Configurations and method for improved gas removal

• US 7,192,468 B2
• Filed: 04/15/2002
• Issued: 03/20/2007
• Est. Priority Date: 04/15/2002
• Status: Expired due to Term

• Current Assignee: Fluor Enterprises Incorporated (Fluor Corporation)
• Original Assignee: Fluor Technologies Corporation (Fluor Corporation)
• Inventors: Mak, John, Graham, Curt, Nielsen, Richard
• Primary Examiner(s): LAWRENCE JR, FRANK M
• Application Number:
  US10/478,350
• Publication Number:
  US 20050000360A1
• Time in Patent Office: 1,800 Days
• Field of Search: 951/60, 951/63, 951/72, 951/77, 951/69, 952/36, 951/91, 951/92, 952/03, 952/04, 952/28, 962/34, 962/42, 423/220, 423/226
• US Class Current: 95/160
• CPC Class Codes: B01D 53/1475 Removing carbon dioxide
• CPC Class Codes: C10L 3/10 Working-up natural gas or synthetic natural gas
• CPC Class Codes: C10L 3/102 of acid contaminants
• CPC Class Codes: Y02C 20/40 of CO2

Abstract

A plant includes an absorber (103) that operates in a gas phase supercritical region and removes an acid gas from a feed stream (9) at high recovery of the feed stream (10) while producing a high purity acid gas stream (36). Particularly preferred plants include gas purification plants that receive a feed gas with at least 5 mol % carbon dioxide at a pressure of at least 3000 psi.

Claims

1. A plant comprising:

an absorber that is configured to operate at a pressure that is supercritical for natural gas having a carbon dioxide content of between 10 mol % and 60 mol %, wherein the supercritical pressure is at least 2000 psig;

a gas source that is configured to provide a dehydrated natural gas-containing feed gas to the absorber at the supercritical pressure;

wherein the absorber is configured to produce a physical solvent that contains at least part of the carbon dioxide; and

a separator fluidly coupled to the absorber and configured to form a lean solvent and a carbon dioxide stream containing at least 95 mol % carbon dioxide from the physical solvent.

2. The plant of claim 1 further comprising an exchanger that is configured to cool the feed gas to a temperature above a hydrate point of the feed gas, and a dehydration unit that is configured to dehydrate the cooled feed gas before entering the absorber.

3. The plant of claim 1 wherein the gas source is configured to provide the feed gas at a pressure of at least 3000 psi.

4. The plant of claim 1 wherein the feed gas comprises natural gas.

5. The plant of claim 1 wherein the absorber is configured to employ propylene carbonate as physical solvent.

6. The plant of claim 1 further comprising a heat exchanger that is configured to provide cooling to the physical solvent using refrigeration content of the carbon dioxide stream.

7. The plant of claim 6 further comprising a second heat exchanger that is configured to provide cooling of the physical solvent in the absorber using refrigeration content of the cooled physical solvent.

8. The plant of claim 1 further comprising a hydraulic turbine that is configured to produce work from expansion of the physical.

9. The plant of claim 1 further comprising a vacuum separator that is configured to regenerate the physical solvent using lean gas and to thereby generate a fuel gas.

10. The plant of claim 2 wherein the absorber produces a product gas, and wherein the exchanger is further configured to cool the feed gas using the product gas.

11. The plant of claim 10 wherein the feed gas comprises natural gas, and wherein the absorber is configured to produce a product gas that comprises at least 99% of the natural gas.

12. The plant of claim 1 wherein the plant is further fluidly coupled to an enhanced oil recovery unit, and wherein the carbon dioxide stream is fed to the enhanced oil recovery.

13. A plant comprising:

an absorber that receives a feed gas at a pressure of at least 1000 psi and comprising at least 5 mol % carbon dioxide wherein the absorber employs a physical solvent to produce a rich solvent and a product gas that is at least partially depleted from the carbon dioxide;

a first turbine that depressurizes the rich solvent and a first separator that separates a first hydrocarbon portion from the depressurized rich solvent, thereby producing a first hydrocarbon recycle stream and a first rich solvent;

a second turbine that further depressurizes the first rich solvent and a cooler that employs the further depressurized first solvent to cool the physical solvent to maintain a bottom temperature of the absorber in a desired temperature range; and

wherein the further depressurized first solvent is separated in a second separator that separates a second hydrocarbon portion from the further depressurized first solvent, thereby producing a second hydrocarbon recycle stream and a second rich solvent, and wherein the first and second hydrocarbon recycle streams are fed into the absorber.

14. The plant of claim 13 wherein the feed gas is at least partially dehydrated.

15. The plant of claim 14 wherein the feed gas is cooled by the product gas and dehydrated in a dehydration unit before entering the absorber.

16. The plant of claim 13 wherein the first rich solvent is employed as a refrigerant to cool a carbon dioxide stream.

17. The plant of claim 13 wherein the second rich solvent is further depressurized to remove at least part of the carbon dioxide, thereby forming a lean solvent.

18. The plant of claim 17 wherein the lean solvent is further processed in a vacuum separator that employs a lean gas and produces a fuel gas, thereby regenerating the physical solvent.

19. The plant of claim 17 wherein the physical solvent comprises propylene carbonate.

20. The plant of claim 17 wherein the carbon dioxide is employed in an enhanced oil recovery.

21. The plant of claim 13 further comprising a stripper having at least two stripping sections separated by a collecting tray, and wherein the stripper regenerates the physical solvent.

22. A method of operating a plant, comprising:

providing an absorber that receives a feed gas at a pressure of at least 1000 psi wherein the feed gas comprises an acid gas;

removing at least part of the acid gas from the feed gas using a physical solvent, thereby forming a product gas and a rich solvent;

reducing pressure of the rich solvent to form a hydrocarbon recycle stream that is fed into the absorber, thereby producing a depressurized rich solvent;

using the depressurized rich solvent to cool the physical solvent, thereby maintaining a bottom temperature of the absorber in a desired temperature range and forming a heated depressurized rich solvent; and

separating the heated depressurized rich solvent into a stream containing at least a portion of the acid gas, thereby forming a lean solvent.

23. The method of claim 22 wherein the feed gas has a pressure of between about 1000 psi and about 3000 psi.

24. The method of claim 22 wherein the acid gas is carbon dioxide.

25. The method of claim 22 wherein the physical solvent comprises propylene carbonate.