Hydrocarbon based sulfur solvent systems and methods

• US 7,988,767 B2
• Filed: 08/28/2007
• Issued: 08/02/2011
• Est. Priority Date: 08/31/2006
• Status: Expired due to Fees

• Current Assignee: Fluor Technologies Corporation (Fluor Corporation)
• Original Assignee: Fluor Technologies Corporation (Fluor Corporation)
• Inventors: Henderson, Robert, Debest, Michael, Nielsen, Richard B., Graham, Curt
• Primary Examiner(s): Smith; Duane
• Assistant Examiner(s): PATEL, PANKTI R
• Application Number:
  US12/376,632
• Publication Number:
  US 20100135880A1
• Time in Patent Office: 1,435 Days
• Field of Search: 952/35, 951/81, 951/86, 951/87, 951/88, 952/23, 208/208.R, 208/210, 208/211, 208/212, 423/220, 423/242.1, 423/573.1, 423/567.1
• US Class Current: 95/235
• CPC Class Codes: B01D 2257/304 Hydrogen sulfide
• CPC Class Codes: B01D 2257/306 Organic sulfur compounds, e.g. mercaptans
• CPC Class Codes: B01D 53/047 Pressure swing adsorption
• CPC Class Codes: B01D 53/1456 Removing acid components
• CPC Class Codes: C01B 17/033 using a liquid extractant
• CPC Class Codes: C01B 17/0404 by processes comprising a dry catalytic conversion of hydrogen sulfide-containing gases, e.g. the Claus process
• CPC Class Codes: C01B 17/162 from elemental sulfur and hydrogen
• CPC Class Codes: C10L 3/10 Working-up natural gas or synthetic natural gas
• CPC Class Codes: C10L 3/102 of acid contaminants

Abstract

Contemplated configurations and methods for elemental sulfur removal from various gases, and especially well acid gases employ a hydrocarbon solvent that dissolves the sulfur to form a rich solvent and that is then regenerated by hydrotreating. Thus, sulfur is removed from the rich solvent as H2S that may then be processed (e.g., in Claus unit or absorption unit) while the regenerated solvent is routed back to the well and associated production pipes.

Claims

1. A gas production plant comprising:

a well fluidly coupled to a separator, wherein the separator is configured to separate a well output into a gas portion and a rich solvent portion;

a hydrotreater that is fluidly coupled to the separator and configured to treat the rich solvent such as to allow production of an H2S product and a regenerated solvent; and

a recycling circuit that is configured to allow feeding of the regenerated solvent to at least one of a topside position of the well, a bottom hole position of the well, and a pipe transporting the well output to thereby allow formation of the rich solvent portion.

2. The production plant of claim 1 further comprising a treatment unit fluidly coupled to the hydrotreater and configured to produce a hydrogen-enriched recycle stream and an H2S enriched sour gas stream.

3. The production plant of claim 2 wherein the treatment unit comprises a separator selected from the group consisting of a membrane separation unit, a solvent-based adsorption unit, and a pressure swing adsorption unit.

4. The production plant of claim 2 further comprising a Claus unit fluidly coupled to the treatment unit and configured to receive the H2S enriched sour gas stream and to produce elemental sulfur.

5. The production plant of claim 1 further comprising a Claus unit fluidly coupled to the hydrotreater and configured to receive the H2S product and to produce elemental sulfur.

6. The production plant of claim 1 further comprising a dehydrogenator fluidly coupled to the hydrotreater and configured to dehydrogenate at least a portion or the regenerated solvent.

7. The production plant of claim 1 wherein the regenerated solvent comprises at least one of a naphthenic hydrocarbon, a paraffinic hydrocarbon, and an aromatic hydrocarbon.

8. The production plant of claim 1 further comprising a bypass that is configured to allow feeding a portion or the regenerated solvent from a position downstream of the hydrotreater to the well output in a position upstream of the hydrotreater or directly to the hydrotreater.

9. The production plant of claim 1 further comprising a surge tank or storage lank fluidly coupled to the hydrotreater and recycling circuit.

10. The production plant of claim 1 wherein the recycling circuit is configured to allow feeding of the regenerated solvent to at least two of the topside position of the well, the bottom hole position of the well, and the pipe transporting the well output.

11. A method of removing sulfur from a gas well output, comprising:

feeding a regenerated solvent to at least one of a topside position of a well, a bottom hole position of the well, and a pipe transporting the gas well output to thereby form a mixed well output that comprises dissolved sulfur;

separating the mixed well output into a rich solvent portion and a gas portion; and

hydrotreating the rich solvent portion to thereby form an H2S product and the regenerated solvent.

12. The method of claim 11 wherein the solvent comprises at least one of a naphthenic hydrocarbon, a paraffinic hydrocarbon, and an aromatic hydrocarbon.

13. The method of claim 11 wherein hydrotreating is performed under conditions that maintain desaturation of the rich solvent and that convert at least a portion of the dissolved sulfur to H2S.

14. The method of claim 11 further comprising a step of desaturating at least a portion of the regenerated solvent.

15. The method of claim 11 further comprising a step of converting the H2S product to elemental sulfur in a downstream Claus unit.

16. The method of claim 11 wherein at least a portion of the regenerated solvent is used as recycle feed in the hydrotreating step.

17. A method of regenerating a rich sulfur solvent with a dissolved sulfur concentration of at least 5 wt %, wherein the rich sulfur solvent is formed upstream of a separator and provided from a gas well, the method comprising a step of hydrotreating the rich solvent to thereby form an H2S product and a regenerated solvent.

18. The method of claim 17 wherein the H2S product is further processed to produce a hydrogen-enriched recycle stream and an H2S enriched sour gas stream.

19. The method of claim 17 wherein at least part of the regenerated solvent is fed to at least one of a topside position of a well, a bottom hole position of the well, and a pipe transporting a well output to thereby form the rich solvent.

20. The method of claim 17 wherein the hydrotreating is performed under conditions that maintain desaturation of the rich solvent and that convert at least a portion of the dissolved sulfur to H2S.