AU2012216559A1 - A system and method for enhanced removal of CO2 from a mixed gas stream - Google Patents
A system and method for enhanced removal of CO2 from a mixed gas stream Download PDFInfo
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- AU2012216559A1 AU2012216559A1 AU2012216559A AU2012216559A AU2012216559A1 AU 2012216559 A1 AU2012216559 A1 AU 2012216559A1 AU 2012216559 A AU2012216559 A AU 2012216559A AU 2012216559 A AU2012216559 A AU 2012216559A AU 2012216559 A1 AU2012216559 A1 AU 2012216559A1
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- Australia
- Prior art keywords
- catalyst
- flue gas
- carbon dioxide
- gas stream
- amine
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Abandoned
Links
- 238000000034 method Methods 0.000 title description 21
- 229910002092 carbon dioxide Inorganic materials 0.000 claims abstract description 60
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 claims abstract description 56
- 239000003054 catalyst Substances 0.000 claims abstract description 33
- 239000001569 carbon dioxide Substances 0.000 claims abstract description 28
- 239000002904 solvent Substances 0.000 claims abstract description 28
- 239000000463 material Substances 0.000 claims abstract description 27
- 238000012856 packing Methods 0.000 claims abstract description 25
- 238000012545 processing Methods 0.000 claims abstract description 17
- 230000008929 regeneration Effects 0.000 claims abstract description 16
- 238000011069 regeneration method Methods 0.000 claims abstract description 16
- UGFAIRIUMAVXCW-UHFFFAOYSA-N Carbon monoxide Chemical compound [O+]#[C-] UGFAIRIUMAVXCW-UHFFFAOYSA-N 0.000 claims description 45
- 239000003546 flue gas Substances 0.000 claims description 45
- QGZKDVFQNNGYKY-UHFFFAOYSA-N Ammonia Chemical group N QGZKDVFQNNGYKY-UHFFFAOYSA-N 0.000 claims description 34
- 239000006096 absorbing agent Substances 0.000 claims description 20
- 239000007789 gas Substances 0.000 claims description 19
- 150000001412 amines Chemical class 0.000 claims description 17
- 229910021529 ammonia Inorganic materials 0.000 claims description 17
- 239000002638 heterogeneous catalyst Substances 0.000 claims description 4
- 230000003993 interaction Effects 0.000 claims description 4
- 238000000354 decomposition reaction Methods 0.000 claims 3
- 238000006243 chemical reaction Methods 0.000 claims 2
- NLXLAEXVIDQMFP-UHFFFAOYSA-N Ammonium chloride Substances [NH4+].[Cl-] NLXLAEXVIDQMFP-UHFFFAOYSA-N 0.000 description 19
- VHUUQVKOLVNVRT-UHFFFAOYSA-N Ammonium hydroxide Chemical compound [NH4+].[OH-] VHUUQVKOLVNVRT-UHFFFAOYSA-N 0.000 description 19
- 235000011114 ammonium hydroxide Nutrition 0.000 description 19
- 230000008569 process Effects 0.000 description 12
- 238000002485 combustion reaction Methods 0.000 description 7
- 238000010586 diagram Methods 0.000 description 7
- 239000007788 liquid Substances 0.000 description 4
- 238000005516 engineering process Methods 0.000 description 3
- 238000010248 power generation Methods 0.000 description 3
- 230000001172 regenerating effect Effects 0.000 description 3
- 239000011343 solid material Substances 0.000 description 3
- 238000012546 transfer Methods 0.000 description 3
- RAHZWNYVWXNFOC-UHFFFAOYSA-N Sulphur dioxide Chemical compound O=S=O RAHZWNYVWXNFOC-UHFFFAOYSA-N 0.000 description 2
- -1 ammonium ions Chemical class 0.000 description 2
- 238000004140 cleaning Methods 0.000 description 2
- 239000002803 fossil fuel Substances 0.000 description 2
- 239000000446 fuel Substances 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- BVKZGUZCCUSVTD-UHFFFAOYSA-M Bicarbonate Chemical compound OC([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-M 0.000 description 1
- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 description 1
- 229910004298 SiO 2 Inorganic materials 0.000 description 1
- 230000002745 absorbent Effects 0.000 description 1
- 239000002250 absorbent Substances 0.000 description 1
- 238000010521 absorption reaction Methods 0.000 description 1
- 239000003513 alkali Substances 0.000 description 1
- 229910052783 alkali metal Inorganic materials 0.000 description 1
- 229910000287 alkaline earth metal oxide Inorganic materials 0.000 description 1
- 239000002585 base Substances 0.000 description 1
- 239000003245 coal Substances 0.000 description 1
- 239000011248 coating agent Substances 0.000 description 1
- 238000000576 coating method Methods 0.000 description 1
- 239000000567 combustion gas Substances 0.000 description 1
- 238000013461 design Methods 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 230000018109 developmental process Effects 0.000 description 1
