WO2012050816A2 - Two-stage membrane process - Google Patents
Two-stage membrane process Download PDFInfo
- Publication number
- WO2012050816A2 WO2012050816A2 PCT/US2011/053358 US2011053358W WO2012050816A2 WO 2012050816 A2 WO2012050816 A2 WO 2012050816A2 US 2011053358 W US2011053358 W US 2011053358W WO 2012050816 A2 WO2012050816 A2 WO 2012050816A2
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- stream
- stage
- permeate
- gas
- residue
- Prior art date
Links
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
- B01D53/22—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
- B01D53/225—Multiple stage diffusion
- B01D53/226—Multiple stage diffusion in serial connexion
-
- 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
-
- 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
Definitions
- This invention relates to a membrane process for purifying gases. More particularly, this invention relates to a more efficient two-stage process for purifying natural gas.
- FIG. 1 for a two-stage membrane process
- FIG. 3 for a two-step membrane process.
- the hydrocarbon recovery for a two-stage membrane process will often exceed 95% and in some cases exceed 98%> or even 99%.
- the major penalty is the cost of the added compressor and its associated power consumption.
- Solvent processes such as those based on amine solvents have also been widely used for CO2 removal from natural gas, with generally above 99% hydrocarbon recovery, although the (important) fuel consumption in the amine unit reboiler needs to be taken into account as well.
- the membrane process provides various advantages such as ease of installation and operation in remote areas, reduced utility requirements, the elimination of a dehydration unit and for off-shore applications the absence of a sea motion effect which in the case of solvent processes can reduce efficiency. Since the value of hydrocarbons is high and its loss incurs a significant penalty, there exists a need to develop an improved membrane process to increase the product recovery while reducing compressor power consumption.
- the invention provides a process for purifying a hydrocarbon gas comprising sending a gas stream through a first stage membrane unit to produce a hydrocarbon-enriched residue stream and a hydrocarbon-reduced permeate stream; compressing this permeate stream and sending it through a second stage membrane unit divided into a first section and a second section wherein each section produces a residue stream and a permeate stream and where the residue stream of the first section feeds the second section.
- the hydrocarbon gas may be natural gas or another hydrocarbon containing gas.
- the impurities that are removed with this invention include carbon dioxide, hydrogen sulfide, helium and water.
- the permeate from the second section of the second stage membrane unit is recombined with the permeate from the first stage membrane unit.
- FIG. 1 shows a two-stage membrane process based upon prior art systems.
- FIG. 2 shows an alternative two-stage membrane process based on prior art systems
- FIG. 3 shows a two-step membrane process based on prior art systems.
- FIG. 4 shows a three-stage membrane process based upon prior art systems.
- FIG. 5 shows a two-stage membrane process based upon the present invention.
- FIG. 1 shows such a two-stage membrane process based upon the prior art.
- a feed 2 is shown going to a first stage membrane 4.
- the gas that does not pass through the first stage membrane is the residue, shown as product 6.
- a permeate 8 that passes through the first stage membrane is compressed in compressor 10 to produce a compressed permeate 12 that then contacts a second stage membrane 14.
- Residue 16 from second stage membrane 14 is then shown being combined with feed 2.
- Permeate 18 that contains carbon dioxide and other impurities removed from feed 2 is the secondary product. It's not uncommon that a slip stream of permeate 8 or permeate 18 is used as a source of fuel gas.
- FIG. 2 Another option to increase the hydrocarbon recovery for the conventional two-stage membrane process is to recycle a portion of the second stage permeate gas back to the compressor, as shown in FIG. 2.
- the recycled permeate gas in addition to increasing the gas flow to the compressor, also raises the CO2 concentration of the gas entering the second stage membrane, which increases the size of the second stage membrane.
- feed 2 is shown going to a first stage membrane 4 with a residue that does not pass through the first stage membrane shown as product 6.
- a permeate 8 that passes through the first stage membrane is compressed in compressor 10 to produce a compressed permeate 12 that then contacts a second stage membrane 14.
- Residue 16 from second stage membrane 14 is then shown being combined with feed 2.
