WO2010110939A1

WO2010110939A1 - Gas stream processing

Info

Publication number: WO2010110939A1
Application number: PCT/US2010/022710
Authority: WO
Inventors: Frederic Z. Kozak; Arlyn V. Petig; Vikram Shabde
Original assignee: Alstom Technology Ltd
Priority date: 2009-03-27
Filing date: 2010-02-01
Publication date: 2010-09-30
Also published as: IL215347A0; MA33215B1; MX2011010135A; BRPI1010274A2; EP2411120A1; RU2011143323A; ZA201107046B

Abstract

A power generation plant (112), a method, and a CO2 capture system (122) for removing carbon dioxide (104) from a flue gas stream (106) are disclosed. As shown in FIG. 2, a CO2 capture system (122), comprises an absorber vessel (202), a water wash vessel (210), and a stripper (214). The CO2 capture system (122) can be configured to introduce both a lean ionic ammonia solution (204) from a regeneration system (124) and a flue gas stream (106) from a cooling system (120) and to provide a rich ionic ammonia solution (206) to a regeneration system (124), wherein the introduction of the lean ionic ammonia solution (204) to the flue gas stream (106) produces a flue gas substantially devoid CO2 (224). The water wash vessel (210) can be configured to receive the flue gas substantially devoid CO2 (224) and produce ammoniated water (212) by introducing water (218) to the flue gas substantially devoid CO2 (224). The stripper (214) can be configured to receive the ammoniated water (212) and to remove ammonia (216) from the ammoniated water (212) thereby producing a cleaned flue gas stream (116), the stripper (214) being operable in at least partial vacuum conditions.

Description

GAS STREAM PROCESSING

FIELD

[0001] This technology relates to systems and methods for removing carbon dioxide from gas streams including carbon dioxide and sulfur dioxide.

BACKGROUND

[0002] 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 process gas or flue gas is generated. Such a flue gas will often contain, among other things, carbon dioxide (CO₂) and sulfur dioxide (SO₂). The negative environmental effects of releasing carbon dioxide to the atmosphere have been widely recognized, 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.

[0003] Known systems include chilled ammonia based systems. Chilled ammonia based systems can capture and/or remove CO₂ from a gas stream. For example, absorption of CO₂ from a gas stream can be achieved by contacting a chilled ionic ammonia solution (or slurry) with a flue gas stream that contains CO₂. These systems can include strippers for removing ammonia from water and returning the water to the process. The strippers operate at predetermined temperatures. The operating temperature affects energy efficiency.

[0004] What is needed is a method and system permitting the reduction of the operational temperature for strippers in gas stream processing.

SUMMARY

[0005] According to aspects illustrated herein, there is provided a CO₂ capture system for removing carbon dioxide from a flue gas stream, the CO₂ capture system comprising an absorber vessel configured to introduce both a lean ionic ammonia solution from a regeneration system and the flue gas stream from a cooling system and configured to provide a rich ionic ammonia solution to the regeneration system, wherein the introduction of the lean ionic ammonia solution and the flue gas stream reacts to produce a flue gas substantially devoid of CO₂. A water wash vessel is configured to receive flue gas from the absorber and produce ammoniated water. A stripper is configured to receive the ammoniated water and is configured to remove ammonia from the ammoniated water thereby producing a cleaned flue gas stream, the stripper being operable in at least partial vacuum conditions.

