Sulfur recovery within a gas processing system

Patent metadata

Field	Value
Publication number	US-11535515-B2
Application number	US-202016984463-A
Country	US
Kind code	B2
Filing date	Aug 4, 2020
Priority date	Aug 20, 2019
Publication date	Dec 27, 2022
Grant date	Dec 27, 2022

Abstract

A method for recovering sulfur within a gas processing system is described herein. The method includes contacting a natural gas stream including an acid gas with a solvent stream within a co-current contacting system to produce a sweetened natural gas stream and a rich solvent stream including an absorbed acid gas. The method also includes removing the absorbed acid gas from the rich solvent stream within a regenerator to produce a concentrated acid gas stream and a lean solvent stream. The method further includes recovering elemental sulfur from hydrogen sulfide (H2S) within the concentrated acid gas stream via a sulfur recovery unit.

First claim

What is claimed is:

1. A gas processing system, comprising:
a co-current contacting system configured to:
contact a natural gas stream comprising an acid gas with a solvent stream to produce a sweetened natural gas stream and a rich solvent stream comprising an absorbed acid gas; and
send the rich solvent stream to a regenerator;

the regenerator configured to:
remove the absorbed acid gas from the rich solvent stream to produce a concentrated acid gas stream and a lean solvent stream; and
send the concentrated acid gas stream to a sulfur recovery unit; and

the sulfur recovery unit configured to recover elemental sulfur from hydrogen sulfide (H2S) within the concentrated acid gas stream; and
the co-current contacting system further comprising:
a co-current contactor located in-line within a pipe, the co-current contactor comprising:
an annular support ring configured to maintain the co-current contactor within the pipe;
a plurality of radial blades configured to allow the solvent stream to flow into the co-current contactor; and
a central gas entry cone configured to allow the natural gas stream to flow through a hollow section within the co-current contactor;
wherein the co-current contactor provides for efficient incorporation of liquid droplets formed from the solvent stream into the natural gas stream such that the acid gas from the natural gas stream is absorbed by the liquid droplets; and

a separation system configured to remove the liquid droplets comprising the absorbed acid gas from the natural gas stream, producing the sweetened natural gas stream and the rich solvent stream.

2. The gas processing system of claim 1 , wherein the sulfur recovery unit comprises:
an absorber configured to contact the concentrated acid gas stream with a chelated iron solution to produce a treated gas stream and a concentrated solution comprising the chelated iron solution and sulfur;
an oxidizer configured to separate the concentrated solution into a sulfur slurry, a vent gas stream, and a regenerated chelated iron solution; and
a sulfur filter configured to produce a sulfur cake from the sulfur slurry.

3. The gas processing system of claim 1 , wherein the sulfur recovery unit comprises:
an oxidizer configured to contact the concentrated acid gas stream with a chelated iron solution to produce a sulfur slurry; and
a sulfur filter configured to produce a sulfur cake from the sulfur slurry.

4. The gas processing system of claim 1 , wherein the sulfur recovery unit comprises:
a contactor configured to contact the concentrated acid gas stream with an aqueous bicarbonate solution such that the H2S within the concentrated acid gas stream is absorbed into the aqueous bicarbonate solution as bisulfide ions;
a bioreactor configured to contact the aqueous bicarbonate solution comprising the bisulfide ions with Thiobacillus bacteria to produce a sulfur-containing solution;
a settler configured to produce a sulfur slurry from the sulfur-containing solution; and
a sulfur filter configured to produce a sulfur cake from the sulfur slurry.

5. The gas processing system of claim 1 , wherein the sulfur recovery unit utilizes a modified liquid-phase Claus reaction.

6. The gas processing system of claim 1 , wherein the solvent stream comprises an H2S-selective solvent stream.

7. The gas processing system of claim 1 , wherein the gas processing system is configured to send the lean solvent stream from the regenerator back into the co-current contacting system as the solvent stream.