- Permeate 18 that contains carbon dioxide and other impurities removed from feed 2 is the secondary product. However, a portion of the permeate 18 is split off as a recycled permeate 20 that is combined with permeate 8 and then passes through the second stage membrane 14 again.
- FIG. 3 shows an alternate open art process which is used to increase hydrocarbon recovery by splitting the first membrane stage into two sections and recycling permeate gas from the second section.
- a feed 2 is shown going to the first section 40 of the first stage membrane, producing a hydrocarbon enriched residue 41 and hydrocarbon reduced permeate 18.
- the residue 41 feeds a second section 42, which produces a further hydrocarbon enriched product 6 and a hydrocarbon reduced permeate 43, which has a greater hydrocarbon content than the permeate from the first section 18.
- This second section permeate 43 is compressed in a compressor 10 to create a compressed gas 44 that is combined with the feed 2.
- FIG. 4 illustrates a three stage membrane process that is based on the prior art schemes and differs from the present invention as shown in FIG. 5.
- a feed 2 is shown going to a first stage membrane 4 with a residue that does not pass through the first stage membrane shown as product 6.
- a permeate 8 that passes through the first stage membrane is compressed in compressor 10 to produce a compressed permeate 12 that then contacts a second stage membrane 14.
- Residue 16 from second stage membrane 14 is then shown being combined with feed 2.
- Permeate 18 that contains carbon dioxide and other impurities removed from feed 2 is shown being sent from second stage membrane 14 to a second compressor 30.
- a second compressed permeate 32 is then sent to third stage membrane 34 with residue 36 being sent from third stage membrane 34 to compressed permeate 12 and third stage membrane permeate 38 being the secondary product from the system.
- the second stage membrane unit of a two-stage membrane process is divided into two sections.
- the residue of the first section of the second stage membrane is feeding the second section of the second stage membrane.
- the permeate from the first section of the second stage membrane contains less hydrocarbons than the permeate from the second section of the second stage membrane and so is more suitable for disposal or reinjection than the full second stage permeate from a standard two stage membrane process.
- the permeate from the second section of the second stage membrane unit, which contains more hydrocarbons than the permeate from the first section is recycled back to the inlet of the compressor.
- the residue of the second section is recycled to the inlet of the first stage membrane, as in a traditional two-stage membrane configuration.
- FIG. 5 is a schematic showing this invention.
- a feed 2 is shown going to a first stage membrane 4 with a residue that does not pass through the first stage membrane shown as product 6.
- a permeate 8 that passes through the first stage membrane is compressed in compressor 10 to produce a compressed permeate 12 that then contacts a first section 15 of a second stage membrane.
- Residue 22 from first section 15 of the second stage membrane is sent to a second section 25 of the second stage membrane.
- Residue 26 is shown combining with feed 2.
- Permeate 28 from second stage 25 of the second membrane is shown being combined with permeate 8 to be recycled through the two sections of the second stage membrane.
- Permeate 18 that has a lower hydrocarbon content than permeate 28 and contains carbon dioxide and other impurities removed from feed 2 is the secondary product from the system.
- this invention provides a way to split the second stage permeate gas into a relatively CC"2 -rich stream for disposal or reinjection and a relatively hydrocarbon-rich stream for recycling back to the compressor.
- Variations to the present invention are those where part of the first stage permeate, part of the permeate from the first section membrane or permeate from the second section membrane is used as a fuel gas, for example to drive the compressors.
- a two-stage membrane process as shown in FIG. 1 is used to remove CO2 by keeping the CC"2 composition from the residue of the second stage membrane at 12.5% or the same as the feed (condition A). The obtained hydrocarbon recovery from simulation is 97.4% as shown in Case la in the table below.
- condition B the process conditions are adjusted (condition B) to have a CO2 composition from the residue of the second stage membrane at 34% (Case lb below).
- the obtained hydrocarbon recovery from simulation is 98.4%>, which is a 38% reduction in hydrocarbon losses versus Case la.