[0006] According to other aspects illustrated herein, there is provided a power generation plant, comprising a CO₂ capture system for removing carbon dioxide from a flue gas stream, the CO₂ capture system comprising an absorber vessel configured to introduce a lean ionic ammonia solution from a regeneration system and the flue gas stream from a cooling system. The ammonia solution and the flue gas react in the absorber vessel. The absorber vessel is further configured to discharge a rich ionic ammonia solution to the regeneration system, wherein the interaction of the lean ionic ammonia solution with the flue gas stream produces an absorber flue gas stream substantially devoid of CO₂. A water wash vessel is configured to receive the absorber flue gas. It introduces water, mixing the two, producing ammoniated water. A stripper is configured to receive the ammoniated water and remove ammonia from the ammoniated water, thereby producing a cleaned flue gas stream, the stripper being operable in at least partial vacuum conditions. The cooling system reduces the temperature of the flue gas stream, then provides the flue gas stream to the CO₂ capture system, and then receives the cleaned flue gas stream from the CO₂ capture system after CO₂ removal. The regeneration system is configured to receive the rich ionic ammonia solution from the CO₂ capture system, remove ammonia, and provide the lean ionic ammonia solution to the CO₂ capture system, wherein the lean ionic ammonia solution is an absorbent ionic ammonia solution. The absorbent ionic ammonia solution is an aqueous solution comprising water, ammonium ions, bicarbonate ions, carbonate ions, and carbamate ions, and wherein heat for operating the stripper is provided by a reject water stream from a power plant, the reject water stream being provided at a temperature of about 90° F.

[0007] According to other aspects illustrated herein, there is provided a method for removing carbon dioxide from flue gas streams, comprising in an absorber vessel, reacting a lean ionic ammonia solution from a regeneration system and a flue gas stream from a cooling system. A rich ionic ammonia solution resulting from the reaction in the absorber vessel is provided to the regeneration system. The introduction of the lean ionic ammonia solution to the flue gas stream in the absorber vessel produces an absorber flue gas stream substantially devoid of CO₂. The absorber flue gas is introduced in the water wash vessel and intermixed with water thereby producing ammoniated water. Discharged water may be returned to the water wash vessel or otherwise recycled. The ammoniated water is then transported from the water wash vessel to a stripper, where ammonia is removed from the ammoniated water thereby producing a cleaned flue gas stream, the stripper being operable in at least partial vacuum conditions.

[0008] The above described and other features are exemplified by the following figures and detailed description.

BRIEF DESCRIPTION OF THE DRAWINGS

[0009] Referring now to the figures, which are exemplary embodiments, and wherein the like elements are numbered alike:

FIG. 1 is a schematic representation of a power generation plant including a system for removing CO₂ from a flue gas stream;

FIG. 2 is a schematic representation of a CO₂ capture system in a system for removing CO₂ from a flue gas stream; and

FIG. 3 is a schematic representation of a CO₂ removal system including a cooling system, a CO₂ capture system, and a regeneration system.

DETAILED DESCRIPTION

[0010] A method and system permitting the reduction of the operational temperature for strippers and the removal of carbon dioxide in gas stream processing is provided.

[0011] Referring to FIG. 1, a flue gas processing system 102 can remove pollutants (for example, CO₂ 104) from a flue gas stream 106 emitted by a combustion chamber 108 of a boiler system 110. System 102 can be used in a power generation plant 112. System 102 can include a CO₂ removal system 114 configured to remove CO₂ from flue gas stream 106 prior to emitting a cleaned flue gas stream 116 (for example, to an exhaust stack 118 or for additional processing). CO₂ removal system 114 can transport CO₂ removed from flue gas stream 106 for storage, collection, or other use. CO₂ removal system 114 can include a cooling system 120 for cooling flue gas stream 106 entering an additional cooling system (not shown), a CO₂ capture system 122 for capturing/removing CO₂ from flue gas stream 106, and/or a regeneration system 124 for regenerating an ionic ammonia solution used to remove CO₂ from flue gas stream 106. Cooling system 120 can be any suitable cooling system configured to provide flue gas stream 106 to CO₂ capture system 122 and receive a cleaned flue gas stream 116 from CO₂ capture system 122.