8. The gas processing system of claim 1 , comprising a plurality of co-current contacting systems configured to produce a progressively sweetened natural gas stream and a progressively richer solvent stream comprising an increasing concentration of the absorbed acid gas, wherein at least one of the plurality of co-current contacting systems is configured to send a corresponding progressively richer solvent stream to the regenerator.

9. The gas processing system of claim 8 , wherein each of the plurality of co-current contacting systems is configured to recirculate a corresponding progressively richer solvent stream to a preceding one of the plurality of co-current contacting systems.

10. A method for recovering sulfur within a gas processing system, comprising:
contacting a natural gas stream comprising an acid gas with a solvent stream within a co-current contacting system to produce a sweetened natural gas stream and a rich solvent stream comprising an absorbed acid gas;
removing the absorbed acid gas from the rich solvent stream within a regenerator to produce a concentrated acid gas stream and a lean solvent stream; and
recovering elemental sulfur from hydrogen sulfide (H2S) within the concentrated acid gas stream via a sulfur recovery unit;
wherein contacting the natural gas stream comprising the acid gas with the solvent stream within the co-current contacting system comprises:
flowing the solvent stream into a co-current contactor via an annular support ring and a plurality of radial blades extending from the annular support ring, wherein the annular support ring secures the co-current contactor in-line within a pipe;
flowing the natural gas stream into the co-current contactor via a central gas entry cone that is supported by the plurality of radial blades, wherein a first portion of the natural gas stream flows through the central gas entry cone and a second portion of the natural gas stream flows around the central gas entry cone between the plurality of radial blades;
contacting the natural gas stream with the solvent stream to provide for incorporation of liquid droplets formed from the solvent stream into the natural gas stream such that the acid gas from the natural gas stream is absorbed by the liquid droplets; and
separating the liquid droplets comprising the absorbed acid gas from the natural gas stream within a separator, producing the sweetened natural gas stream and the rich solvent stream.

11. The method of claim 10 , wherein recovering the elemental sulfur from the H2S within the concentrated acid gas stream via the sulfur recovery unit comprises:
contacting the concentrated acid gas stream with a chelated iron solution within an absorber to produce a treated gas stream and a concentrated solution comprising the chelated iron solution and sulfur;
separating the concentrated solution into a sulfur slurry, a vent gas stream, and a regenerated chelated iron solution within an oxidizer; and
producing a sulfur cake from the sulfur slurry using a sulfur filter.

12. The method of claim 10 , wherein recovering the elemental sulfur from the H2S within the concentrated acid gas stream via the sulfur recovery unit comprises:
contacting the concentrated acid gas stream with a chelated iron solution within an oxidizer to produce a sulfur slurry; and
producing a sulfur cake from the sulfur slurry using a sulfur filter.

13. The method of claim 10 , wherein recovering the elemental sulfur from the H2S within the concentrated acid gas stream via the sulfur recovery unit comprises:
contacting the concentrated acid gas stream with an aqueous bicarbonate solution within a contactor such that the H2S within the concentrated acid gas stream is absorbed into the aqueous bicarbonate solution as bisulfide ions;
contacting the aqueous bicarbonate solution comprising the bisulfide ions with Thiobacillus bacteria within a bioreactor to produce a sulfur-containing solution;
producing a sulfur slurry from the sulfur-containing solution within a settler; and
producing a sulfur cake from the sulfur slurry using a sulfur filter.

14. The met

Assignees

• Exxonmobil Upstream Res Co

Inventors

• Northrop Paul Scott
• Cullinane John Timothy

Classifications

• B01D2252/20431

  Tertiary amines · CPC title

• B01D53/1462

  Removing mixtures of hydrogen sulfide and carbon dioxide · CPC title

• B01D53/1468 Primary

  Removing hydrogen sulfide · CPC title

• C01B17/0408

  Pretreatment of the hydrogen sulfide containing gases · CPC title

• B01D53/526

  Mixtures of hydrogen sulfide and carbon dioxide · CPC title