- 230000007613 environmental effect Effects 0.000 description 1
- 239000003344 environmental pollutant Substances 0.000 description 1
- 229910044991 metal oxide Inorganic materials 0.000 description 1
- 150000004706 metal oxides Chemical class 0.000 description 1
- 239000002808 molecular sieve Substances 0.000 description 1
- 239000003921 oil Substances 0.000 description 1
- 239000003415 peat Substances 0.000 description 1
- 231100000719 pollutant Toxicity 0.000 description 1
- 229920000642 polymer Polymers 0.000 description 1
- 239000002002 slurry Substances 0.000 description 1
- URGAHOPLAPQHLN-UHFFFAOYSA-N sodium aluminosilicate Chemical compound [Na+].[Al+3].[O-][Si]([O-])=O.[O-][Si]([O-])=O URGAHOPLAPQHLN-UHFFFAOYSA-N 0.000 description 1
- 238000001179 sorption measurement Methods 0.000 description 1
- 239000004291 sulphur dioxide Substances 0.000 description 1
- 235000010269 sulphur dioxide Nutrition 0.000 description 1
- 229910000314 transition metal oxide Inorganic materials 0.000 description 1
- 239000002699 waste material Substances 0.000 description 1
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 1
Classifications
-
- 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
- Y02A—TECHNOLOGIES FOR ADAPTATION TO CLIMATE CHANGE
- Y02A50/00—TECHNOLOGIES FOR ADAPTATION TO CLIMATE CHANGE in human health protection, e.g. against extreme weather
- Y02A50/20—Air quality improvement or preservation, e.g. vehicle emission control or emission reduction by using catalytic converters
-
- 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
Landscapes
- Gas Separation By Absorption (AREA)
- Treating Waste Gases (AREA)
Abstract
A mixed gas processing system comprising a regeneration tower containing packing materials coated with a catalyst, a carbon dioxide rich solvent inlet arranged for contact of a carbon dioxide rich solvent with the packing 5 material, wherein the catalyst promotes the release of carbon dioxide within the carbon dioxide rich solvent to produce a carbon dioxide lean solvent.
Description
1 A SYSTEM AND METHOD FOR ENHANCED REMOVAL OF CO 2 FROM A MIXED GAS STREAM Cross Reference to Related Application(s) This application claims priority to U.S. provisional application entitled, "System and Method For Enhanced Removal of CO 2 From a Mixed Gas Stream," having U.S. Serial No. 61/038,494, filed 03/21/2008, the disclosure of which is entirely incorporated herein by reference. Field of the Invention The invention relates to a system and method for removing carbon dioxide
(CO
2 ) from a process gas stream containing carbon dioxide and sulphur dioxide. More particularly, the invention is directed to a solvent based flue gas processing system for removing CO 2 from a flue gas stream in which a catalyst is provided to increase the efficiency of the solvent in capturing CO 2 from the flue gas stream or in regenerating the solvent. Background In the combustion of a fuel, such as coal, oil, peat, waste, etc., in a combustion plant, such as those associated with boiler systems for providing steam to a power plant, a hot process gas (or flue gas) is generated. Such a flue gas will often contain, among other things, carbon dioxide (CO 2 ) The negative environmental effects of releasing carbon dioxide to the atmosphere have been widely recognised, and have resulted in the development of processes adapted for removing carbon dioxide from the hot process gas generated in the combustion of the above mentioned fuels. One such system and process has previously been disclosed and is directed to a single-stage Chilled Ammonia based system and method for removal of carbon dioxide (CC 2 ) from a post combustion flue gas stream. Known solvent based CO 2 capture systems, such as ammonia based systems and processes (CAP) provide a relatively low cost means for capturing/removing CO 2 from a gas stream, such as, for example, a post combustion flue gas stream. An example of such a system and process has previously been disclosed in WO 2006/022885 filed on 12 April 2005 and titled 2 Ultra Cleaning of Combustion Gas Including the Removal of CO 2 . In this process the absorption of C02 from a flue gas stream is achieved by contacting a chilled ammonia ionic ammonia solution (or slurry) with a flue gas stream that contains C02. FIG. 1A is a diagram generally depicting a flue gas processing system 15 for use in removing various pollutants from a flue gas stream FG emitted by the combustion chamber of a boiler system 26 used in a steam generator system of, for example, a power generation plant. This system includes a C02 removal system 70 that is configured to remove C02 from the flue gas stream FG before emitting the