Method for syngas separation at hydrogen producing facilities for carbon capture and storage

Patent metadata

Field	Value
Publication number	US-11642620-B2
Application number	US-201916505379-A
Country	US
Kind code	B2
Filing date	Jul 8, 2019
Priority date	Apr 8, 2019
Publication date	May 9, 2023
Grant date	May 9, 2023

Abstract

Methods and systems for gas separation of syngas applying differences in water solubilities of syngas components, the method including producing a product gas comprising hydrogen and carbon dioxide from a hydrocarbon fuel source; separating hydrogen from the product gas to create a hydrogen product stream and a byproduct stream by solubilizing components in water that are more soluble in water than hydrogen; injecting the byproduct stream into a reservoir containing mafic rock; and allowing components of the byproduct stream to react in situ with components of the mafic rock to precipitate and store components of the byproduct stream in the reservoir.

First claim

What is claimed is:

1. A method for gas separation of syngas applying differences in water solubilities of syngas components, the method comprising the steps of:
producing a product gas comprising hydrogen and carbon dioxide from a hydrocarbon fuel source;
separating hydrogen from the product gas at the surface to create a hydrogen product stream and a byproduct stream by solubilizing components in water that are more soluble in water than hydrogen; wherein the byproduct stream comprises carbon dioxide solubilized in water;
injecting the byproduct stream into a reservoir containing mafic rock; and
allowing components of the byproduct stream to react in situ with components of the mafic rock to precipitate and store components of the byproduct stream in the reservoir.

2. The method according to claim 1 , where the step of separating includes the use of at least one vertical scrubbing tower with countercurrent flow of the product gas and water, the product gas flowing at about 20° C.

3. The method according to claim 2 , where at least about 50% of CO 2 and about 95% of H 2 S are removed from the product gas and separated from the hydrogen product stream by being solubilized in the countercurrent flow of water.

4. The method according to claim 1 , where the step of separating includes the use of at least two vertical scrubbing towers in series with countercurrent flow of the product gas and water.

5. The method according to claim 1 , where the mafic rock comprises basaltic rock.

6. The method according to claim 1 , where before the step of injecting the byproduct stream into the reservoir, the byproduct stream is further treated to separate and purify CO 2 from other components to increase CO 2 concentration of the byproduct stream for injection into the reservoir.

7. The method according to claim 6 , further comprising the step of liquefying CO 2 in the byproduct stream for injection into the reservoir.

8. The method according to claim 1 , further comprising the step of reacting the separated hydrogen with nitrogen to form compressed liquid ammonia.

9. The method according to claim 8 , further comprising the steps of transporting the compressed liquid ammonia and returning the compressed liquid ammonia to hydrogen and nitrogen via electrolysis for use of hydrogen as a hydrogen fuel source.

10. The method according to claim 1 , where the step of producing a product gas includes steam reforming or partial oxidation.

11. The method according to claim 1 , where the step of allowing components of the byproduct stream to react in situ with components of the mafic rock produces precipitates selected from the group consisting of: calcium carbonates, magnesium carbonates, iron carbonates, and combinations thereof.

12. The method according to claim 1 , where the reservoir is between about 250 m and about 2,200 m below the surface and is between about 30° C. and about 325° C.

13. The method according to claim 1 , where the reservoir is between about 350 m and about 1,500 m below the surface and is less than about 325° C.

Assignees

• Saudi Arabian Oil Co

Inventors

• Arkadakskiy Serguey Viktorov
• Kunnummal Noushad
• Ahmed Zeyad Tareq

Classifications

• B01D53/1475 Primary

  Removing carbon dioxide · CPC title

• B01D53/1493

  Selection of liquid materials for use as absorbents · CPC title

• C01B3/36

  using oxygen; using mixtures containing oxygen as gasifying agents · CPC title

• C25B1/02

  Hydrogen or oxygen · CPC title

• B01D53/1462 Primary

  Removing mixtures of hydrogen sulfide and carbon dioxide · CPC title