[0012] In an exemplary embodiment, system 102 may further include a dust removal system 126. Dust removal system 126 can receive flue gas stream 106 emitted by combustion chamber 108. Dust removal system 126 can remove dust, ash, and other particulate matter from flue gas stream 106 prior to flue gas stream 106 being processed by CO₂ removal system 114. In further exemplary embodiments, system 102 may further include suitable processing systems. For example, system 102 may include a scrubber 128 configured to further process flue gas stream 106 prior to flue gas stream 106 being processed by CO₂ removal system 114.

[0013] Referring to FIG. 2, CO₂ capture system 122 can include an absorber vessel 202 configured to apply an absorbent ionic ammonia solution (for example, a lean ionic ammonia solution 204) from regeneration system 124 to flue gas stream 106 coming from cooling system 120. For example, the absorbent ionic ammonia solution from regeneration system 124 can be co-mixed with flue gas stream 106 input coming from cooling system 120. The absorbent ionic ammonia solution can be aqueous and can include water and ammonium ions, bicarbonate ions, carbonate ions, and/or carbamate ions. Regeneration system 124 can be any suitable system configured to receive a rich ionic ammonia solution 206 from CO₂ capture system 122 and provide lean ionic ammonia solution 204 to CO₂ capture system 122. As used herein, the phrase "rich ionic ammonia solution" refers to ionic ammonia solution having an increased concentration of CO₂. For example, in one embodiment, the rich ionic ammonia solution 206 includes a ratio of ammonia : CO₂, which may be from about 1.5 : 1 to about 1.9 : 1. As used herein, the phrase "lean ionic ammonia solution" refers to ionic ammonia solution having a decreased concentration of CO₂ as compared to the rich ionic ammonia solution. For example, in one embodiment, the lean ionic ammonia solution 204 includes a ratio of ammonia : CO₂, which may be from about 2.3 : 1 to about 3.5 : 1.

[0014] Absorber vessel 202 can receive the lean ionic ammonia solution 204 from regeneration system 124. A liquid distribution system (not shown) can introduce lean ionic ammonia solution 204 into absorber vessel 202 while flue gas stream 106 is being received by absorber vessel 202.

[0015] A gas-liquid contacting device 205 (for example, a mass transfer device) can introduce absorbent ionic ammonia solution 204 into device 205 to contact and/or co-mix solution 204 with flue gas stream 106. The gas-liquid contacting device 205 can be a predetermined structure and/or random packing materials. For example, the gas-liquid contacting device 205 can include valve trays, sieve trays, structured packing, random packing or other suitable packing materials, or a combination thereof. Device 205 increases surface area of ionic ammonia solution 204, thereby increasing gas-liquid interface. The gas- liquid contacting device 205 can be located in absorber vessel 202 and within a path of flue gas stream 106.

[0016] Lean ionic ammonia solution 204 can absorb CO₂ from flue gas stream 106, thus increasing the concentration of CO₂ in a solution derived from lean ionic ammonia solution 204 being contacted and/or co-mixed with flue gas stream 106. This solution derived from lean ionic ammonia solution 204 can be rich ionic ammonia solution 206. Rich ionic ammonia solution 206 can flow toward gas-liquid contacting device 205 and then be collected. For example, solution 206 can be collected in absorber vessel 202.

[0017] Rich ionic ammonia solution 206 can then flow to regeneration system 124. In regeneration system 124, rich ionic ammonia solution 206 can release CO₂ absorbed by lean ionic ammonia solution 204. The released CO₂ can be collected and/or transported for storage and/or use. Upon releasing CO₂, the resulting ionic ammonia solution has a lower concentration of CO₂ and thereby can be recycled as lean ionic ammonia solution 204. The recycled lean ionic ammonia solution 204 can be reused to absorb CO₂ from flue gas stream 106 or an additional flue gas stream.

