permeate partial pressures.
  • the permeability of component 1 is expressed as follows:
  • the purge gas comprises a sales gas flow that is depleted in carbon dioxide, is sent through a valve to reduce the pressure of the gas and subsequently cool the gas into a two phase (gas/liquid) stream to be separated in a gas liquid separator with de-mister pads or other separation means known to one skilled in the art. The remaining gas becomes a purge gas stream.
  • the purge gas includes nitrogen gas added to the purge gas flow.
  • a hydrocarbon gas feed stream in line 200 at a separation pressure ranging from 700 kPa (100 psia) to 11,032 kPa (1600 psia) and a separation temperature ranging from 25° to 60 0 C is passed to a membrane separation zone 250 via line 200.
  • the feed gas Prior to passing to the membrane separation zone 250, the feed gas is purified by passing through filter coalescer 210, preheater 220, guard bed 230 and particle filter 240.
  • the hydrocarbon gas feed stream comprises C j to Cg hydrocarbons, carbon dioxide, and heavy hydrocarbons such as Cg + or CjQ + hydrocarbons.
  • the membrane separation zone 250 comprises a non-permeate zone 250a and a permeate zone 250b.
  • a non- permeate stream comprising heavy hydrocarbons and having a reduced amount of carbon dioxide relative to the feed stream is withdrawn from non-permeate zone 250a at a non- permeate pressure essentially equal to the separation pressure via line 270 and a permeate stream enriched in carbon dioxide is withdrawn from permeate zone 250b at a permeate pressure ranging from 100 kPa (15 psia) to 1050 kPa (150 psia) via line 260.
  • the process is operated in an intermittent manner such that when the feed stream is unavailable, the membrane separation zone 250 is shut-down.
  • the process of this invention when the feed stream in line 200 flow is interrupted, a portion of the feed stream in line 200 is passed via line 300 and valve 310 to Joules-Thompson valve 320 and to gas-liquid separator 330 to produce a purge gas stream in line 340 that comprises less than the non- permeate stream Cg + hydrocarbons.
  • the purge gas stream is passed to non-permeate zone 250a via lines 360, valve 370 and line 380 to sweep any residual non-permeate gas comprising condensible Cg + hydrocarbons remaining in non-permeate zone 250a prior to reducing the pressure in the non- permeate zone.
  • Nitrogen gas may be injected into the purge stream in line 350 to provide further insurance that the purge stream is low in hydrocarbon content. Typically, the nitrogen gas is added to provide 25% of the purge gas stream by volume.
  • the condensation zone comprising the Joules-Thompson valve 320 and the gas- liquid separator 330, is thus available during intermittent feed stream outages to provide a purge gas stream.
  • the purge gas stream comprises a portion of the non-permeate stream depleted in the less-readily permeable, condensible component, and more preferably, the purge gas comprises a portion of the feed gas mixture depleted in the less-readily permeable, condensible component relative to the non-permeate stream.
  • FIG. 2 shows how the treated residue stream prevents retrograde condensation.
  • a plant operating at 8.2 to 1 1.0 MPa (1200 to 1600 psia) would not experience retrograde condensation during depressurization since operation at 49°C (12O 0 F) with the operation at that temperature being to the right of the curve, which shows the temperature/pressures at which condensation would occur.
  • FIG. 3 shows how a non-treated residue stream would suffer from retrograde condensation between 690 kPa and 7.6 MPa (100 and 1 100 psia) during operation at 49 0 C
  • FIG. 2 illustrates a wide range of operating conditions being possible with the treated stream.
  • membranes operating in a potentially condensing environment were based on the performance of membrane micromodules, each containing 2800 mm ⁇ composite membrane surface having a separation layer comprised of at least one poly (tetramethyl) bisphenol A phthalate as disclosed in US 4,822,382.
  • the micromodules were pressurized to a separation pressure of 3.6 MPa (515 psia) with a prepared feed stream without the withdrawal of a non-permeate stream.
  • the condensible-loaded gas feed stream was prepared by sparging a hydrogen gas stream of 99.9% purity through a liquid hydrocarbon mixture of 10 vol-% benzene and 90 vol-% hexane to saturate the hydrogen gas stream with the hydrocarbon mixture at a temperature of 24°C (75°F).
  • the selectivity of the membrane was measured before and after the exposure to the saturated hydrogen gas stream by pressurizing the membrane micromodule with a gas mixture of 10 vol-% carbon dioxide and 90 vol-% methane.
  • the molar ratio of the permeate flow to the feed flow was less than 3%.
  • Example I a hydrogen gas stream was sparged as described herein above and passed to a membrane micromodule for 6 hours at a pressure of 3.6 MPa and a temperature of 24°C measured at the sparger while the temperature of the micromodule was maintained at 37 0 C (100 0 F) without a non-permeate flow from the membrane module.
  • the micromodule was then depressurized to atmospheric pressure.
  • a gas mixture containing 10 vol-% carbon dioxide and 90 vol-% methane was passed to the membrane micromodule to repressurize the micromodule to 3.6 MPa (515 psia) at a temperature of 49°C (120 0 F) and the selectivity of the membrane was determined.
  • Table 1 The results are shown in Table 1.
  • a membrane plant is designed to operate in the supercritical region above the phase envelope. Retrograde condensation will occur as the system is depressurizing during an emergency shut-down. The change in pressure before condensation will occur is approximately 2.4 MPa (350 psia).
  • the process disclosed will use Joules-Thompson cooling as the feed stream is decreased from 1 1.0 to 8.6 MPa (1600 psia to 1250 psia) to change the composition of the purge gas stream and provide ⁇ 38 0 C (100 0 F) circondentherm. The membrane system can then be purged with this gas and then decreased in pressure to avoid retrograde condensation.
  • FIGS. 2 and 3 illustrate the advantage of the present invention (FIG. 2) as compared to the result when the purge stream is not treated (FIG. 3).
  • the gas stream from the separator may be diluted with 25% nitrogen.
  • the injection of 25% nitrogen into the purge gas will also produce a lower circondentherm or dew point.
  • the proposed system may be a combination of both nitrogen dilution and Joules-Thompson cooling to provide redundancy if either system fails.

