Additive of cellulose nanofibrils or nanocrystals and a second polymer

Patent metadata

Field	Value
Publication number	US-10781138-B2
Application number	US-201415529161-A
Country	US
Kind code	B2
Filing date	Dec 19, 2014
Priority date	Dec 19, 2014
Publication date	Sep 22, 2020
Grant date	Sep 22, 2020

Abstract

A wellbore treatment fluid comprising: a base fluid; and an additive comprising: a first polymer bundle selected from the group consisting of cellulose nanofibrils, cellulose nanocrystals, and combinations thereof; and a second polymer, wherein the second polymer attaches to the first polymer bundle by a non-covalent mechanism. A method of treating a portion of a wellbore comprising: introducing the treatment fluid into the wellbore.

First claim

What is claimed is:

1. A method of treating a portion of a wellbore comprising: introducing a treatment fluid into the wellbore, the treatment fluid comprising:
(A) a base fluid; and
(B) an additive consisting of:
(i) a first polymer bundle selected from the group consisting of cellulose nanofibrils, cellulose nanocrystals, and combinations thereof; and
(ii) a second polymer, wherein the second polymer attaches to the first polymer bundle by a non-covalent mechanism, wherein the second polymer comprises a cationic polyelectrolytes containing primary, secondary, tertiary or quaternary amino groups, selected from the group consisting of cationic polyacrylamides (CPAMs), cationic starch, poly(diallyldimethyl ammonium chloride), and epichlorohydrin/dimethylamine polymers;
wherein a ratio of the second polymer to the first polymer bundle is about 0.5:1 to about 4:1,

wherein the treatment fluid has a fluid loss of less than 5 grams in 30 minutes at a differential pressure of 100 psi.

2. The method according to claim 1 , wherein the base fluid comprises water.

3. The method according to claim 2 , wherein the water is selected from the group consisting of freshwater, saltwater, sea water, brackish water, and combinations thereof.

4. The method according to claim 1 , wherein the base fluid further comprises a water-soluble salt.

5. The method according to claim 1 , wherein the first polymer bundle and second polymer form a polymer network.

6. The method according to claim 5 , wherein the first polymer bundle forms the backbone of the polymer network.

7. The method according to claim 1 , wherein the second polymer attaches to the first polymer bundle via hydrogen bonding through hydroxyl groups on the first polymer, dispersion, van der Waals forces, dipole forces, and other forces, or mechanical entanglement.

8. The method according to claim 1 , wherein the second polymer has an affinity to the first polymer.

9. The method according to claim 8 , wherein the affinity occurs due to opposite charges wherein the second polymer has cationic functional groups and the first polymer bundle has anionic functional groups.

10. The method according to claim 8 , wherein the affinity occurs due to an attraction of one or more functional groups of the first polymer bundle and the second polymer.

11. The method according to claim 1 , wherein the second polymer is in a concentration in the range of about 0.1% to about 2% by weight of the first polymer.

12. The method according to claim 1 , wherein the additive is in a concentration in the range of about 0.1% to about 5% by weight of the base fluid.

13. The method according to claim 1 , wherein the additive is a viscosifier, a gelling agent, a rheology modifier, or a fluid loss control additive.

14. The method according to claim 1 , wherein the treatment fluid is a drilling fluid, a drill-in fluid, a packer fluid, a completion fluid, a spacer fluid, a work-over fluid, an insulating fluid, a cement composition, or a stimulation fluid.

15. The method according to claim 1 , wherein the drilling fluid is mixed with mixing equipment.

16. The method according to claim 1 , wherein the step of introducing comprises pumping the treatment fluid into the wellbore using pumping equipment.

Assignees

• Halliburton Energy Services Inc

Inventors

• Hall Lee J
• Deville Jay P
• Rojas Orlando J
• Carrillo Carlos A
• Salas Carlos L

Classifications

• C09K8/88

  macromolecular compounds · CPC title

• C09K8/68

  containing organic compounds · CPC title

• C09K8/42

  Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells (compositions for plastering C09K8/50) · CPC title

• C09K8/508

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

• C09K8/90

  of natural origin, e.g. polysaccharides, cellulose · CPC title