Sweetening of natural gas

Patent metadata

Field	Value
Publication number	US-9227889-B2
Application number	US-201313862859-A
Country	US
Kind code	B2
Filing date	Apr 15, 2013
Priority date	Apr 15, 2013
Publication date	Jan 5, 2016
Grant date	Jan 5, 2016

Abstract

An exemplary embodiment can be a process for sweetening natural gas to liquefied natural gas specifications. The process can include providing a membrane contactor having a lumen side and a shell side. A feed natural gas is introduced to the lumen side of the membrane contactor. An absorption solvent is introduced to the shell side of the membrane contactor. CO 2 and H 2 S are removed with the absorption solvent from the feed natural gas resulting in a sweetened natural gas containing less than 50 ppmv CO 2 and less than 4 ppmv H 2 S. Corresponding or associated systems for such sweetening of natural gas are also provided.

First claim

What is claimed is:

1. A process for sweetening natural gas to liquefied natural gas specifications comprising:
providing a membrane contactor having a lumen side and a shell side and with a membrane packing configuration to minimize at least one of channeling and bypassing;
introducing a feed natural gas to the lumen side of the membrane contactor;
introducing an absorption solvent to the shell side of the membrane contactor; and
removing CO 2 and H 2 S with the absorption solvent from the feed natural gas resulting in a sweetened natural gas containing less than 50 ppmv CO 2 and less than 4 ppmv H 2 S.

2. The process of claim 1 wherein the membrane contactor comprises hollow fibers.

3. The process of claim 2 wherein the membrane contactor comprises super-hydrophobic hollow fibers.

4. The process of claim 1 wherein the absorption solvent comprises an amine solvent.

5. The process of claim 4 wherein the absorption solvent comprises DEA.

6. The process of claim 4 wherein the absorption solvent comprises MDEA.

7. The process of claim 1 wherein at least said step of removing CO 2 and H 2 S with the absorption solvent occurs on a floating platform.

8. The process of claim 7 wherein at least said step of removing CO 2 and H 2 S with the absorption solvent occurs offshore.

9. The process of claim 1 wherein said removing CO 2 and H 2 S with the absorption solvent results in a CO 2 and H 2 S containing solvent stream and said process additionally comprising:
stripping CO 2 and H 2 S from the CO 2 and H 2 S containing solvent stream to form a regenerated absorption solvent; and
recycling at least a portion of the regenerated absorption solvent to the shell side of the hollow fiber membrane contactor.

10. The process of claim 9 wherein at least said step of stripping CO 2 and H 2 S from the CO 2 and H 2 S containing solvent stream occurs on a floating platform.

11. The process of claim 1 wherein the feed natural gas contains in excess of 3% CO 2 and in excess of 50 ppmv H 2 S.

12. The process of claim 11 wherein the feed natural gas contains in 5% to 40% CO 2 and 100 ppmv to 40% H 2 S.

13. A process for sweetening natural gas to liquefied natural gas specifications on an offshore platform, barge or ship, said process comprising:
providing a hollow fiber membrane contactor having a lumen side and a shell side and with a membrane packing configuration to minimize at least one of channeling and bypassing;
introducing a feed natural gas to the lumen side of the hollow fiber membrane contactor;
introducing an absorption solvent to the shell side of the hollow fiber membrane contactor;
removing CO 2 and H 2 S from the feed natural gas with the absorption solvent to form a CO 2 and H 2 S containing solvent stream and a sweetened natural gas stream containing less than 50 ppmv CO 2 and less than 4 ppmv H 2 S;
stripping CO 2 and H 2 S from the CO 2 and H 2 S containing solvent stream to form a regenerated absorption solvent; and
introducing at least a portion of the regenerated absorption solvent to the shell side of the hollow fiber membrane contactor.

14. The process of claim 13 wherein the feed natural gas contains in excess of 3% CO 2 and in excess of 50 ppmv H 2 S.

15. The process of claim 14 wherein the feed natural gas contains in 5% to 40% CO 2 and 100 ppmv to 1000 ppmv H 2 S.

16. The process of claim 13 wherein the absorption solvent comprises an amine solvent selected from the group consisting of DEA and MDEA.

17. The process of claim 13 wherein the hollow fiber membrane contactor comprises super-hydrophobic hollow fibers.

18. The process of claim 1 wherein said introducing of the feed natural gas to the lumen side of the membrane contactor is countercurrent to said introducing of the absorption solvent to the shell side of the membrane contactor.

19. The process of claim 2 wherein said hollow fibers are arranged in a helical path with an axis of the fibers running confluent to the principle direction of fluid flow.

20. The process of claim 3 wherein said super-hydrophobic hollow fibers comprise PEEK hollow fibers with a water breakthrough pressure greater than 600 psig.

Assignees

• Zhou Shaojun
• Meyer Howard S
• Gas Technology Inst

Inventors

• Zhou Shaojun
• Meyer Howard S

Classifications

• B01D2257/504

  Carbon dioxide · CPC title

• B01D69/08

  Hollow fibre membranes (manufacture of hollow fibres D01D5/24, D01F1/08) · CPC title

• C10L3/10

  Working-up natural gas or synthetic natural gas · CPC title

• C10L2290/548

  Membrane- or permeation-treatment for separating fractions, components or impurities during preparation or upgrading of a fuel · CPC title

• C10L3/103

  Sulfur containing contaminants · CPC title