[0018] The flue gas stream 106 containing ammonia leaving absorber vessel 202 after interaction with lean ionic ammonia solution 204 can be directed to water wash vessel 210 where it interacts with water. Water wash vessel 210 can remove ammonia 216 that may be present in flue gas substantially devoid CO₂ 224 thereby producing ammoniated water 212. Additionally or alternatively, ammoniated water 212 may be provided by regeneration system 124. Thus, the source of ammoniated water 212 may be water wash vessel 210, lean ionic ammonia solution 204, regeneration system 124, or combinations thereof. Ammoniated water 212 can be directed to stripper 214. Stripper 214 can remove ammonia 216 from ammoniated water 212 and return water 218 back to water wash vessel 210. Ammonia 216 removed from water wash vessel 210 can be returned to absorber vessel 202. [0019] Stripper 214 can operate at a predetermined temperature. Generally, the predetermined temperature is a boiling point of water at a given operating pressure. Decreasing the boiling point of water can improve efficiency of stripper 214 by decreasing the predetermined temperature. Such a reduction in the predetermined temperature permits additional sources of heat to be effective. For example, in a power plant, the predetermined temperature may be about 90° F when the source is at a pressure of about 0.70 pounds-force per square inch absolute ("psia"). Thus, in the power plant, a reject water stream having a temperature of about 90° F can be the source of heat for operating stripper 214 when pressure is correspondingly reduced.

[0020] Referring again to FIG. 2, in an exemplary embodiment of system 102, stripper 214 can be heated by any suitable source with a lower temperature under lower pressure. Stripper 214 can be part of CO₂ capture system 122 within CO₂ removal system 114. Stripper 214 can include a stripper vessel 222 and a vacuum pump 220. Stripper vessel 222 can be any suitable vessel (for example, a generally cylindrically-shaped vessel (for example, a steel vessel) configured to operate within a predetermined pressure range). Stripper vessel 222 can include one or more suitable gas-liquid contacting devices 205 (for example, a mass transfer device) as described above. Stripper vessel 222 can include a heater (not shown) for providing temperature control of liquid collected in stripper vessel 222. For example, the heater can heat the liquid collected in the bottom of stripper vessel 222. Vacuum pump 220 can generate at least partial vacuum conditions for stripper vessel 222. The at least partial vacuum conditions can be generated by a vacuum pump (not shown) or steam jet injector. Thus, stripper 214 can be operated as a vacuum stripper. Operating the vacuum stripper under at least partial vacuum conditions can permit use of a water source within lower temperature ranges. The at least partial vacuum conditions are known and can be found in available steam tables. As stripper 214 approaches full evacuation, the source used can be of a lower temperature. Thus, the desired amount of heat for stripper 214 can be reduced by increased evacuation. In exemplary embodiments, the at least partial vacuum conditions of stripper 214 include a pressure of less than about 10 psia. In other exemplary embodiments, the at least partial vacuum conditions of stripper 214 include a pressure of less than about 1 psia.

[0021] FIG. 3 shows a further exemplary embodiment of power generation plant 112 including cooling system 120, CO₂ capture system 122, and regeneration system 124. In the embodiment, cooling system 120 can include a first vessel 302 configured to cool cleaned flue gas stream 116 prior to cleaned flue gas stream 116 being sent to exhaust stack 118. First vessel 302 can receive water 218 from a water source. Heat from the gas stream is exchanged with the water and water is sent to a cooling tower 304. In an open system, water is circulated through the cooling tower, some of which evaporates, the remainder being returned to the first vessel and supplemented with water from the water source, such as a river, lake, or stream. In a closed loop system, water is circulated though the cooling tower and is returned to the first vessel. Cooling tower 304 can be any suitable cooling mechanism. In one embodiment, cooling tower 304 receives air 306 and cools heated water 218 prior to air 306 being released into the atmosphere, into another process, or stored. In one embodiment, second vessel 308 may receive flue gas stream 106 from another system (for example, boiler system 110). Second vessel 308 is configured to provide ammonia scrubbing of SO₂ by reacting flue gas stream 106 with chilled water 218 from first vessel 302 to form ammonium sulfate. A portion of the flue gas stream 106 can then form a bleed 310, which may be used in another process or stored. The remaining portion of flue gas stream 106 can flow to CO₂ capture system 122.