cleaned flue gas stream to an exhaust stack 90 (or alternatively additional processing). It is also configured to output C02 removed from the flue gas stream FG. Details of C02 removal system 70 are generally depicted in FIG. 1B. With reference to FIG. 11B, C02 removal System 70 includes a capture system 72 for capturing/removing C02 from a flue gas stream FG and a regeneration system 74 for regenerating ionic ammonia solution used to remove C02 from the flue gas stream FG. Details of capture system 72 are generally depicted in FIG. 1C. With reference to FIG. 1C, a capture system 72 of a C02 capture system 70 (FIG. 1A) is generally depicted. In this system, the capture system 72 is a solvent based C02 capture system. More particularly, in this example, the solvent used is chilled ammonia. In a chilled ammonia (CAP) based system/method for C02 removal, an absorber vessel is provided in which an absorbent ionic ammonia solution (ionic ammonia solution) is contacted with a flue gas stream (FG) containing C02. The ionic ammonia solution is typically aqueous and may be composed of, for example, water and ammonium ions, bicarbonate ions, carbonate ions, and/or carbamate ions. An example of a known CAP C02 removal system is generally depicted in the diagrams of FIG. 1C. With reference to FIG. 1C, an absorber vessel 170 is configured to receive a flue gas stream (FG) originating from, for example, the combustion chamber of a fossil fuel fired boiler 26 (see FIG. 1A). It is also configured to receive a lean ionic ammonia solution supply from regeneration system 74 (see FIG. 1B). The lean ionic ammonia solution is introduced into the vessel 170 via a liquid distribution system 122 while the flue gas stream FG is also received by the absorber vessel 170 via flue gas inlet 76.
3 The ionic ammonia solution is put into contact with the flue gas stream via a gas-liquid contacting device (hereinafter, mass transfer device, MTD) 111 used for contacting the flue gas stream with solvent and located in the absorber vessel 170 and within the path that the flue gas stream travels from its entrance via inlet 76 to the vessel exit 77. The gas-liquid contacting device 111 may be, for example, one or more commonly known structured or random packing materials, or a combination thereof. Once contacted with the flue gas stream, the ionic ammonia solution acts to absorb CO 2 from the flue gas stream, thus making the ionic ammonia solution "rich" with CO 2 (rich solution). The rich ionic ammonia solution continues to flow downward through the mass transfer device and is then collected in the bottom 78 of the absorber vessel 170. The rich ionic ammonia solution is then regenerated via regenerator system 74 (see FIG. 1 B) to release the CO 2 absorbed by the ionic ammonia solution from the flue gas stream. The C02 released from the ionic ammonia solution may then be output to storage or other predetermined uses/purposes. Once the C02 is released from the ionic ammonia solution, the ionic ammonia solution is said to be "lean". The lean ionic ammonia solution is then again ready to absorb C02 from a flue gas stream and may be directed back to the liquid distribution system 121 whereby it is again introduced into the absorber vessel 170. The regenerating system 74 includes a regenerator vessel 195. Regenerator vessel 195 is configured to receive a rich solution feed from the capture system 72 and to return a lean solution feed to the capture system 72 once C02 has been separated from the rich solution. During the regeneration process, the rich ionic ammonia solution is heated so that C02 contained in the solution separates from the chilled ammonia solution. Once separated from the C02, ammonia (ammonia slip) is returned to the capture system for use in capturing further C02 from a gas stream. These currently known solvent based C02 capture technologies typically consume approximately 20-30% of the power generated by the power generation system in order for the C02 capture process to work effectively. In addition, these technologies often require a large portion of thermal energy generated by boiler/re-boiler functions (reboiler duty) in order to regenerate amine solution for re-use in capturing C02 from a flue gas stream. In short, while there are known 4 technologies for capturing CO 2 from a flue gas stream, they require immense amounts of energy in order to function well. Further, in order to maximize/optimize the amount of time that flue gas is in contact with amine, the physical size of the absorber and/or re-generator tanks in a typical system must be very large. The cost to design and implement these towers