Configurations and methods for removal of mercaptans from feed gases

• US 8,377,403 B2
• Filed: 07/30/2007
• Issued: 02/19/2013
• Est. Priority Date: 08/09/2006
• Status: Expired due to Fees

• Current Assignee: Fluor Technologies Corporation (Fluor Corporation)
• Original Assignee: Fluor Technologies Corporation (Fluor Corporation)
• Inventors: Mak, John
• Primary Examiner(s): Boyer, Randy
• Application Number:
  US12/375,337
• Publication Number:
  US 20110237856A1
• Time in Patent Office: 2,031 Days
• Field of Search: 952/09, 952/29, 952/35, 962/43, 423/242.1
• US Class Current: 423/242.1
• CPC Class Codes: B01D 2252/205 Other organic compounds not covered by B01D2252/00 - B01D2252/20494
• CPC Class Codes: B01D 2257/304 Hydrogen sulfide
• CPC Class Codes: B01D 2257/306 Organic sulfur compounds, e.g. mercaptans
• CPC Class Codes: B01D 2257/308 Carbonoxysulfide COS
• CPC Class Codes: B01D 2258/06 Polluted air
• CPC Class Codes: B01D 53/1431 Pretreatment by other processes
• CPC Class Codes: B01D 53/1487 Removing organic compounds
• CPC Class Codes: B01D 53/1493 Selection of liquid materials for use as absorbents
• CPC Class Codes: B01D 53/48 Sulfur compounds
• CPC Class Codes: C01B 17/0408 Pretreatment of the hydrogen sulfide containing gases
• CPC Class Codes: C01B 32/50 Carbon dioxide
• CPC Class Codes: C07C 319/28 Separation; Purification
• CPC Class Codes: C07C 321/04 of an acyclic saturated carbon skeleton
• CPC Class Codes: C10G 2300/202 Heteroatoms content, i.e. S, N, O, P
• CPC Class Codes: C10G 2300/207 Acid gases, e.g. H2S, COS, SO2, HCN
• CPC Class Codes: C10G 45/02 to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbons; Hydrofinishing
• CPC Class Codes: C10L 3/103 Sulfur containing contaminants
• CPC Class Codes: C10L 3/12 Liquefied petroleum gas liquefying by pressure and cold treatment F25J
• CPC Class Codes: Y02C 20/40 of CO2
• CPC Class Codes: Y02P 20/151 Reduction of greenhouse gas [GHG] emissions, e.g. CO2

Abstract

Contemplated configurations and methods employ COS hydrolysis and a downstream H2S removal unit to produce a treated feed gas that is then further desulfurized in an absorber using two lean oil fluids. The so produced mercaptan enriched hydrocarbon fluid is fed to a distillation column that produces a light overhead vapor that is preferably combined with the treated feed gas and a sulfur rich bottom product that is in most cases preferably directly fed to a hydrocarbon processing unit comprising a hydrotreater. In further especially preferred aspects, the hydrocarbon processing unit produces at least one and more typically both of the two lean oil fluids, and the treated gas is optionally further processed to produce clean fuel gas in a hydrotreater for olefinic saturation and sulfur conversion using a lean oil recycle for reactor temperature control.

Claims

1. A gas treatment plant comprising:

a COS hydrolysis unit configured to hydrolyze COS in a mercaptan-containing feed gas to form a treated feed gas;

an absorber fluidly coupled to the COS hydrolysis unit and further fluidly coupled to a first and a second conduit that are configured to provide a first and a second lean hydrocarbon fluid to the absorber;

wherein the absorber is configured to allow contacting of the treated feed gas with the first and a second lean hydrocarbon fluid to thereby produce a mercaptan enriched hydrocarbon fluid and a desulfurized product gas;

a distillation column coupled to the absorber and configured to receive the mercaptan enriched hydrocarbon fluid and further configured to produce a light overhead vapor and a sulfur rich bottom product; and

a hydrocarbon processing unit comprising a hydrotreater, wherein the hydrocarbon processing unit is fluidly coupled to the distillation column and configured to receive the sulfur rich bottom product and to produce a sulfur-containing product and at least one of the first and second lean hydrocarbon fluid.