[0022] The exemplary embodiment of CO₂ capture system 122 in FIG. 3 can include features identified above with reference to FIG. 2. In addition, CO₂ capture system 122 can include one or more buffer tanks 312 for providing flow control and/or a volume for storage of lean ionic ammonia solution 204 and/or rich ionic ammonia solution 206. Additionally or alternatively, CO₂ capture system 122 can include cooling tower 304 and chiller arrangement 322 for cooling water 218 to be used in water wash vessel 210. As will be appreciated, additional heat exchangers, pumps, flow control devices, and other process control systems/apparatus may be included for further regulating the flow of flue gas stream 106, lean ionic ammonia solution 204, rich ionic ammonia solution 206, water 218, ammoniated water 212, ammonia 216, flue gas substantially devoid of CO₂ 224, or other suitable process fluids.

[0023] Regeneration system 124 can receive rich ionic ammonia solution 206 from CO₂ capture system 122. Regeneration system 124 can include a heat exchanger 314 for transferring heat from lean ionic ammonia solution 204 directed toward CO₂ capture system 122 to rich ionic ammonia solution 206 heading toward a main column 316 of regeneration system 124. Regeneration system 124 can further include a direct contact cooler 318 and a treatment system 320 for purifying CO₂ 104 prior to its release, storage, or use. [0024] Operation of an embodiment including the vacuum stripper 222 according to the embodiments disclosed herein can increase energy efficiency by permitting use of a source to drive the vacuum stripper within lower temperature ranges. Such operation can clean gas being emitted by industrial processes. Additionally or alternatively, such operation can permit sequestration of CO₂ to be more efficient.

[0025] While the invention has been described with reference to various exemplary 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. Therefore, it is intended that the invention not be limited to the particular embodiment 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.

Claims

CLAIMSWhat is claimed is:

1. A CO₂ capture system for removing carbon dioxide from a flue gas stream, the CO₂ capture system comprising: an absorber vessel configured to introduce both a lean ionic ammonia solution from a regeneration system and the flue gas stream from a cooling system, wherein the lean ionic ammonia solution interacts with the flue gas stream to provide a rich ionic ammonia solution to the regeneration system, wherein the introduction of the lean ionic ammonia solution to the flue gas stream further produces a flue gas substantially devoid of CO₂; a water wash vessel configured to receive the flue gas substantially devoid of CO₂ and produce ammoniated water by introducing water to the flue gas substantially devoid of CO₂; and a stripper configured to receive the ammoniated water and configured to remove ammonia from the ammoniated water thereby producing a cleaned flue gas stream, the stripper being operable in at least partial vacuum conditions.

2. The CO₂ capture system of claim 1, wherein the at least partial vacuum conditions include a pressure of less than about 10 psia.

3. The CO₂ capture system of claim 1, wherein the at least partial vacuum conditions include a pressure of less than about 1 psia.

4. The CO₂ capture system of claim 1, wherein heat for operating the stripper is provided by a reject water stream from a power generation plant, the reject water stream having a temperature of about 90° F.

5. The CO₂ capture system of claim 1, wherein the lean ionic ammonia solution includes a ratio of ammonia to CO₂ from about 2.3:1 to about 3.5:1.

6. The CO₂ capture system of claim 1, wherein the rich ionic ammonia solution includes a ratio of ammonia to CO₂ from about 1.5:1 to about 1.9:1.

7. The CO₂ capture system of claim 1, further comprising the cooling system configured to cool and provide the flue gas stream to the CO₂ capture system and configured to receive the cleaned flue gas stream from the CO₂ capture system.

8. The CO₂ capture system of claim 1, further comprising the regeneration system configured to receive the rich ionic ammonia solution from the CO₂ capture system and provide the lean ionic ammonia solution to the CO₂ capture system while removing CO₂.