of such large scale is very high. Additionally, the physical space that is required on-site to accommodate these vessels is significant. Where on-site space is limited, additional steps must be taken to implement the vessels/system in the limited space, if possible. Any discussion of documents, devices, acts or knowledge in this specification is included to explain the context of the invention. It should not be taken as an admission that any of the material formed part of the prior art base or the common general knowledge in the relevant art in Australia on or before the priority date of the claims herein. Summary Of the Invention In accordance with a first aspect of the invention, there is provided a mixed gas processing system including: a regeneration tower containing packing materials coated with a catalyst, a carbon dioxide rich solvent inlet arranged for contact of a carbon dioxide rich solvent with the packing material, wherein the catalyst promotes the release of carbon dioxide within the carbon dioxide rich solvent to produce a carbon dioxide lean solvent. In accordance with another aspect of the invention, there is provided a process for cleaning a mixed gas stream including: providing carbon dioxide rich solvent including carbon dioxide and a solvent to a regeneration tower; passing the carbon dioxide rich solvent through a regeneration tower containing packing materials arranged for contact between the carbon dioxide rich solvent and the packing materials, wherein the packing material is coated with a catalyst to promote release of carbon dioxide within the carbon dioxide rich solvent. Comprises/comprising and grammatical variations thereof when used in this specification are to be taken to specify the presence of stated features, integers, steps or components or groups thereof, but do not preclude the presence or addition of one or more other features, integers, steps, components or groups thereof.
Other systems, methods, features, and advantages of the present invention will be or become apparent to one with skill in the art upon examination of the following drawings and detailed description. It is intended that all such additional systems, methods, features, and advantages be included within this 5 description, be within the scope of the present invention, and be protected by the accompanying claims. Brief Description of the Drawings Many aspects of the invention can be better understood with reference to io the following drawings. The components in the drawings are not necessarily to scale, emphasis instead being placed upon clearly illustrating the principles of the present invention. Moreover, in the drawings, like reference numerals designate corresponding parts throughout the several views. The invention will now be described in more detail with reference to the appended drawings in which: 15 FIG. 1A - FIG. 1C are diagram generally depicting a typical flue gas processing system 15 with provisions for CO 2 removal. FIG. 2A - FIG. 2D are diagrams generally illustrating an example of packing materials 315 on which a catalyst capable of holding CO 2 has been immobilized on the wall/surfaces of the packing materials 315. 20 FIG. 3 is a diagram generally depicting relevant portions of an amine or ammonia based CO 2 capture system 70 in which absorber 110 and regenerator 330 are provided with packing materials 315 and 335, respectively that have been coated with a catalyst capable of holding CO 2 . 25 Discussion The proposed invention is directed to increasing CO 2 removal efficiency in a solvent based (amine/ammonia) C02 removal system/process. In one embodiment, generally depicted in FIG. 2A - FIG. 3, a mass transfer device MTD 315 (or packing materials) composed of, for example, one or more support 30 structures 320 is provided and disposed within the interior of an absorber vessel 110 (FIG. 3). The support structure(s) 320 is coated with a catalyst 425. FIG. 2A - FIG. 2D are diagrams generally depicting packing materials 315 that have been coated with a solid material capable of holding CO 2 425. FIG. 2B and 2C shows that the packing materials 315 may be composed of, for example, -5a series of corrugated support structures 320 arranged in close proximity to each other so as to form a series of channels 334 through which flue gas entering the absorber vessel 110 flow. The catalyst 425 is coated on one or more surfaces of each corrugated support structures 320. 