Method of scavenging hydrogen sulfide and mercaptans using well treatment composites

Patent metadata

Field	Value
Publication number	US-10434467-B2
Application number	US-201715490964-A
Country	US
Kind code	B2
Filing date	Apr 19, 2017
Priority date	Jul 31, 2014
Publication date	Oct 8, 2019
Grant date	Oct 8, 2019

Abstract

Hydrogen sulfide and mercaptans may be removed from a fluid or gaseous stream by introducing a composite to the fluid or gaseous stream containing a hydrogen sulfide scavenger adsorbed onto a water-insoluble adsorbent.

First claim

What is claimed is:

1. A method for reducing the amount of hydrogen sulfide or mercaptans or both hydrogen sulfide and mercaptans in a hydrocarbon producing reservoir which comprises transporting into the reservoir a composite of a hydrogen sulfide scavenger adsorbed onto a water-insoluble adsorbent and scavenging the hydrogen sulfide or mercaptans or both hydrogen sulfide and mercaptans in the hydrocarbon producing reservoir by continuously desorbing the hydrogen sulfide scavenger from the water-insoluble adsorbent and then releasing the hydrogen sulfide scavenger with the hydrogen sulfide or mercaptans or both hydrogen sulfide and mercaptans into the reservoir wherein the composite is transported into the reservoir in a carrier fluid, wherein:
(a) the carrier fluid is gelled or contains a gelling agent;
(b) the carrier fluid is a liquefied gas or a foamed gas;
(c) the carrier fluid is a fracturing fluid, acidizing fluid or completion fluid; or
(d) the pH of the carrier fluid is in excess of 11.0.

2. The method of claim 1 , wherein the weight ratio of the hydrogen sulfide scavenger to adsorbent in the composite is between from about 90:10 to about 10:90.

3. The method of claim 1 , wherein the hydrogen sulfide scavenger is continuously desorbed from the water-insoluble adsorbent and released into the reservoir over a minimum of three months.

4. The method of claim 1 , wherein the surface area of the adsorbent is between from about 1 m 2 /g to about 100 m 2 /g.

5. The method of claim 1 , wherein the carrier fluid is gelled or contains a gelling agent.

6. The method of claim 1 , wherein the carrier fluid is a liquefied gas or a foamed gas.

7. The method of claim 1 , wherein the carrier fluid is a fracturing fluid, acidizing fluid or completion fluid.

8. The method of claim 1 , wherein the pH of the carrier fluid is in excess of 11.0.

9. A method for reducing the amount of hydrogen sulfide or mercaptans or both hydrogen sulfide and mercaptans in a hydrocarbon producing reservoir which comprises:
(a) transporting a composite into the reservoir in a carrier fluid, wherein the composite is a hydrogen sulfide scavenger adsorbed onto a water-insoluble adsorbent wherein the composite is prepared by adsorbing the hydrogen sulfide scavenger onto the water-insoluble adsorbent and then drying the adsorbed hydrogen sulfide scavenger and water-insoluble adsorbent; and
(b) scavenging the hydrogen sulfide or mercaptans or both hydrogen sulfide and mercaptans in the hydrocarbon producing reservoir by continuously releasing the hydrogen sulfide scavenger from the water-insoluble adsorbent into the reservoir and further wherein the carrier fluid transporting the composite into the reservoir is:
(i) contains a component selected from the group consisting of gelling agents, cross-linking agents, gel breakers, surfactants, foaming agents, demulsifiers, clay stabilizer, acids or a combination thereof;
(ii) is a liquefied gas or a foamed gas;
(iii) is a fracturing fluid, acidizing fluid or completion fluid; or
(iv) has a pH in excess of 11.0.

10. The method of claim 9 , wherein the hydrogen sulfide scavenger is continuously released from the composite into the reservoir for a minimum of three months.

11. The method of claim 9 , wherein the surface area of the adsorbent is between from about 1 m 2 /g to about 100 m 2 /g.

12. The method of claim 9 , wherein the carrier fluid contains a component selected from the group consisting of gelling agents, cross-linking agents, gel breakers, surfactants, foaming agents, demulsifiers, clay stabilizer, acids or a combination thereof.

13. The method of claim 9 , wherein the carrier fluid is a liquefied gas or a foamed gas.

14. The method of claim 9 , wherein the carrier fluid is a fracturing fluid, acidizing fluid or completion fluid.

15. The method of claim 14 , wherein the carrier fluid is a fracturing fluid and further wherein the carrier fluid contains a proppant.

16. A method for reducing the amount of hydrogen sulfide or mercaptans or both hydrogen sulfide and mercaptans in a hydrocarbon producing reservoir which comprises (i) transporting into a targeted area of the reservoir a composite comprising particles of a hydrogen sulfide scavenger adsorbed onto a water-insoluble adsorbent wherein the composite is transported into the reservoir in a fracturing fluid and wherein the composite is neutrally buoyant in the fracturing fluid; and (ii) scavenging the hydrogen sulfide or mercaptans or both hydrogen sulfide and mercaptans in the hydrocarbon producing reservoir by continuously releasing the hydrogen sulfide scavenger from the water-insoluble adsorbent in the targeted area.

17. The method of claim 16 , wherein the surface area of the adsorbent is between from about 1 m 2 /g to about 100 m 2 /g.

18. The method of claim 16 , wherein the fracturing fluid contains proppant.

19. The method of claim 16 , wherein the hydrogen sulfide scavenger is continuously released from the composite over a minimum of three months.

20. The method of claim 16 , wherein the weight ratio of the hydrogen sulfide scavenger to adsorbent in the composite is between from about 90:10 to about 10:90.

Assignees

• Baker Hughes Inc
• Baker Hughes A Ge Co Llc

Inventors

• Shen Dong
• Steiner William H
• Szymczak Stephen J

Classifications

• C09K2208/20

  Hydrogen sulfide elimination · CPC title

• E21B43/25

  Methods for stimulating production {(by vibrating earth formations E21B43/003)} · CPC title

• C02F1/20

  by degassing, i.e. liberation of dissolved gases (degasification of liquids in general B01D19/00; arrangement of degassing apparatus in boiler feed supply F22D) · CPC title

• C02F1/283

  using coal, charred products, or inorganic mixtures containing them · CPC title

• B01D53/48

  Sulfur compounds · CPC title