Separating carbon dioxide and hydrogen sulfide from a natural gas stream using co-current contacting systems

Patent metadata

Field	Value
Publication number	US-10343107-B2
Application number	US-201715433168-A
Country	US
Kind code	B2
Filing date	Feb 15, 2017
Priority date	May 9, 2013
Publication date	Jul 9, 2019
Grant date	Jul 9, 2019

Abstract

Systems and methods for separating CO 2 and H 2 S from a natural gas stream are provided herein. The system includes a first loop of co-current contacting systems configured to remove H 2 S and CO 2 from a natural gas stream and a second loop of co-current contacting systems configured to remove the H 2 S from the CO 2 .

First claim

What is claimed is:

1. A system for separating H 2 S and CO 2 from a natural gas stream, comprising:
a first loop of co-current contacting systems configured to remove H 2 S and CO 2 from a natural gas stream, the first loop of co-current contacting systems including
a first series of co-current contacting systems configured to remove the H 2 S and the CO 2 from the natural gas stream by contacting the natural gas stream with a solvent stream, providing for incorporation of the H 2 S and the CO 2 from the natural gas stream into the solvent stream, and;
a second series of co-current contacting systems configured to remove the H 2 S and the CO 2 from the solvent stream, wherein the solvent stream is recirculated to the first series of co-current contacting systems; and

a second loop of co-current contacting systems configured to remove the H 2 S from the CO 2 , the second loop of co-current contacting systems including
a third series of co-current contacting systems configured to remove the H 2 S from the CO 2 by contacting the H 2 S and the CO 2 with an H 2 S-selective solvent stream, providing for incorporation of the H 2 S into the H 2 S-selective solvent stream, and
a fourth series of co-current contacting systems configured to remove the H 2 S from the H 2 S-selective solvent stream, wherein the H 2 S-selective solvent stream is recirculated to the third series of co-current contacting systems;

wherein each of the co-current contacting systems includes
a co-current contactor located in-line within a pipe, the co-current contactor including
a mixer, including
an annular support ring configured to maintain the mixer within the pipe,
a number of radial blades extending from the annular support ring and configured to allow a liquid stream to flow into the mixer, and
a central gas entry cone supported by the number of radial blades and configured to allow a gas stream to flow through a hollow section within the mixer, and

a mass transfer section downstream of the mixer,
wherein the mixer and the mass transfer section provide for efficient incorporation of liquid droplets formed from the liquid stream into the gas stream; and

a separation system configured to remove the liquid droplets from the gas stream.

2. The system of claim 1 , further comprising:
a hollow channel in the annular support ring and the plurality of radial blades, the hollow channel being configured to permit the liquid stream to be flowed therethrough into the mixer; and
injection orifices disposed on the plurality of radial blades, the injection orifices being configured to thereby inject the liquid stream into the gas stream.

3. The system of claim 1 , further comprising gas exit slots included in the plurality of radial blades, wherein a first portion of the gas stream flows through a hollow section in the central gas entry cone and through the gas exit slots.

4. A system for separating CO 2 and H 2 S from a natural gas stream, comprising:
a first series of co-current contacting systems configured to contact a sour natural gas stream comprising CO 2 and H 2 S with a lean solvent stream to generate a sweetened natural gas stream and a rich solvent stream comprising the CO 2 and the H 2 S;
a second series of co-current contacting systems configured to contact the rich solvent stream with a stripping gas to regenerate the lean solvent stream and generate a first gas stream comprising the CO 2 , the H 2 S, and the stripping gas, wherein the lean solvent stream is recirculated to the first series of co-current contacting systems;
a third series of co-current contacting systems configured to contact the first gas stream with a lean H 2 S-selective solvent stream to generate a rich H 2 S-selective solvent stream comprising the H 2 S and a second gas stream comprising the CO 2 and the stripping gas; and
a fourth series of co-current contacting systems configured to contact the rich H 2 S-selective solvent stream with a stripping gas to regenerate the lean H 2 S-selective solvent stream and generate a third gas stream comprising the H 2 S and the stripping gas, wherein the lean H 2 S-selective solvent stream is recirculated to the third series of co-current contacting systems;
wherein each of the first series of co-current contacting systems, the second series of co-current contacting systems, the third series of co-current contacting systems, and the fourth series of co-current contacting systems includes a number of co-current contacting systems connected in series; and
wherein each of the number of co-current contacting systems includes:
a co-current contactor located in-line within a pipe, the co-current contactor including:
a mixer, including:
an annular support ring configured to maintain the mixer within the pipe;
a number of radial blades extending from the annular support ring and configured to allow a liquid stream to flow into the mixer; and
a central gas entry cone supported by a number of radial blades and configured to allow a gas stream to flow through a hollow section within the mixer; and

a mass transfer section downstream of the mixer;
wherein the mixer and the mass transfer section provide for efficient incorporation of liquid droplets formed from the liquid stream into the gas stream; and

a separation system configured to remove the liquid droplets from the gas stream.

5. The system of claim 4 , wherein the separation system comprises a cyclonic separator.

6. The system of claim 4 , wherein a downstream portion of the central gas entry cone comprises a blunt ended cone.

7. The system of claim 4 , wherein a downstream portion of the central gas entry cone comprises a tapered ended cone.

8. The system of claim 4 , wherein the H 2 S-selective solvent stream comprises a tertiary amine.

9. The system of claim 4 , wherein the H 2 S-selective solvent stream comprises a sterically-hindered amine.

10. The system of claim 4 , wherein the stripping gas comprises nitrogen.

11. The system of claim 4 , wherein the system comprises a CO 2 separation system configured to remove the CO 2 from the second gas stream to recover a final CO 2 product.

12. The system of claim 11 , wherein the stripping gas from the second gas stream is recirculated to the second series of co-current contacting systems.

13. The system of claim 4 , wherein the system comprises a H 2 S separation system configured to remove the H 2 S from the third gas stream to recover a final H 2 S product.

14. The system of claim 13 , wherein the stripping gas from the third gas stream is recirculated to the fourth series of co-current contacting systems.

15. The method of claim 4 , wherein the liquid stream is flowed into the co-current contactor via a hollow channel in the annular support ring and the plurality of radial blades, and further comprising:
injecting the liquid stream into the gas stream via injection orifices disposed on the plurality of radial blades.

16. The method of claim 4 , wherein a first portion of the gas stream flows through a hollow section in the central gas entry cone and through gas exit slots included in the plurality of radial blades.

Assignees

• Northrop Paul Scott
• Mart Charles J
• Cullinane J Tim
• Exxonmobil Upstream Res Co

Inventors

• Northrop Paul Scott
• Mart Charles J
• Cullinane J Tim

Classifications

• B01D53/14 Primary

  by absorption · CPC title

• B01D53/18

  Absorbing units; Liquid distributors therefor (B01D3/16, B01D3/26, B01D3/30 take precedence; packing elements B01J19/30, B01J19/32) · CPC title

• B01D53/1462

  Removing mixtures of hydrogen sulfide and carbon dioxide · CPC title

• C01B32/50

  Carbon dioxide · CPC title

• B01D2257/30

  Sulfur compounds · CPC title