5 The catalyst coated on the support structure(s) 320 will preferably be a heterogeneous catalyst. Further the catalyst 425 will preferably have a moderate basicity I interaction with CO 2 and high specific surface area, for example, 100 1000 m 2 /g. Preferably the catalyst 425 will be a commercially available catalyst having a high BET (Brunauer, Emmett and Teller) surface area and porosity 10 (polymer, metal oxides, SiO 2 , molecular sieves, etc.), which should be able to store or retain CO 2 with moderate interaction (basicity) with the catalyst. Surface basicity may be tuned by, for example, surface modification using alkali /alkali earth metal or transition metal oxide in order to enhance CO 2 adsorption capacity. The catalyst 425 can be immobilized onto the support structures(s) 320 15 by using, for example, known wash-coating techniques. In operation, the flue gas stream is contacted with the packing materials 315 and thus, the support structure 320 that is coated (layered) with the catalyst 425 capable of holding/retaining C02 from the flue gas stream for at least a period of time. By retaining C02 on the catalyst disposed on the support 20 structure 320, the C02 is exposed to solvent flowing through the packing materials 115, counter current to the flue gas stream, for a longer period of time, thus increasing the likelihood that the CO 2 will be captured by the solvent. In this way, it is possible to indirectly increase the residence time of the C02 contained in a flue gas stream with the solvent (amine/ammonia) in absorber 25 tower 110 and thus, increase the amount of CO 2 that will be adsorbed onto the surface of the solid materials. In order to do this, it is proposed in one embodiment of the proposed invention, that a solid material capable of holding (adsorbing) C02 for a period of time be immobilized (coated) on one or more surfaces of the packing materials 315 used in the absorber tower 110 (FIG. 3)) of 30 a solvent based C02 capture system. FIG. 3 is a diagram generally depicting relevant portions of an solvent based (example: amine or ammonia) based C02 capture system 300 for use in processing a flue gas stream from, for example, a fossil fuel fired boiler of a power generation plant. The system 300 includes an absorber tower 110 that -6includes packing materials 315 that are coated with a catalyst 425 on one or more surfaces. A regeneration tower 330 is provided and includes packing materials 339 that are coated with a catalyst 425 on one or more surfaces. While the invention has been described with reference to a number of 5 preferred embodiments, it will be understood by those skilled in the art that various changes may be made and equivalents may be substituted for elements thereof without departing from the scope of the invention. In addition, many modifications may be made to adapt a particular situation or material to the teachings of the invention without departing from the essential scope thereof. 10 Therefore, it is intended that the invention not be limited to the particular embodiments disclosed as the best mode contemplated for carrying out this invention, but that the invention will include all embodiments falling within the scope of the appended claims. Moreover, the use of the terms first, second, etc. do not denote any order or importance, but rather the terms first, second, etc. are 15 used to distinguish one element from another. -7-
Claims (15)
1. A flue gas processing system comprising: absorber tower configured to receive a mixed gas stream containing carbon dioxide and to contact it with a solvent; and the absorber tower comprises packing materials that are coated with a io catalyst.
2. The system of claim 1 wherein the catalyst is a heterogeneous catalyst.
3. The system of claim 1 wherein said flue gas system is an amine based 15 flue gas processing system.
4. The system of claim 3 wherein the catalyst provided to promote the capture of carbon dioxide within the flue gas stream with amine. 20
5. The system of claim 1 wherein said mixed gas system is ammonia based mixed gas processing system.
6. A mixed gas processing system comprising: regeneration tower configured to receive a carbon dioxide rich amine 25 stream; and the regeneration tower comprises packing materials that are coated/immobilized with a catalyst.
7. The system of claim 6 wherein the catalyst is a heterogeneous catalyst. 30 -8-
8. A mixed gas processing system comprising: regeneration tower configured to receive a carbon dioxide rich ammonia stream; and the regeneration tower comprises packing materials that are coated with a 5 catalyst.
9. The system of claim 8 wherein the catalyst is a heterogeneous catalyst.
10. A mixed gas processing system comprising an absorber tower configured 10 to receive a flue gas stream and an amine feed supply that includes a catalyst.