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  • Chemical & Material Sciences (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • Engineering & Computer Science (AREA)
  • General Chemical & Material Sciences (AREA)
  • Organic Chemistry (AREA)
  • Analytical Chemistry (AREA)
  • Separation Using Semi-Permeable Membranes (AREA)

Abstract

Le procédé de l'invention permet de fermer une zone de séparation à membrane (250) comprenant un côté non-perméat (50a) et un côté perméat (250b) et de traiter un flux d'alimentation comprenant un composant non perméable, un composant condensable, moins facilement perméable, et un composant facilement perméable. Quand on ne fait pas passer le flux d'alimentation dans la zone de séparation à membrane, on fait passer un flux de purge du côté non-perméat de la zone de séparation à membrane pour éliminer un flux gazeux résiduel et empêcher ainsi la condensation du composant condensable, moins facilement perméable lors de la dépressurisation et/ou du refroidissement de la zone de séparation à membrane. Le besoin de surdimensionnement du système à membrane est réduit, ce qui réduit les coûts de traitement et prévient les dommages occasionnés aux surfaces de la membrane par le perméat, provoqués par condensation des composants condensables, moins facilement perméables tels que les hydrocarbures C6+.
PCT/US2007/086597 2007-12-06 2007-12-06 Procédé pour un fonctionnement de membrane sans risque Ceased WO2009073029A1 (fr)

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Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US11471823B2 (en) 2019-02-12 2022-10-18 Haffmans B.V. System and method for separating a gas mixture

Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5669959A (en) * 1996-05-16 1997-09-23 Uop Process for safe membrane operation
EP0826629B1 (fr) * 1996-08-27 2002-11-20 The Boc Group, Inc. Récupération de gaz nobles
US6648944B1 (en) * 2003-01-28 2003-11-18 Membrane Technology And Research, Inc. Carbon dioxide removal process
US7025804B2 (en) * 2002-12-02 2006-04-11 L'air Liquide, Societe Anonyme A Directoire Et Conseil De Surveillance Pour L'etude Et L'exploitation Des Procedes Georges Claude Method for separating hydrocarbon-containing gas mixtures using hydrocarbon-resistant membranes
US7329306B1 (en) * 2004-12-02 2008-02-12 Uop Llc Process for safe membrane operation

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5669959A (en) * 1996-05-16 1997-09-23 Uop Process for safe membrane operation
EP0826629B1 (fr) * 1996-08-27 2002-11-20 The Boc Group, Inc. Récupération de gaz nobles
US7025804B2 (en) * 2002-12-02 2006-04-11 L'air Liquide, Societe Anonyme A Directoire Et Conseil De Surveillance Pour L'etude Et L'exploitation Des Procedes Georges Claude Method for separating hydrocarbon-containing gas mixtures using hydrocarbon-resistant membranes
US6648944B1 (en) * 2003-01-28 2003-11-18 Membrane Technology And Research, Inc. Carbon dioxide removal process
US7329306B1 (en) * 2004-12-02 2008-02-12 Uop Llc Process for safe membrane operation

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US11471823B2 (en) 2019-02-12 2022-10-18 Haffmans B.V. System and method for separating a gas mixture
US11964231B2 (en) 2019-02-12 2024-04-23 Haffmans B.V. System and method for separating a gas mixture

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