Hydrogen production from gasification of sour gas

Patent metadata

Field	Value
Publication number	US-12415723-B2
Application number	US-202318473613-A
Country	US
Kind code	B2
Filing date	Sep 25, 2023
Priority date	Sep 25, 2023
Publication date	Sep 16, 2025
Grant date	Sep 16, 2025

Abstract

A sour gas stream is sub-stoichiometrically combusted to produce soot and a sour syngas stream. At least 10% of the carbon in the sour gas stream is converted into the soot. At least a portion of the hydrogen sulfide of the sour syngas stream is reacted with sulfur dioxide to produce a syngas stream comprising the carbon dioxide, the carbon monoxide, the hydrogen, water, elemental sulfur vapor, a residual portion of the hydrogen sulfide, and a residual portion of the sulfur dioxide. The syngas stream is reacted with steam to produce a shifted sour gas stream including more carbon dioxide, more hydrogen, more hydrogen sulfide, and less carbon monoxide in comparison to the syngas stream. Water and hydrogen sulfide is separated from the shifted sour gas stream to produce a sweet gas stream. The sweet gas stream is separated into a hydrogen product stream and an exhaust stream.

First claim

What is claimed is:

1. A system comprising:
a sour gas stream comprising hydrogen sulfide and at least one hydrocarbon, the sour gas stream having a molar flow rate of carbon (C) and a molar flow rate of hydrogen (H);
an oxidizing stream comprising oxygen gas and having a molar flow rate of oxygen gas (O 2 ) in a range of from 10% to 70% of C+H/4;
a combustion reactor configured to receive the sour gas stream and the oxidizing stream, the combustion reactor configured to combust the sour gas stream to produce soot and sour syngas, wherein sub-stoichiometric combustion of the sour gas stream within the combustion reactor converts at least 10% of the carbon in the sour gas stream into soot;
a mechanical separator configured to separate the soot from the sour syngas to produce a sour syngas stream comprising carbon dioxide, carbon monoxide, hydrogen, and hydrogen sulfide;
a Claus unit configured to receive the sour syngas stream and a sulfur dioxide stream comprising sulfur dioxide, the Claus unit configured to react at least a portion of the hydrogen sulfide of the sour syngas stream with the sulfur dioxide of the sulfur dioxide stream to produce elemental sulfur and water, the Claus unit configured to discharge a sulfur stream comprising the elemental sulfur, the Claus unit configured to discharge a syngas stream comprising the carbon dioxide, the carbon monoxide, the hydrogen, the water, elemental sulfur vapor, a residual portion of the hydrogen sulfide, and a residual portion of the sulfur dioxide;
a sour shift/hydrogenation reactor configured to receive the syngas stream and stean, the sour shift/hydrogenation reactor comprising a water-gas shift hydrogenation catalyst, the water-gas shift hydrogenation catalyst configured to convert at least a portion of the carbon monoxide of the syngas stream and steam to carbon dioxide and hydrogen to produce a shifted sour gas stream, the water-gas shift hydrogenation catalyst configured to reduce the elemental sulfur vapor and the residual portion of the sulfur dioxide into hydrogen sulfide, the shifted sour gas stream substantially free of elemental sulfur and sulfur dioxide;
a quench tower configured to receive the shifted sour gas stream and separate water from the shifted sour gas stream to produce a dehydrated sour gas stream;
an amine unit configured to receive the dehydrated sour gas stream, the amine unit configured to contact the dehydrated sour gas stream with a lean amine solvent to extract the residual portion of the hydrogen sulfide from the dehydrated sour gas stream into the lean amine solvent to produce a sweet gas stream and a rich amine solvent, the sweet gas stream comprising the carbon dioxide and the hydrogen, the amine unit configured to boil off the residual portion of the hydrogen sulfide from the rich amine solvent to produce an acid gas stream and regenerate the lean amine solvent, the acid gas stream comprising the residual portion of the hydrogen sulfide; and
a purifier configured to receive the sweet gas stream and separate hydrogen from the sweet gas stream to produce a hydrogen product stream and an exhaust stream, the hydrogen product stream comprising a majority of the hydrogen from the sweet gas stream, the exhaust stream comprising a remainder of the sweet gas stream, wherein the combustion reactor is configured to receive at least a portion of the exhaust stream.

2. The system of claim 1 , comprising a boiler configured to use heat generated from combustion of the sour gas stream within the combustion reactor to generate steam and cool the soot and sour syngas to a temperature in a range of from about 250 degrees Celsius (° C.) to about 500° C.

3. The system of claim 2 , wherein the sour shift hydrogenation reactor is configured to receive at least a portion of the steam generated by the boiler.

4. The system of claim 2 , comprising a steam turbine configured to receive at least a portion of the steam generated by the boiler, the steam turbine configured to generate electrical power in response to the portion of the steam flowing through the steam turbine.

5. The system of claim 1 , wherein the combustion reactor is configured to receive at least a portion of the acid gas stream.

6. The system of claim 1 , wherein a second portion of the exhaust stream is sequestered within a subterranean formation to avoid releasing carbon dioxide to the atmosphere.

7. The system of claim 1 , comprising a feed pre-treatment unit upstream of the combustion reactor, wherein the feed pre-treatment unit is configured to process a high pressure raw sour gas stream to separate water and natural gas liquids from the high pressure raw sour gas stream to produce a reject water stream, a natural gas liquids (NGL) stream, and the sour gas stream.

8. The system of claim 7 , comprising a turboexpander downstream of the feed pre-treatment unit and upstream of the combustion reactor, wherein the turboexpander is configured to receive the sour gas stream and generate electrical power in response to flow of the sour gas stream through the turboexpander, wherein the turboexpander is configured to discharge the sour gas stream to the combustion reactor.

Assignees

• Saudi Arabian Oil Co

Inventors

• O'Connell John
• Rithauddeen Megat A
• Kotze Jacobus Scholtz

Classifications

• C01B2203/148

  involving a recycle stream to the feed of the process for making hydrogen or synthesis gas · CPC title

• C01B2203/1235

  Hydrocarbons · CPC title

• C01B2203/062

  Hydrocarbon production, e.g. Fischer-Tropsch process · CPC title

• C01B2203/0495

  the impurity being water · CPC title

• C01B2203/0485

  the impurity being a sulfur compound · CPC title