11. The system of claim 10 wherein the absorber tower is configured to cause the flue gas stream to contact amine/catalyst from the amine feed supply. 15
12. A mixed gas processing system comprising: absorber tower configured to receive a flue gas stream; and the absorber tower comprises packing materials that are coated/immobilized with a catalyst which can be used to activate CO 2 adsorbed onto its surfaces and catalyse carbonation/bi-carbonation and carbonation of 20 amine with CO 2 .
13. A mixed gas processing system comprising: regeneration tower configured to receive a carbon dioxide rich amine stream; and the regeneration tower comprises packing materials that are 25 coated/immobilized with a catalyst which can be used to catalyse the decomposition of products formed from the carbonation/bi-carbonation and carbonation of amine with CO 2 . -9-
14. A mixed gas processing system comprising: regeneration tower configured to receive a carbon dioxide rich ammonia stream; and the regeneration tower comprises packing materials that are 5 coated/immobilized with a catalyst which can be used to catalyse the decomposition of products formed from the reaction/interaction of ammonia with CO 2 .
15. A mixed gas processing system comprising an absorber tower configured 10 to receive a flue gas stream and an amine feed supply that includes a catalyst which can be used to catalyse CO 2 capture using amine/ammonia at low temperature and also the decomposition of products formed from the reaction/interaction of ammonia with CO 2 at high temperature. 15 - 10-
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| AU2012216559A AU2012216559A1 (en) | 2008-03-21 | 2012-08-31 | A system and method for enhanced removal of CO2 from a mixed gas stream |
Applications Claiming Priority (4)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US61/038,494 | 2008-03-21 | ||
| US12/406,360 | 2009-03-18 | ||
| AU2009225587A AU2009225587B2 (en) | 2008-03-21 | 2009-03-19 | A system and method for enhanced removal of CO2 from a mixed gas stream |
| AU2012216559A AU2012216559A1 (en) | 2008-03-21 | 2012-08-31 | A system and method for enhanced removal of CO2 from a mixed gas stream |
Related Parent Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| AU2009225587A Division AU2009225587B2 (en) | 2008-03-21 | 2009-03-19 | A system and method for enhanced removal of CO2 from a mixed gas stream |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| AU2012216559A1 true AU2012216559A1 (en) | 2012-09-20 |
Family
ID=46846080
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| AU2012216559A Abandoned AU2012216559A1 (en) | 2008-03-21 | 2012-08-31 | A system and method for enhanced removal of CO2 from a mixed gas stream |
Country Status (1)
| Country | Link |
|---|---|
| AU (1) | AU2012216559A1 (en) |
Cited By (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| WO2014142668A3 (en) * | 2013-03-14 | 2014-12-04 | Stamicarbon B.V. Acting Under The Name Of Mt Innovation Center | Cos and cs2 abatement method |
| CN113491946A (en) * | 2020-04-08 | 2021-10-12 | 中石化南京化工研究院有限公司 | Absorbent regeneration equipment and regeneration method |
-
2012
- 2012-08-31 AU AU2012216559A patent/AU2012216559A1/en not_active Abandoned
Cited By (7)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| WO2014142668A3 (en) * | 2013-03-14 | 2014-12-04 | Stamicarbon B.V. Acting Under The Name Of Mt Innovation Center | Cos and cs2 abatement method |
| US9765272B2 (en) | 2013-03-14 | 2017-09-19 | Stamicarbon B.V. Acting Under The Name Of Mt Innovation Center | COS and CS2 abatement method |
| EA030955B1 (en) * | 2013-03-14 | 2018-10-31 | Стамикарбон Б.В. Эктин Андер Те Нейм Оф Мт Инновейшн Сентр | Cos and csabatement method |
| US10865355B2 (en) | 2013-03-14 | 2020-12-15 | Stamicarbon B.V. | COS and CS2 abatement method |
| US11331623B2 (en) | 2013-03-14 | 2022-05-17 | Stamicarbon B.V. Acting Under The Name Of Mt Innovation Center | COS and CS2 abatement method |
| CN113491946A (en) * | 2020-04-08 | 2021-10-12 | 中石化南京化工研究院有限公司 | Absorbent regeneration equipment and regeneration method |
| CN113491946B (en) * | 2020-04-08 | 2023-04-11 | 中国石油化工股份有限公司 | Absorbent regeneration equipment and regeneration method |
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Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| MK4 | Application lapsed section 142(2)(d) - no continuation fee paid for the application |