Downhole resin coatings comprising a carbon nanomaterial and methods associated therewith

Patent metadata

Field	Value
Publication number	US-10344200-B2
Application number	US-201415516379-A
Country	US
Kind code	B2
Filing date	Nov 4, 2014
Priority date	Nov 4, 2014
Publication date	Jul 9, 2019
Grant date	Jul 9, 2019

Abstract

Resin coatings are frequently formed in conjunction with performing a subterranean treatment operation. However, poor thermal conductivity and mechanical strength of resin coatings can be problematic in a downhole environment and eventually lead to their breakdown. Methods for enhancing a resin coating in a downhole environment can comprise: introducing a treatment fluid comprising a curable resin and a carbon nanomaterial into a wellbore penetrating a subterranean formation; forming a coating of the curable resin on a surface in the wellbore, the carbon nanomaterial being dispersed throughout the coating; and curing the curable resin to form a cured resin coating.

First claim

The invention claimed is:

1. A method comprising:
introducing a treatment fluid comprising a curable resin and a carbon nanomaterial into a wellbore penetrating a subterranean formation, wherein the carbon nanomaterial has a size of about 100 nm or less and the carbon nanomaterial comprises a graphene selected from the group consisting of as-produced graphene, single-layer graphene, multi-layer graphene, graphene platelets, graphene sheets, graphene nanoribbons, graphene oxide, reduced graphene, functionalized graphene, any hybrid variant thereof, and any combination thereof;
forming a coating of the curable resin on a surface in the wellbore, the carbon nanomaterial being dispersed throughout the coating; and
curing the curable resin to form a cured resin coating comprising about 0.01 wt. % to about 5 wt. % of the carbon nanomaterial;
producing a fluid from the subterranean formation: and
fluorescence spectroscopically assaying the produced fluid for the carbon nanomaterial or any derivative thereof:
wherein the carbon nanomaterial having a size of about 100 nm or less enhances the mechanical strength and thermal conductivity of the resin coating thereby decreasing susceptibility of the resin coating to undergo crack formation and propagation.

2. The method of claim 1 , wherein the graphene material is covalently bonded to the cured resin coating.

3. The method of claim 1 , wherein the treatment fluid is introduced into the wellbore during a fracturing operation, a gravel packing operation, a frac-packing operation, a consolidation operation, or a sand control operation.

4. The method of claim 3 , wherein forming a coating of the curable resin takes place on-the-fly on proppant particulates or gravel particulates.

5. The method of claim 3 , wherein forming a coating of the curable resin takes place on unconsolidated sand within the subterranean formation.

6. The method of claim 3 , wherein forming a coating of the curable resin takes place on proppant particulates that are disposed in a propped fracture of the subterranean formation.

7. The method of claim 3 , wherein forming a coating of the curable resin takes place on a fracture face present in the subterranean formation.

8. The method of claim 1 , wherein forming a coating of the curable resin takes place on formation fines within the subterranean formation.

9. The method of claim 1 , further comprising:
correlating an amount of the carbon nanomaterial or any derivative thereof in the produced fluid to a breakdown of the cured resin coating.

10. A method comprising:
introducing a treatment fluid comprising a curable resin and a graphene material into a wellbore penetrating a subterranean formation,
wherein the graphene material has a size of about 100 nm or less and the graphene material comprises a material selected from the group consisting of as-produced graphene, single-layer graphene, multi-layer graphene, graphene platelets, graphene sheets, graphene nanoribbons, graphene oxide, reduced graphene, functionalized graphene, any hybrid variant thereof, and any combination thereof;
forming a coating of the curable resin on a surface of particulates in the wellbore, the coating being formed on-the-fly and the graphene material being dispersed throughout the coating; and
curing the curable resin to form a cured resin coating comprising about 0.01 wt. % to about 5 wt. % of the graphene material;
producing a fluid from the subterranean formation; and
fluorescence spectroscopically assaying the produced fluid for the carbon nanomaterial or any derivative thereof;
wherein the graphene material having a size of about 100 nm or less enhances the mechanical strength and thermal conductivity of the resin coating thereby decreasing susceptibility of the resin coating to undergo crack formation and propagation.

11. The method of claim 10 , wherein the graphene material is covalently bonded to the cured resin coating.

12. The method of claim 10 , wherein the treatment fluid is introduced into the wellbore during a fracturing operation, a gravel packing operation, a frac-packing operation, a consolidation operation, or a sand control operation.

13. The method of claim 12 , wherein forming a coating of the curable resin takes place on proppant particulates or gravel particulates.

14. The method of claim 12 , wherein forming a coating of the curable resin takes place on unconsolidated sand within the subterranean formation.

15. The method of claim 12 , wherein forming a coating of the curable resin takes place on proppant particulates that are disposed in a propped fracture of the subterranean formation.

16. The method of claim 10 , wherein forming a coating of the curable resin takes place on formation fines present in the subterranean formation.

17. The method of claim 10 , wherein a loading of the graphene material in the cured resin coating ranges between about 0.01 wt. % and about 5 wt. %.

18. The method of claim 10 , further comprising:
correlating an amount of the graphene material or any derivative thereof in the produced fluid to a breakdown of the cured resin coating.

Assignees

• Halliburton Energy Services Inc

Inventors

• Salla Rajender
• Raysoni Neelam Deepak
• Nguyen Philip D

Classifications

• C09K2208/10

  Nanoparticle-containing well treatment fluids · CPC title

• E21B43/025

  Consolidation of loose sand or the like round the wells without excessively decreasing the permeability thereof · CPC title

• C09K8/64

  Oil-based compositions · CPC title

• C09K8/565

  Oil-based compositions · CPC title

• C09K8/88

  macromolecular compounds · CPC title