Compositions and methods for improving thermal and brine stability of nanoparticles
Amine functionalized nanoparticles having improved thermal and brine stability comprising a core-shell nanoparticle morphology comprising a trialkoxyorganosilane coated nanoparticle core and an amine functionalized group on the surface of the nanoparticle as a shell are disclosed. Methods and applications of use of the amine functionalized nanoparticles and compositions comprising the amine functionalized nanoparticles dispersed in an aqueous medium are also disclosed.
1. A treatment fluid composition comprising:
an amine functionalized nanoparticle, a surfactant composition, and a solvent comprising a water source, mutual solvent, or mixture thereof, wherein the amine functionalized nanoparticle comprises a core-shell nanoparticle morphology comprising a trialkoxyorganosilane coated nanoparticle core and an amine functionalized group on the surface of the trialkoxyorganosilane coated nanoparticle core as a shell, wherein the amine functionalized nanoparticle has an average particle size from about 1 nm to about 1000 nm, wherein a molar ratio of the trialkoxyorganosilane coated nanoparticle core to the amine-functionalized silane on the coated nanoparticle is about 1:1 to about 20:1, and wherein the treatment fluid composition is introduced into a subterranean formation or well.
2. The composition of claim 1 , wherein the nanoparticle is selected from silica and metal-based nanoparticles, and wherein the silica is selected from the group consisting of colloidal silica, nanosilica, silicate nanoparticle, polyhedral oligomeric silsesquioxane nanoparticle, and silicon dioxide nanoparticle dispersion.
3. The composition of claim 1 , wherein the nanoparticle is free of ceramics and carbon or carbon-based materials.
4. The composition of claim 1 , wherein the trialkoxyorganosilane is an epoxy functional silane, hydroxylic hydrophilic silane, or hydroxyl functional silane.
5. The composition of claim 1 , wherein the amine functionalized group is provided by an amine-functionalized silane according to formula I or II,
wherein:
R 1 , R 2 , and R 3 are independently —OMCH 3 , —OH, —CH 3 , or —Cl and wherein M is absent, —(CH 2 ) m —, or —(CH 2 Y) n —, wherein m is an integer from 1 to 5, n is an integer from 1 to 5, wherein Y is O, N, or S; and
R 4 is —CH 2 , or a substituted or an unsubstituted, linear or branched C2-C20 alkyl group, or —(Ar)—;
R 5 is absent or H; and
R 6 is —CH 3 , a substituted or an unsubstituted, linear or branched C2-C20 alkyl group or a primary, secondary, tertiary or quaternary alkyl amine, —(Ar)—, ═(CNH 2 NH 2 ), —((CH 2 ) o NH 2 ), —((CH 2 ) o NHCH 3 ), —((CH 2 ) o NH(CH 2 ) p NH 2 ), —((CH 2 ) o NH(CH 2 ) p Ar), wherein o and p are independently integers from 1 to 15.
6. The composition of claim 1 , wherein the amine functionalized group is covalently bonded to the trialkoxyorganosilane coated nanoparticle.
7. The composition of claim 1 , wherein a mass ratio of the trialkoxyorganosilane coated nanoparticle core to the amine-functionalized silane on the coated nanoparticle is about 1:1 to about 100:1.
8. The composition of claim 1 , wherein the nanoparticle is stable at a total dissolved solids of about 100,000 mg/L to about 350,000 mg/L for at least about 7 days, and is stable at a temperature from about 60° C. to about 250° C.
9. The composition of claim 1 , wherein the amine functionalized nanoparticle is a reaction product obtained by a first step of coating a nanoparticle core with a trialkoxyorganosilane coating to create the trialkoxyorganosilane coated nanoparticle core and thereafter covalently bonding the amine-functionalized silane group to the surface of the trialkoxyorganosilane coated nanoparticle core.
10. A method of treating a subterranean formation comprising:
introducing a treatment fluid composition according to claim 1 into a subterranean formation or well, wherein the surfactant composition comprising amphoteric surfactants, nonionic surfactants, anionic surfactants, or combinations thereof.
11. The method of claim 10 , wherein the introducing is injecting the treatment fluid composition into the subterranean formation or well.
12. The method of claim 10 , wherein the treatment fluid composition is a drilling fluid, a fracturing fluid, or an injectate, wherein the injectate comprises a water source.
13. The method of claim 12 , wherein the water source of the injectate comprises a produced water or high total dissolved solids, a high temperature water source or a combination of high total dissolved solids and a high temperature water source.
14. The method of claim 10 , wherein the subterranean formation or well comprises a low permeability formation of less than 0.1 mD, a secondary well, a tertiary well, or a shale formation.
15. The method of claim 10 , further comprising the step of recovering hydrocarbon from the treated subterranean formation, wherein the recovered hydrocarbon comprises an oil or a condensate.
16. The method of claim 10 , wherein the surfactant is a nonionic surfactant comprising alkoxylated alcohol, alkoxylated alkyl phenol, or ethylene oxide/propylene oxide copolymers having an HLB of at least about 10.
17. The method of claim 10 , wherein the surfactant is an anionic surfactant comprising salts of sulfate, sulfonate, and/or carboxylate.
18. The method of claim 10 , wherein the treatment fluid composition further comprises a stability component comprising a sulfate, chloride, carbonate or oxide salt of aluminum, titanium or zirconium.
19. The method of claim 10 , wherein the treatment fluid composition on contact with the subterranean formation changes the formation from an oil wettable to water wettable, and/or changes a contact angle of oil from about 60 degrees to about 100 degrees, and/or changes a contact angle of water from about 50 degrees to about 10 degrees.