Hydrophobized nanoparticles as breaker for viscoelastic surfactant gelled fluids
A method of breaking the viscosity of a treatment fluid comprises: adding hydrophobic nanoparticles to a treatment fluid comprising a base fluid and a viscoelastic surfactant gelling agent, the hydrophobic nanoparticles comprising metallic nanoparticles that are surface modified with C 6-30 aliphatic groups, wherein the hydrophobic nanoparticles are added in an amount effective to decrease the viscosity of the treatment fluid as compared to a treatment fluid absent the hydrophobic nanoparticles.
1. A method of breaking a viscosity of a treatment fluid, the method comprising:
adding hydrophobic nanoparticles to a treatment fluid comprising a base fluid and a viscoelastic surfactant gelling agent, the hydrophobic nanoparticles comprising metallic nanoparticles that are surface modified with C 6-30 aliphatic groups,
wherein the hydrophobic nanoparticles are added in an amount effective to decrease the viscosity of the treatment fluid as compared to a treatment fluid absent the hydrophobic nanoparticles; and
the hydrophobic nanoparticles reduce the viscosity of the treatment fluid from greater than about 150 cP to less than about 30 cP, each measured at 300° F. and 100 s −1 .
2. The method of claim 1 , wherein the hydrophobic nanoparticles have one or more of the following characteristics: a static contact angle greater than about 120°; a contact angle hysteresis less than about 30°; or a roll-off angle less than about 20°.
3. The method of claim 1 , wherein the hydrophobic nanoparticles comprise metallic nanoparticles that are surface modified with C 8-26 alkyl groups.
4. The method of claim 1 , wherein the aliphatic groups are derived from a fatty acid.
5. The method of claim 4 , wherein the fatty acid comprises caprylic acid, capric acid, lauric acid, myristic acid, palmitic acid, stearic acid, behenic acid, lignoceric acid, cerotic acid, myristoleic acid, palmitoleic acid, sapienic acid, oleic acid, elaidic acid, vaccenic acid, linoleic acid, arachidonic acid, erucic acid, or a combination comprising at least one of the foregoing.
6. The method of claim 1 , wherein the metallic nanoparticles comprise one or more of the following: an alkaline earth metal; an alkaline earth metal oxide; an alkaline earth metal hydroxide; a transition metal; a transition metal oxide; a transition metal hydroxide; aluminum; aluminum oxide; aluminum hydroxide.
7. The method of claim 6 , wherein the metallic nanoparticles comprise zinc oxide, zinc hydroxide, or a combination thereof.
8. A method of treating a subterranean formation penetrated by a well, the method comprising:
combining a base fluid, a viscoelastic surfactant gelling agent, and hydrophobic nanoparticles to form a treatment fluid, the viscoelastic surfactant gelling agent forming micelles in the base fluid to gel the base fluid, the hydrophobic nanoparticles comprising metallic nanoparticles that are surface modified with C 8-30 aliphatic groups; and
pumping the treatment fluid into the well.
9. The method of claim 8 , wherein the hydrophobic nanoparticles have one or more of the following characteristics: a static contact angle greater than about 120°; a contact angle hysteresis less than about 30°; or a roll-off angle less than about 20°.
10. The method of claim 8 , wherein the aliphatic groups are derived from a fatty acid.
11. The method of claim 8 , wherein the metallic nanoparticles comprise one or more of the following: an alkaline earth metal; an alkaline earth metal oxide; an alkaline earth metal hydroxide; a transition metal; a transition metal oxide; a transition metal hydroxide; aluminum; aluminum oxide; or aluminum hydroxide.
12. The method of claim 11 , wherein the metallic nanoparticles comprise zinc oxide, zinc hydroxide, or a combination thereof.
13. The method of claim 8 , wherein the base fluid is a brine comprising about 2 wt. % to about 50 wt. % of a salt.
14. The method of claim 8 , wherein an amount of the hydrophobic nanoparticles is selected such that the treatment fluid has a viscosity variation of less than about 20% within about 2 hours after the treatment fluid is heated to a temperature of about 300° F.
15. The method of claim 8 , further comprising reducing a viscosity of the treatment fluid to less than about 30 cP in the well, the subterranean formation, or a combination thereof.
16. The method of claim 8 , wherein the hydrophobic nanoparticles are present in an amount of about 2 pptg to about 50 pptg.
17. The method of claim 8 , wherein treating the subterranean formation comprises a hydraulic fracturing operation, a frac packing operation, a gravel packing operation, an acidifying operation, a diversion operation, or a sand control operation.
18. The method of claim 8 , wherein the viscoelastic surfactant gelling agent comprises erucamidopropyl hydroxypropyl sulfobetaine, erucamidopropyl hydroxyethyl sulfobetaine, erucamidopropyl hydroxymethyl sulfobetaine, or a combination comprising at least one of the foregoing.
19. The method of claim 8 , wherein the viscoelastic surfactant gelling agent is present in an amount of about 1 wt. % to about 30 wt. % based on the total weight of the treatment fluid.
20. The method of claim 8 , wherein the viscoelastic surfactant gelling agent is present in an amount of about 2 wt. % to about 20 wt. % based on the total weight of the treatment fluid.
21. The method of claim 8 , wherein the treatment fluid is free of foams.
22. The method of claim 8 , wherein the base fluid comprises about 15 w % to about 40 wt. % of a calcium salt based on the total weight of the base fluid.
23. The method of claim 8 , wherein the metallic nanoparticles comprises zinc oxide, zinc hydroxide, or a combination thereof.