- the same hydrocarbon recovery can also be obtained using the alternative two-stage membrane process as shown in FIG. 2 with slightly higher compression power (Case lc). If the same feed stream is processed with the current invented process, the same hydrocarbon recovery, 98.4% can be achieved, but with 19%> less membrane area, while using equivalent compressor power (Case Id).
- the current invention process can provide a recovery of 98.9%> (30%> reduction in hydrocarbon losses versus Case lb), while using 15% lower compressor power (Case le). Concluding, the current invention process provides equivalent hydrocarbon recovery to open art processes using 19% less membrane area or reduces hydrocarbon losses by 30% while also using 15% lower compressor power consumption.
- a two-stage membrane process as shown in FIG. 1 is used to remove C0 2 by keeping the C0 2 composition from the residue of the second stage membrane at 7% or the same as the feed (condition A). The obtained hydrocarbon recovery from simulation is 98.1%. Results are shown as Case 2a in the table below.
- condition B the process conditions are adjusted to have a C0 2 composition from the residue of the second stage membrane at 21% (condition B).
- the obtained hydrocarbon recovery from simulation is 98.9%) as shown for Case 2b in the table below. If the same feed stream is processed with the current invented process, the same hydrocarbon recovery, 98.9%> can be achieved, but with a 12% lower compressor power consumption and 16% lower membrane area (Case 2c).
- the current invented process allows increasing the hydrocarbon recovery to 99.2%) (22%o lower hydrocarbon losses) for the same compression power while also using 12% less membrane area. Results for this case are shown below as Case 2d.
- a three-stage membrane process as shown in FIG. 4 can also be used to further increase the hydrocarbon recovery of 99.2%>, but as shown in Table 2 (Case 2e), 15% more membrane area is required and power consumption for the two compressors is equivalent to the current invention process.
- the three-stage process has the disadvantage of requiring two compressors as well as a separate third stage membrane unit which adds to the complexity of the process.
- a two-stage membrane process as shown in FIG. 1 is used to remove C0 2 by keeping the C0 2 composition from the residue of the second stage membrane at 35% or the same as the feed (condition A). The obtained hydrocarbon recovery from simulation is 97.7%. Results are shown as Case 3a in the table below.
- the process conditions are adjusted to have a CO2 composition from the residue of the second stage membrane at 60% (condition B).
- the obtained hydrocarbon recovery from simulation is 98.4%) as shown for Case 3b in the table below. If the same feed stream is processed with the current invented process, the same hydrocarbon recovery, 98.4%> can be achieved, but with a 13%) lower compressor power consumption while using equivalent membrane area (Case 3 c).
- a higher hydrocarbon recovery of 98.6% can be obtained using the alternative two-stage membrane process as shown in FIG. 2 using higher compression power (Case 3d).
- the current invented process can achieve the same higher hydrocarbon recovery of 98.6% using equivalent compression power, but with 21% less membrane area (Case 3e).