9. The CO₂ capture system of claim 1, wherein the CO₂ capture system is part of a power generation plant.

10. The CO₂ capture system of claim 9, wherein the power generation plant further comprises a boiler system having a combustion chamber.

11. The CO₂ capture system of claim 1 , wherein the lean ionic ammonia solution is an aqueous solution further comprising water, ammonium ions, bicarbonate ions, carbonate ions, and carbamate ions.

12. The CO₂ capture system of claim 1, further comprising a gas-liquid contacting device configured to contact the lean ionic ammonia solution with the flue gas stream.

13. The CO₂ capture system of claim 12, wherein the gas-liquid contacting device includes a first gas-liquid contacting device having a predetermined structure and a second gas-liquid contacting device having a random structure.

14. A power generation plant, comprising: a CO₂ capture system for removing carbon dioxide from a flue gas stream, the CO₂ capture system comprising: an absorber vessel configured to introduce a lean ionic ammonia solution from a regeneration system and the flue gas stream from a cooling system, wherein the lean ionic ammonia solution interacts with the flue gas stream to provide a rich ionic ammonia solution to the regeneration system, wherein the introduction of the lean ionic ammonia solution to the flue gas stream further produces a flue gas substantially devoid of CO₂; a water wash vessel configured to receive the flue gas substantially devoid of CO₂ and water thereby producing ammoniated water; and a stripper configured to receive the ammoniated water and remove ammonia from the ammoniated water, thereby producing a cleaned flue gas stream, ammonia, and reclaimed water, the stripper being operable in at least partial vacuum conditions; the cooling system configured to provide the flue gas stream to the CO₂ capture system after reducing the temperature of the flue gas stream and configured to receive the cleaned flue gas stream from the CO₂ capture system; and the regeneration system configured to receive the rich ionic ammonia solution from the CO₂ capture system and provide the lean ionic ammonia solution to the CO₂ capture system; and, wherein the lean ionic ammonia solution is an absorbent ionic ammonia solution, the absorbent ionic ammonia solution being an aqueous solution comprising water, ammonium ions, bicarbonate ions, carbonate ions, and carbamate ions, and wherein heat for operating the stripper is provided by a reject water stream from a power generation plant, the reject water stream being provided at a temperature of about 90° F.

15. The CO₂ capture system of claim 14, wherein the lean ionic ammonia solution includes a ratio of ammonia to CO₂ from about 2.3:1 to about 3.5:1 and the rich ionic ammonia solution includes a ratio of ammonia to CO₂ from about 1.5:1 to about 1.9:1.

16. A method for removing carbon dioxide from flue gas streams, comprising: interacting a lean ionic ammonia solution from a regeneration system and a flue gas stream from a cooling system in an absorber vessel; providing a rich ionic ammonia solution resulting from the interaction in the absorber vessel to the regeneration system, wherein the introduction of the lean ionic ammonia solution to the flue gas stream in the absorber vessel further produces a flue gas substantially devoid CO₂; introducing the flue gas substantially devoid CO₂ to water in a water wash vessel thereby producing ammoniated water; providing ammoniated water from the water wash vessel to a stripper; and removing ammonia from the ammoniated water in the stripper thereby producing a cleaned flue gas stream, the stripper being operable in at least partial vacuum conditions.

17. The method of claim 16, wherein the at least partial vacuum conditions include a pressure of less than about 10 psia.

18. The method of claim 16, wherein the at least partial vacuum conditions include a pressure of less than about 1 psia.

19. The method of claim 16, further comprising operating the stripper with heat produced by a reject water stream from a power generation plant, the reject water stream having a temperature of about 90° F.

20. The method of claim 16, wherein the lean ionic ammonia solution includes a ratio of ammonia to CO₂ from about 2.3:1 to about 3.5:1 and the rich ionic ammonia solution includes a ratio of ammonia to CO₂ from about 1.5:1 to about 1.9:1.