Removal of acid gases from a gas stream, with O2 enrichment for acid gas capture and sequestration

Patent metadata

Field	Value
Publication number	US-11083994-B2
Application number	US-202016916983-A
Country	US
Kind code	B2
Filing date	Jun 30, 2020
Priority date	Sep 20, 2019
Publication date	Aug 10, 2021
Grant date	Aug 10, 2021

Abstract

A method and apparatus for processing a hydrocarbon gas stream including sulfurous components and carbon dioxide. The hydrocarbon gas stream is separated into a sweetened gas stream and an acid gas stream. The acid gas stream and an air stream, enriched with oxygen such that the air stream comprises between 22% and 100% oxygen, are combusted in a sulfur recovery unit to separate the acid gas stream into a liquid stream of elemental sulfur and a tail gas stream comprising acid gas impurities. The tail gas stream and an air flow are sub-stoichiometrically combusted to produce an outlet stream comprising hydrogen sulfide and carbon monoxide. The outlet stream is hydrogenated to convert sulfur species to a gaseous catalytic output stream comprising hydrogen sulfide. Water is removed from the gaseous catalytic output stream to produce a partially-dehydrated acid gas stream, which is pressurized and injected into a subsurface reservoir.

First claim

What is claimed is:

1. A gas processing facility for processing a hydrocarbon gas stream including sulfurous components and carbon dioxide, the gas processing facility comprising:
an acid gas removal facility for separating the hydrocarbon gas stream into
a sweetened gas stream and
an acid gas stream comprised primarily of hydrogen sulfide and carbon dioxide;

a Claus sulfur recovery unit (SRU) that receives the acid gas stream and an air stream, the air stream being enriched with oxygen such that the air stream comprises between 22% and 100% oxygen, the SRU combusting the acid gas stream and the atmospheric air to thereby separate the acid gas stream into
a liquid stream of elemental sulfur, and
a tail gas stream comprising acid gas impurities; and

a tail gas treating unit including
a reducing gas generator (RGG) that combusts fuel gas and the tail gas stream with an air flow, the RGG sub-stoichiometrically combusting the fuel gas and tail gas stream with the air flow to produce an RGG outlet stream comprising hydrogen sulfide (H 2 S) and carbon monoxide;
a catalytic bed configured to receive and hydrogenate the RGG outlet stream, thereby converting sulfur dioxide, carbonyl sulfide, mercaptans, and other sulfur species to a gaseous catalytic output stream comprising H 2 S;
a dehydration unit that removes water from the gaseous catalytic output stream to produce a partially-dehydrated acid gas stream; and
a compressor station for receiving the partially-dehydrated acid gas stream, and providing pressure to the partially-dehydrated acid gas stream for injection into a subsurface reservoir.

2. The gas processing facility of claim 1 , wherein the catalytic bed reduces oxidized sulfur species in the RGG outlet stream to H 2 S.

3. The gas processing facility of claim 1 , further comprising an absorber vessel and a regenerator vessel, the dehydration unit using an amine that absorbs both carbon dioxide and sulfurous components such that a majority of the carbon dioxide entering the tail gas treating unit is absorbed in the absorber vessel and released from the absorber vessel to the regenerator vessel in a rich solvent stream.

4. The gas processing facility of claim 3 , further comprising:
a condenser vessel for separating residual amine and condensed water from carbon dioxide and sulfurous components in an overhead gas stream of the regenerator; and
a line for directing the residual amine and condensed water back to the regenerator vessel;
and wherein the overhead acid gas stream from the regenerator vessel is taken through the condenser vessel for removal of residual amine and some water vapor before the overhead gas stream is delivered to the compressor station.

5. The gas processing facility of claim 3 , further comprising:
an acid gas enrichment facility for receiving the acid gas stream from the acid gas removal facility, and separating the acid gas stream into (i) an overhead CO 2 -rich stream, and (ii) an H 2 S-rich acid gas stream; and
wherein:
the acid gas stream received by the Claus sulfur recovery unit is the H 2 S-rich acid gas stream, and
the overhead CO 2 -rich stream is directed from the acid gas enrichment facility to the compressor station and placed under pressure for injection into the subsurface reservoir along with the partially-dehydrated acid gas stream.