Landscapes
- Chemical & Material Sciences (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Engineering & Computer Science (AREA)
- General Chemical & Material Sciences (AREA)
- Chemical Kinetics & Catalysis (AREA)
- Organic Chemistry (AREA)
- Analytical Chemistry (AREA)
- Separation Using Semi-Permeable Membranes (AREA)
Abstract
Description
Claims
Priority Applications (4)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
CN2011800457079A CN103140571A (en) | 2010-09-29 | 2011-09-27 | Two-stage membrane process |
BR112013006542A BR112013006542A2 (en) | 2010-09-29 | 2011-09-27 | process to purify a hydrocarbon gas |
AU2011314136A AU2011314136B2 (en) | 2010-09-29 | 2011-09-27 | Two-stage membrane process |
RU2013118555/04A RU2013118555A (en) | 2010-09-29 | 2011-09-27 | TWO-STAGE MEMBRANE PROCESS |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US38749210P | 2010-09-29 | 2010-09-29 | |
US61/387,492 | 2010-09-29 |
Publications (2)
Publication Number | Publication Date |
---|---|
WO2012050816A2 true WO2012050816A2 (en) | 2012-04-19 |
WO2012050816A3 WO2012050816A3 (en) | 2012-06-14 |
Family
ID=45938855
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/US2011/053358 WO2012050816A2 (en) | 2010-09-29 | 2011-09-27 | Two-stage membrane process |
Country Status (5)
Country | Link |
---|---|
CN (1) | CN103140571A (en) |
AU (1) | AU2011314136B2 (en) |
BR (1) | BR112013006542A2 (en) |
RU (1) | RU2013118555A (en) |
WO (1) | WO2012050816A2 (en) |
Cited By (12)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
CN104001408A (en) * | 2013-02-26 | 2014-08-27 | 乔治洛德方法研究和开发液化空气有限公司 | Helium recovery from natural gas |
WO2015103040A1 (en) | 2013-12-30 | 2015-07-09 | L'air Liquide, Societe Anonyme Pour L'etude Et L'exploitation Des Procedes Georges Claude | Method of recovering a low concentration gas using two membrane stages with a second stage reflux |
RU2561072C2 (en) * | 2013-10-10 | 2015-08-20 | Закрытое Акционерное Общество "БЮРО ИНВЕСТ" | Method of helium recovery from natural gas |
WO2015138308A3 (en) * | 2014-03-12 | 2015-11-26 | Linde Aktiengesellschaft | Methods for removing contaminants from natural gas |
US9375677B2 (en) | 2013-02-26 | 2016-06-28 | Air Liquide Advanced Technologies U.S. Llc | Helium recovery from natural gas |
WO2016109353A1 (en) | 2014-12-29 | 2016-07-07 | L'Air Liquide Société Anonyme Pour L'Étude Et L'Exploitation Des Procedes Georges Claude | Three stage membrane separation with partial reflux |
WO2017011832A1 (en) * | 2015-07-16 | 2017-01-19 | Cameron Solutions, Inc. | Process design for acid gas removal |
US9662609B2 (en) | 2015-04-14 | 2017-05-30 | Uop Llc | Processes for cooling a wet natural gas stream |
WO2019118603A1 (en) * | 2017-12-15 | 2019-06-20 | Uop Llc | Helium purity adjustment in a membrane system |
EP3513863A1 (en) * | 2018-01-22 | 2019-07-24 | Linde Aktiengesellschaft | Method and assembly for recovering pure helium |
RU2730344C1 (en) * | 2018-09-13 | 2020-08-21 | Эр Продактс Энд Кемикалз, Инк. | Extraction of helium from natural gas |
RU2779486C1 (en) * | 2017-12-12 | 2022-09-07 | Линде Акциенгезельшафт | Method and installation for production of pure helium |
Families Citing this family (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
FR3010640B1 (en) * | 2013-09-16 | 2015-09-04 | Air Liquide | PROCESS FOR FINAL PURIFICATION OF BIOGAS TO PRODUCE BIOMETHANE |
Citations (4)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US5071451A (en) * | 1990-12-28 | 1991-12-10 | Membrane Technology & Research, Inc. | Membrane process and apparatus for removing vapors from gas streams |
US5102432A (en) * | 1990-12-10 | 1992-04-07 | Union Carbide Industrial Gases Technology Corporation | Three-stage membrane gas separation process and system |
US5256295A (en) * | 1990-12-28 | 1993-10-26 | Membrane Technology & Research | Two-stage membrane process and apparatus |
US20070232847A1 (en) * | 2006-04-04 | 2007-10-04 | Minhas Bhupender S | Membrane process for LPG recovery |