2. The plant of claim 1 further comprising an H₂S removal unit fluidly coupled to the COS hydrolysis unit and configured to remove H₂S from the treated feed gas prior to feeding the treated feed gas into the absorber.

3. The plant of claim 1 further comprising a conduit that is configured to feed the light overhead product to the treated feed gas.

4. The plant of claim 1 wherein the hydrocarbon processing unit is configured to produce the first and the second lean hydrocarbon fluid.

5. The plant of claim 4 further comprising first and second coolers that are configured to cool the first and the second lean hydrocarbon fluid.

6. The plant of claim 4 further comprising a second absorber that is fluidly and upstream coupled to the absorber, wherein the second absorber is configured to receive the treated feed gas and to produce an overhead gas and a second mercaptan enriched hydrocarbon fluid, and wherein the second absorber is further configured to provide the overhead gas to the absorber.

7. The plant of claim 6 wherein the first conduit is configured to provide the first lean hydrocarbon fluid to the overhead gas prior to entering the absorber.

8. The plant of claim 1 further comprising an absorber overhead condenser and reflux drum configured to produce a reflux to the absorber as the first lean hydrocarbon fluid via the first conduit, wherein the second conduit is configured to combine the desulfurized product gas with the second lean hydrocarbon fluid in a location upstream of the reflux drum, and wherein the overhead condenser is optionally configured to cool the first and second lean hydrocarbon fluids.

9. The plant of claim 1 wherein the treated gas is further processed in a hydrotreater and COS hydrolysis reactor for saturation of the olefinic hydrocarbons and conversion of the residual mercaptans using a recycled lean oil to control the reactor temperatures sufficiently to eliminate fouling.

10. The plant of claim 1 wherein the distillation column and the hydrocarbon processing unit are fluidly coupled to each other such that the sulfur rich bottom product is fed to the hydrocarbon processing unit without passing through a catalytic oxidation unit.

11. A method of removing sulfur compounds from a feed gas, comprising:

hydrolyzing COS in a sulfur and mercaptan-containing feed gas to form a treated feed gas;

absorbing sulfur species from the treated feed gas in an absorber using a first and a second lean hydrocarbon fluid to thereby produce a mercaptan enriched fluid and a desulfurized product gas;

separating the mercaptan enriched fluid in a distillation column to produce a light overhead vapor and a sulfur rich bottom product; and

processing the sulfur rich bottom product in a hydrocarbon processing unit that has a hydrotreater to produce a sulfur-containing product and at least one of the first and second lean hydrocarbon fluid.

12. The method of claim 11 further comprising a step of removing H₂S in an H₂S removal unit prior to feeding the treated feed gas into the absorber.

13. The method of claim 11 further comprising a step of feeding the light overhead vapor to the treated feed gas.

14. The method of claim 11 wherein the hydrocarbon processing unit that has the hydrotreater produces the first and second lean hydrocarbon fluid.

15. The method of claim 14 further comprising a step of cooling the first and the second lean hydrocarbon fluid.

16. The method of claim 14 further comprising a step of providing a second absorber that is fluidly and upstream coupled to the absorber, wherein the second absorber receives the treated feed gas and produces an overhead gas and a second mercaptan enriched hydrocarbon fluid, and wherein the second absorber provides the overhead gas to the absorber.

17. The method of claim 16 wherein the first lean hydrocarbon fluid is combined with the overhead gas prior to entering the absorber.

18. The method of claim 11 further comprising providing an absorber overhead condenser and reflux drum to produce a reflux to the absorber as the first lean hydrocarbon fluid, and combining the desulfurized product gas with the second lean hydrocarbon fluid in a location upstream of the reflux drum.

19. The method of claim 18 wherein the absorber overhead condenser cools the first and second lean hydrocarbon fluids.

20. The method of claim 11 wherein the sulfur rich bottom product is fed to the processing unit without passing through a catalytic oxidation unit.