Methods of Generating and Utilizing Utility Gas

• US 20100212493A1
• Filed: 10/14/2008
• Published: 08/26/2010
• Est. Priority Date: 11/12/2007
• Status: Active Grant

• Current Assignee: Bruce T. Kelley, Harry W. Deckman, Paul L. Tanaka, Peter C. Rasmussen, Stanley O. Uptigrove
• Original Assignee: Bruce T. Kelley, Harry W. Deckman, Paul L. Tanaka, Peter C. Rasmussen, Stanley O. Uptigrove
• Inventors: Tanaka, Paul L., Deckman, Harry W., Kelley, Bruce T., Rasmussen, Peter C., Uptigrove, Stanley O.
• Granted Patent: US 8,906,138 B2
• Time in Patent Office: Days
• US Class Current: 95/45
• CPC Class Codes: B01D 2256/10 Nitrogen
• CPC Class Codes: B01D 2257/302 Sulfur oxides
• CPC Class Codes: B01D 2257/304 Hydrogen sulfide
• CPC Class Codes: B01D 2257/504 Carbon dioxide
• CPC Class Codes: B01D 2257/80 Water
• CPC Class Codes: B01D 53/04 with stationary adsorbents B01D53/025 takes precedence
• CPC Class Codes: F04D 29/104 the sealing fluid being other than the working fluid or being the working fluid treated
• CPC Class Codes: F04D 29/124 with special means for adducting cooling or sealing fluid
• CPC Class Codes: Y02C 20/40 of CO2

Abstract

The present application is directed to a method and system for preparing gaseous utility streams from gaseous process streams, nitrogen process streams, and other types of streams. The methods and systems may include at least one swing adsorption process including pressure swing adsorption, temperature swing adsorption, and rapid-cycle adsorption processes to treat gaseous streams for use in dry gas seals of rotating equipment such as compressors, turbines and pumps and for other utilities. The systems and processes of the present disclosure are further applicable to high pressure gaseous streams, for example, up to about 600 bar.

Claims

1. A method of treating a gaseous feed stream, comprising:

producing a gaseous feed stream;

dividing at least a portion of the gaseous feed stream to form a gaseous slip stream;

separating the gaseous slip stream using a selective component removal system having at least one swing adsorption process unit to form a utility stream for use in a utility component;

feeding the first utility stream into the utility component, wherein the utility stream is compatible with the utility component; and

utilizing the utility stream in the utility component.

2. The method of claim 1, wherein the gaseous slip stream is at least one of a hydrocarbon containing feed stream, a nitrogen-rich stream, at least a portion of a high pressure process stream, and at least a portion of a compressor discharge stream.

3. The method of claim 2, wherein the gaseous slip stream is at a pressure above the critical point of the gaseous feed stream.

4. The method of claim 3, wherein the gaseous slip stream is at a pressure of from at least about 100 bar to at least about 500 bar.

5. The method of claim 3, wherein the gaseous slip stream is at a pressure of from at least about 200 bar to at least about 320 bar.

6. The method of claim 1 wherein at least one of the at least one utility component is selected from the group consisting of a compressor, a dry seal compressor, a compressor string, a turbo-expander compressor, a turbo-expander generator, a pump, a fired steam boiler, a fired process heater, a gas engine, a hermetically sealed direct-drive electric motor, turbomachinery equipped with magnetic bearings, gas-operated instruments and controls, and a gas turbine.

7. The method of claim 1 wherein the utility component is located remotely from a gas processing plant.

8. The method of claim 1 wherein the utility stream is utilized as a dry seal gas for at least one of a dry gas seal, a labyrinth seal, and a mechanical seal in the at least one utility component.

9. The method of claim 1 wherein the at least one swing adsorption process unit is selected from the group of units consisting of a pressure swing adsorption (PSA) unit, a thermal swing adsorption (TSA) unit, a partial pressure swing or displacement purge adsorption (PPSA) unit, a rapid cycle thermal swing adsorption (RCTSA) unit, a rapid cycle pressure swing adsorption (RCPSA) unit, a rapid cycle partial pressure swing or displacement purge adsorption (RCPPSA) unit, a compact PSA, a compact TSA, a compact PPSA, and any combination thereof.

10. The method of claim 1 wherein the selective component removal system (SCRS) further comprises at least one of an absorption unit, a membrane separation unit, a molecular sieve, a distillation tower, and a glycol contactor.

11. The method of claim 1 wherein the utility stream is a non-condensible gas stream at an operating temperature and pressure of the utility component.

12. The method of claim 1 wherein the utility stream has a composition, wherein the composition remains in the gaseous phase throughout its utilization in the utility component.

13. The method of claim 1 wherein the utility stream has a composition, wherein the composition is substantially free of toxic and corrosive components.

14. The method of claim 13, wherein the toxic and corrosive components include at least one of H₂S, CO₂, H₂O, and SO₂.

15. The method of claim 1 wherein the utility stream has a composition, wherein the composition is substantially completely made up of inert components.

16. The method of claim 15, wherein the inert components include at least one of nitrogen and carbon dioxide.

17. The method of claim 1 wherein the swing adsorption process is performed inside a secondary pressure vessel.

18. The method of claim 17, wherein the secondary pressure vessel is maintained at an inside pressure of from at least about 100 bar to at least about 600 bar.

19. The method of claim 18, wherein the secondary pressure vessel is maintained at an inside pressure of from at least about 200 bar to at least about 500 bar.

20. The method of claim 1, further comprising exchanging heat to or from the swing adsorption process unit by a heat exchanger selected from the group consisting of internal electric heating, jacket cooling, and any combination thereof.

21. A method of treating a nitrogen-rich gaseous stream, comprising:

producing a nitrogen-rich gaseous stream;

separating at least a portion of the nitrogen-rich gaseous stream using a selective component removal system having at least one swing adsorption process unit to form a utility stream for use in a utility component;

feeding the utility stream into the utility component, wherein the utility stream is compatible with the utility component; and

utilizing the utility stream in the utility component.

22. A system for treating a gaseous feed stream, comprising:

a tubular member containing a gaseous feed stream operatively connected to a selective component removal system including at least one swing adsorption process unit, wherein the selective component removal system is utilized to separate at least a portion of the gaseous feed stream to form a utility stream; and

a utility component configured to receive and utilize the utility stream, wherein the utility stream is compatible with the utility component.

23. The system of claim 22, wherein the gaseous slip stream is at least one of a hydrocarbon containing feed stream, a nitrogen-rich stream, at least a portion of a high pressure process stream, and at least a portion of a compressor discharge stream.

24. The system of claim 22 wherein the utility component is at least one of a compressor, a dry seal compressor, a compressor string, a turbo-expander compressor, a turbo-expander generator, a pump, a fired steam boiler, a fired process heater, a gas engine, a hermetically sealed direct-drive electric motor, turbomachinery equipped with magnetic bearings, gas-operated instruments and controls, and a gas turbine.

25. The system of claim 22 wherein the at least one swing adsorption process unit is selected from the group of units consisting of a pressure swing adsorption (PSA) unit, a thermal swing adsorption (TSA) unit, a partial pressure swing or displacement purge adsorption (PPSA) unit, a rapid cycle thermal swing adsorption (RCTSA) unit, a rapid cycle pressure swing adsorption (RCPSA) unit, a rapid cycle partial pressure swing or displacement purge adsorption (RCPPSA) unit, a compact PSA, a compact TSA, a compact PPSA, and any combination thereof.

26. The system of claim 22 wherein the utility stream is utilized as a dry seal gas for at least one of a dry gas seal, a labyrinth seal, and a mechanical seal in the at least one utility component.