6. The gas processing facility of claim 1 , further comprising:
a plurality of injection wells for transmitting the pressurized partially-dehydrated acid gas stream from the compressor station to the subsurface reservoir.

7. The gas processing facility of claim 1 , wherein the hydrocarbon gas stream comprises raw natural gas from a hydrocarbon production operation.

8. The gas processing facility of claim 1 , wherein the dehydration unit comprises a quench tower, and further comprising:
a cooler that cools at least part of the water removed from the gaseous catalytic output stream and returns at least part of the water to the quench tower.

9. A gas processing facility for processing a hydrocarbon gas stream including sulfurous components and carbon dioxide, the gas processing facility comprising:
an acid gas removal facility for separating the hydrocarbon gas stream into
a sweetened gas stream and
an acid gas stream comprised primarily of hydrogen sulfide and carbon dioxide;

a Claus sulfur recovery unit (SRU) that receives the acid gas stream and an air stream, the air stream being enriched with oxygen such that the air stream comprises between 22% and 100% oxygen, the SRU combusting the acid gas stream and the atmospheric air to thereby separate the acid gas stream into
a liquid stream of elemental sulfur, and
a tail gas stream comprising acid gas impurities; and

a tail gas treating unit including
a heat exchanger that receives the tail gas stream and an air flow, the tail gas stream and the air flow stream being heated through indirect heat exchange with a source of heat to produce a preheated tail gas stream;
a catalytic bed configured to receive and hydrogenate the preheated tail gas stream, thereby converting sulfur dioxide, carbonyl sulfide, mercaptans, and other sulfur species to H 2 S, thereby forming a gaseous catalytic output stream;
a dehydration unit that removes water from the gaseous catalytic output stream to produce a partially-dehydrated acid gas stream; and
a compressor station for receiving the partially-dehydrated acid gas stream from the dehydration unit, and providing pressure to the partially-dehydrated acid gas stream for injection into a subsurface reservoir.

10. The gas processing facility of claim 9 , further comprising:
a plurality of injection wells for transmitting the pressurized partially-dehydrated acid gas stream from the compressor station to the subsurface reservoir.

11. The gas processing facility of claim 9 , wherein the hydrocarbon gas stream comprises raw natural gas from a hydrocarbon production operation.

12. The gas processing facility of claim 9 , wherein the source of heat is steam.

13. A method for processing a hydrocarbon gas stream in a gas processing facility, the hydrocarbon gas stream comprising sulfurous components and carbon dioxide, the method comprising:
separating the hydrocarbon gas stream into (i) a sweetened gas stream, and (ii) an acid gas stream comprised primarily of hydrogen sulfide and carbon dioxide;
receiving the acid gas stream at a sulfur recovery unit (SRU);
receiving an air stream at the SRU, the air stream being enriched with oxygen such that the air stream comprises between 22% and 100% oxygen;
combusting the acid gas stream and the air stream in the SRU to thereby separate the acid gas stream into (i) a liquid stream of elemental sulfur, and (ii) a tail gas stream comprising acid gas impurities;
with an air flow, sub-stoichiometrically combusting the tail gas stream and fuel gas to produce an outlet stream comprising hydrogen sulfide and carbon monoxide;
hydrogenating the outlet stream in a catalytic bed, thereby converting SO 2 , COS, mercaptans, and other sulfur species to a gaseous catalytic output stream comprising H 2 S;
removing water from the gaseous catalytic output stream to produce a partially-dehydrated acid gas stream; and
pressurizing the partially-dehydrated acid gas stream to produce a compressed dehydrated acid gas stream; and
injecting the compressed, partially-dehydrated acid gas stream into a subsurface reservoir.

14. The method of claim 13 , wherein removing the acid gas from the gaseous catalytic output stream is accomplished using an absorber vessel and a regenerator vessel, the method further comprising:
in the

Assignees

• Exxonmobil Upstream Res Co

Inventors

• Northrop P Scott
• Aikins Tye R

Classifications

• C01B17/0447

  Separation of the obtained sulfur · CPC title

• Y02C20/40

  of CO2 · CPC title

• B01D53/1425

  Regeneration of liquid absorbents · CPC title

• B01D2252/20489

  with two or more hydroxyl groups · CPC title

• B01D53/1462 Primary

  Removing mixtures of hydrogen sulfide and carbon dioxide · CPC title