-
2011
- 2011-09-27 WO PCT/US2011/053358 patent/WO2012050816A2/en active Application Filing
- 2011-09-27 AU AU2011314136A patent/AU2011314136B2/en not_active Ceased
- 2011-09-27 CN CN2011800457079A patent/CN103140571A/en active Pending
- 2011-09-27 BR BR112013006542A patent/BR112013006542A2/en not_active IP Right Cessation
- 2011-09-27 RU RU2013118555/04A patent/RU2013118555A/en not_active Application Discontinuation
Patent Citations (4)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US5102432A (en) * | 1990-12-10 | 1992-04-07 | Union Carbide Industrial Gases Technology Corporation | Three-stage membrane gas separation process and system |
US5071451A (en) * | 1990-12-28 | 1991-12-10 | Membrane Technology & Research, Inc. | Membrane process and apparatus for removing vapors from gas streams |
US5256295A (en) * | 1990-12-28 | 1993-10-26 | Membrane Technology & Research | Two-stage membrane process and apparatus |
US20070232847A1 (en) * | 2006-04-04 | 2007-10-04 | Minhas Bhupender S | Membrane process for LPG recovery |
Cited By (22)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
RU2647296C2 (en) * | 2013-02-26 | 2018-03-15 | Л'Эр Ликид, Сосьете Аноним Пур Л'Этюд Э Л'Эксплуатасьон Де Проседе Жорж Клод | Helium production from natural gas |
US9375677B2 (en) | 2013-02-26 | 2016-06-28 | Air Liquide Advanced Technologies U.S. Llc | Helium recovery from natural gas |
CN104001408A (en) * | 2013-02-26 | 2014-08-27 | 乔治洛德方法研究和开发液化空气有限公司 | Helium recovery from natural gas |
CN104001408B (en) * | 2013-02-26 | 2018-04-27 | 乔治洛德方法研究和开发液化空气有限公司 | Helium is recycled by natural gas |
RU2561072C2 (en) * | 2013-10-10 | 2015-08-20 | Закрытое Акционерное Общество "БЮРО ИНВЕСТ" | Method of helium recovery from natural gas |
WO2015103040A1 (en) | 2013-12-30 | 2015-07-09 | L'air Liquide, Societe Anonyme Pour L'etude Et L'exploitation Des Procedes Georges Claude | Method of recovering a low concentration gas using two membrane stages with a second stage reflux |
WO2015138308A3 (en) * | 2014-03-12 | 2015-11-26 | Linde Aktiengesellschaft | Methods for removing contaminants from natural gas |
WO2016109353A1 (en) | 2014-12-29 | 2016-07-07 | L'Air Liquide Société Anonyme Pour L'Étude Et L'Exploitation Des Procedes Georges Claude | Three stage membrane separation with partial reflux |
US9433888B2 (en) | 2014-12-29 | 2016-09-06 | L'Air Liquide Société Anonyme Pour L'Étude Et L'Exploitation Des Procedes Georges Claude | Three stage membrane separation with partial reflux |
US9662609B2 (en) | 2015-04-14 | 2017-05-30 | Uop Llc | Processes for cooling a wet natural gas stream |
WO2017011832A1 (en) * | 2015-07-16 | 2017-01-19 | Cameron Solutions, Inc. | Process design for acid gas removal |
JP2018528076A (en) * | 2015-07-16 | 2018-09-27 | キャメロン ソリューションズ インコーポレイテッド | Process design for acid gas removal |
JP7176160B2 (en) | 2015-07-16 | 2022-11-22 | キャメロン ソリューションズ インコーポレイテッド | Process design for acid gas removal |
US10427094B2 (en) | 2015-07-16 | 2019-10-01 | Cameron Solutions, Inc. | Process design for acid gas removal |
AU2016293675B2 (en) * | 2015-07-16 | 2020-07-02 | Cameron Solutions, Inc. | Process design for acid gas removal |
RU2779486C1 (en) * | 2017-12-12 | 2022-09-07 | Линде Акциенгезельшафт | Method and installation for production of pure helium |
WO2019118603A1 (en) * | 2017-12-15 | 2019-06-20 | Uop Llc | Helium purity adjustment in a membrane system |
WO2019141508A1 (en) * | 2018-01-22 | 2019-07-25 | Linde Aktiengesellschaft | Method and system for extracting pure helium |
RU2782032C2 (en) * | 2018-01-22 | 2022-10-21 | Линде Гмбх | Method and system for extraction of pure helium |
EP3513863A1 (en) * | 2018-01-22 | 2019-07-24 | Linde Aktiengesellschaft | Method and assembly for recovering pure helium |
US11607641B2 (en) | 2018-01-22 | 2023-03-21 | Linde Gmbh | Method and system for extracting pure helium |
