Power generation system and processes thereof, including adsorbing heat exchangers for CO2 capture from fossil fuel consumption

Patent metadata

Field	Value
Publication number	US-9316123-B2
Application number	US-201113581234-A
Country	US
Kind code	B2
Filing date	Feb 25, 2011
Priority date	Feb 25, 2010
Publication date	Apr 19, 2016
Grant date	Apr 19, 2016

Abstract

The present invention generally relates to power generation systems configured to absorb and capture a component, such as carbon dioxide, in a flue gas for later sequestration or utilization, wherein heat generated in the sorption process is captured for use in the power generation system. In some examples, the heat of sorption is used to preheat fluids in one or more systems of the power generation system to reduce the heating load on the subsystem. By using the heat of sorption, the carbon dioxide capture and sequestration process not only reduces or eliminates the concentration of carbon dioxide in the flue gas, but reduces or eliminates the parasitic effect of carbon dioxide capture and sequestration on power generation.

First claim

What is claimed is:

1. A power generation system comprising;
a boiler system comprising:
a combustion chamber for combusting one or more fossil fuels to produce combustion heat and a flue gas comprising a component to be sorbed; and
a steam generation chamber receiving the combustion heat from the combustion chamber and applying the combustion heat to water to produce steam at a first temperature and a first pressure;

a turbine receiving the steam from the steam generation chamber of the boiler system, wherein the turbine outputs spent steam having a second temperature and a second pressure, wherein the second temperature and the second pressure are lower than the first temperature and the first pressure;
a condenser condensing the spent steam from the turbine, wherein the condenser outputs a feedwater stream having a third temperature lower than the second temperature; and
a component capture system that receives as an input the feedwater stream having the third temperature and the flue gas comprising the component to be sorbed, wherein the component capture system comprises a sorbing media that:
sorbs at least a portion of the component in the flue gas;
generates sorption heat; and
transfers at least a portion of the sorption heat to the feedwater stream having the third temperature to increase the temperature of the feedwater stream to a fourth temperature, wherein the feedwater stream having the fourth temperature serves as the water of the steam generation chamber of the boiler system to which the combustion heat is applied.

2. The power generation system of claim 1 , wherein the component to be sorbed is carbon dioxide.

3. The power generation system of claim 1 , wherein the sorbing media is selected from the group consisting of hollow fiber tubes containing zeolite, chilled ammonia, and one or more liquid amines.

4. The power generation system of claim 1 , wherein the sorbing media comprises a hollow fiber tube comprising:
a hollow inner core receiving at least a portion of the feedwater stream having the third temperature and outputting the feedwater stream having the fourth temperature;
a zeolite packing disposed around the hollow inner core; and
an impermeable membrane disposed between the hollow inner core and the zeolite packing to limit fluid flow from the hollow inner core to the zeolite packing.

5. The power generation system of claim 1 , wherein the sorbing media is a plurality of hollow fiber tubes in a packed bed arrangement.

6. The power generation system of claim 1 , wherein the component capture system comprises a plurality of component capture subsystems.

7. The power generation system of claim 6 , wherein the plurality of component capture subsystems comprise a first component capture subsystem, a second component capture subsystem and a third component capture subsystem, each component capture subsystem independently operating in one or more of an online mode for sorbing at least a portion of the component in the flue gas, a desorption mode for desorbing at least a portion of the sorbed component, and a standby mode.

8. The power generation system of claim 7 , wherein at least one of the plurality of component capture systems further comprises an inlet for introducing nitrogen gas during an initial gas removal phase after the desorption mode.

9. The power generation system of claim 6 , wherein at least one of the plurality of component capture systems further comprise:
a first outlet for outputting a first output gas during an initial gas removal phase; and
a second outlet for outputting a second output gas during a secondary gas removal phase after the initial gas removal phase.

10. The power generation system of claim 9 , wherein the second output gas has a higher component concentration than the first output gas.

11. The power generation system of claim 8 , wherein the nitrogen gas increases an internal pressure of the at least one of the plurality of component capture subsystems to push at least a portion of the component desorbed out of the at least one of the plurality of component capture subsystems.

12. The power generation system of claim 1 , wherein the component capture system further comprises a steam net to increase the temperature of the sorbing media to cause the sorbing media to desorb at least a portion of the sorbed component.

13. A process for generating power, the process comprising:
combusting one or more fossil fuels to produce combustion heat and a flue gas comprising a component to be sorbed;
producing steam having a first temperature and a first pressure using the combustion heat;
generating the power in the form of electricity from the steam having the first temperature and the first pressure to produce spent steam with a second temperature and a second pressure, wherein the second temperature and the second pressure are lower than the first temperature and the first pressure;
condensing the spent steam to produce low temperature feedwater; and
sorbing at least a portion of the component in the flue gas in a sorbing media to produce sorption heat, wherein the sorption heat is transferred to the low temperature feedwater to produce a preheated feedwater used to produce the steam having the first temperature and the first pressure.

14. The process of claim 13 , wherein the component to be sorbed is carbon dioxide.

15. The process of claim 13 , wherein the sorbing media is selected from a group consisting of hollow fiber tubes containing zeolite, chilled ammonia, and one or more liquid amines.

16. The process of claim 13 , further comprising placing a first component capture subsystem in an online mode to sorb at least a portion of the component.

17. The process of claim 16 , further comprising placing a second component capture subsystem in a desorption mode to desorb at least a portion of the component.

18. The process of claim 17 , wherein placing the second component capture subsystem in the desorption mode to desorb the component comprises increasing a temperature of the at least a portion of the sorbing media using steam to cause the at least a portion of the sorbing media to desorb at least a portion of the sorbed component.

19. The process of claim 18 , further comprising introducing nitrogen gas in an initial gas removal phase into the second component capture subsystem after the desorption mode.

20. The process of claim 19 , further comprising opening a valve in a first position to output a first output gas during the initial gas removal phase and opening the valve to a second position for outputting a second output gas during a secondary gas removal phase after the initial gas removal stage.

Assignees

• Lively Ryan Paul
• Koros William John
• Chance Ron
• Georgia Tech Res Inst

Inventors

• Lively Ryan Paul
• Koros William John
• Chance Ron

Classifications

• F01K17/06 Primary

  Returning energy of steam, in exchanged form, to process, e.g. use of exhaust steam for drying solid fuel or plant · CPC title

• Y02E20/32

  Direct CO2 mitigation · CPC title

• Y02C20/40

  of CO2 · CPC title