Well treatment fluid having an acidic nanoparticle based dispersion, an epoxy resin, and a polyamine

Patent metadata

Field	Value
Publication number	US-11279865-B2
Application number	US-202016927477-A
Country	US
Kind code	B2
Filing date	Jul 13, 2020
Priority date	Sep 11, 2017
Publication date	Mar 22, 2022
Grant date	Mar 22, 2022

Abstract

A well treatment fluid having an acidic nanosilica dispersion, an epoxy resin, and a polyamine activator. The acidic nanosilica dispersion and the polyamine activator may form a gelled solid after interaction over a time period. Methods of reducing water production using the well treatment fluids are also provided.

First claim

What is claimed is:

1. A method to reduce water production in a treatment zone in a wellbore, comprising:
introducing a treatment fluid into the wellbore such that the treatment fluid contacts the treatment zone and reduces the water production in the treatment zone, wherein the treatment fluid comprises:
an acidic nanosilica dispersion;
an epoxy resin; and
a polyethylene polyamine.

2. The method of claim 1 , wherein the treatment fluid consists of the acidic nanosilica dispersion, the epoxy resin, and the polyethylene polyamine.

3. The method of claim 1 , wherein the polyethylene polyamine comprises at least one of diethylenetriamine, ethylenediamine, tetraethylenepetamine (TEPA), triethylentetramine, pentaethylenehexamine (PEHA), and hexaethyleneheptamine (HEHA).

4. The method of claim 1 , wherein the polyethylene polyamine is present in an amount in the range of 0.1 percent by volume of the total volume (v/v %) to 20 v/v %.

5. The method of claim 1 , wherein the epoxy resin is present in an amount in the range of 5 wt % to 95 wt %.

6. The method of claim 1 , wherein the epoxy resin comprises at least one of a bisphenol-A based epoxy resin, a bisphenol-F based epoxy resin, an aliphatic epoxy resin, an aromatic epoxy resin, and a Novalac resin.

7. The method of claim 1 , comprising maintaining the treatment fluid in contact with the treatment zone for a time period, such that the acidic nanosilica dispersion, epoxy resin, and the polyethylene polyamine form a gelled solid.

8. The method of claim 1 , wherein the time period comprises a range of 0.5 hours to 24 hours.

9. The method of claim 1 , comprising mixing the acidic nanosilica dispersion, the epoxy resin, and the polyethylene polyamine to form the treatment fluid at the surface before introducing the treatment fluid into the wellbore.

10. The method of claim 1 , wherein the treatment fluid comprises at least one of calcium carbonate particles, fibers, mica, and graphite.

11. The method of claim 10 , wherein the fibers comprise at least one of polyester fibers, polypropylene fibers, starch fibers, polyketone fibers, ceramic fibers, glass fibers or nylon fibers.

12. The method of claim 1 , wherein the acidic nanosilica dispersion is stabilized by a cationic polymer.

13. The method of claim 1 , wherein the acidic nanosilica dispersion is stabilized by a carboxylic acid.

14. The method of claim 1 , wherein the acidic nanosilica dispersion is stabilized by acetic acid.

15. A treatment fluid for reducing water production in a treatment zone in a wellbore, comprising:
an acidic nanosilica dispersion;
an epoxy resin; and
a polyethylene polyamine, the polyethylene polyamine selected to form a gelled solid after interaction with the acidic nanosilica dispersion for a time period.

16. The treatment fluid of claim 15 , wherein the time period comprises a range of 0.5 hours to 24 hours.

17. The treatment fluid of claim 15 , consisting of the acidic nanosilica dispersion, the epoxy resin, and the polyethylene polyamine.

18. The treatment fluid of claim 15 , wherein the polyethylene polyamine comprises at least one of diethylenetriamine, ethylenediamine, tetraethylenepetamine (TEPA), triethylentetramine, pentaethylenehexamine (PEHA), and hexaethyleneheptamine (HEHA).

19. The treatment fluid of claim 15 , wherein the polyethylene polyamine is present in an amount in the range of 0.1 percent by volume of the total volume (v/v %) to 20 v/v %.

20. The treatment fluid of claim 15 , wherein the epoxy resin is present in an amount in the range of 5 wt % to 95 wt %.

21. The treatment fluid of claim 15 , wherein the epoxy resin comprises a bisphenol-A based epoxy resin, a bisphenol-F based epoxy resin, an aliphatic epoxy resin, an aromatic epoxy resin, or a Novalac resin.

22. The treatment fluid of claim 15 , wherein the acidic nanosilica dispersion is stabilized by a cationic polymer.

23. The treatment fluid of claim 15 , wherein the acidic nanosilica dispersion is stabilized by a carboxylic acid.

24. The treatment fluid of claim 15 , wherein the acidic nanosilica dispersion is stabilized by acetic acid.

Assignees

• Saudi Arabian Oil Co

Inventors

• Wagle Vikrant
• Al-Yami Abdullah
• Alsaihati Zainab
• Alhelal Abdulaziz

Classifications

• C09K8/5083 Primary

  obtained by reactions only involving carbon-to-carbon unsaturated bonds · CPC title

• C09K8/516

  characterised by their form or by the form of their components, e.g. encapsulated material · CPC title

• E21B43/20

  Displacing by water · CPC title

• C09K8/508 Primary

  macromolecular compounds {(C09K8/512 takes precedence)} · CPC title

• C09K2208/10

  Nanoparticle-containing well treatment fluids · CPC title