RU2730344C1 (en) * | 2018-09-13 | 2020-08-21 | Эр Продактс Энд Кемикалз, Инк. | Extraction of helium from natural gas |
Also Published As
Publication number | Publication date |
---|---|
CN103140571A (en) | 2013-06-05 |
RU2013118555A (en) | 2014-10-27 |
AU2011314136B2 (en) | 2015-04-16 |
AU2011314136A1 (en) | 2013-05-02 |
BR112013006542A2 (en) | 2016-06-07 |
WO2012050816A3 (en) | 2012-06-14 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
AU2011314136B2 (en) | Two-stage membrane process | |
KR101985551B1 (en) | Process for separation of gases | |
US7604681B2 (en) | Three-stage membrane gas separation process | |
US9988326B2 (en) | Method for the final purification of biogas for producing biomethane | |
EP1970428B1 (en) | Method for removing carbon dioxide from synthesis gas | |
US20110009684A1 (en) | Multi-stage membrane separation process | |
KR20220093130A (en) | Geothermal energy recovery process through selective recirculation | |
WO2000016879A1 (en) | Process for separating natural gas and carbon dioxide | |
AU2011271029B2 (en) | Integrated membrane and adsorption system for carbon dioxide removal from natural gas | |
US11021366B2 (en) | Helium purification process and unit | |
CN107081045A (en) | The method and its special equipment of a kind of collecting carbon dioxide from fuel gas | |
US20180250627A1 (en) | Plant and method for the membrane permeation treatment of a gaseous feedstream comprising methane and carbon dioxide | |
EP1459023B1 (en) | Combined recovery of hydrogen and hydrocarbon liquids from hydrogen-containing gases | |
CN116710397A (en) | Enhanced hydrogen recovery using gas separation membranes integrated with pressure swing adsorption units and/or cryogenic separation systems | |
CN104001408A (en) | Helium recovery from natural gas | |
CN1646421A (en) | Method and installation for separating a mixture of hydrogen and carbon monoxide | |
CN115417378B (en) | Method and system for recovering and purifying hydrogen from hydrogen-containing gas | |
WO2022146741A1 (en) | Two-stage membrane gas separation with cooling and use of sweep gas | |
CN114682055A (en) | Three stage membrane gas separation with cooling and use of purge gas | |
US20160265840A1 (en) | Unit and method for purifying co2 by adsorption | |
US10012434B2 (en) | Method and apparatus for producing carbon dioxide and hydrogen | |
US20240093108A1 (en) | System and method for recovery of fuel gas from crude oil purification | |
US20220297055A1 (en) | Plant for the membrane permeation treatment of a biogas stream with a membrane separation unit containing two modules | |
CN113357840B (en) | Low-temperature enhanced permselectivity nitrogen-containing natural gas membrane separation process | |
CN115637178A (en) | Decarbonization process of coal synthesis gas |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
WWE | Wipo information: entry into national phase |
Ref document number: 201180045707.9 Country of ref document: CN |
|
121 | Ep: the epo has been informed by wipo that ep was designated in this application |
Ref document number: 11833002 Country of ref document: EP Kind code of ref document: A2 |
|
NENP | Non-entry into the national phase in: |
Ref country code: DE |
|
ENP | Entry into the national phase in: |
Ref document number: 2013118555 Country of ref document: RU Kind code of ref document: A |
|
ENP | Entry into the national phase in: |
Ref document number: 2011314136 Country of ref document: AU Date of ref document: 20110927 Kind code of ref document: A |
|
122 | Ep: pct application non-entry in european phase |
Ref document number: 11833002 Country of ref document: EP Kind code of ref document: A2 |
|
REG | Reference to national code |
Ref country code: BR Ref legal event code: B01A Ref document number: 112013006542 Country of ref document: BR |
|
ENP | Entry into the national phase in: |
Ref document number: 112013006542 Country of ref document: BR Kind code of ref document: A2 Effective date: 20130322 |