Synergistic effects of nanoparticles and surfactants for gas lift flow improvement

Abstract

Compositions of nanoparticles and surfactants for enhanced gas lift through increased foaming heights and foam stability are disclosed. More specifically, synergistic combination of nanoparticles, including amine functionalized colloidal nanoparticles and surfactants, provides enhanced gas lift and increased oil production are disclosed. Methods of using are also disclosed.

1 . An injectate composition comprising:
 a water source and a gas lift flow improving composition comprising a functionalized nanoparticle, wherein the nanoparticle has an average particle size from about 1 nm to about 1000 nm; a foaming surfactant comprising an amphoteric, anionic and/or nonionic surfactant; and wherein the composition is dispersed in an aqueous medium.   
     
     
         2 . Use of the injectate composition of  claim 1  to increase the gas lift of hydrocarbon from a subterranean formation or well, rate of hydrocarbon recovery from a subterranean formation or well, total yield of hydrocarbon recovered from a subterranean formation or well, or combinations thereof. 
     
     
         3 . A method of improving gas lift flow in a subterranean formation or well comprising:
 introducing an injectate according to  claim 1  or a gas lift flow improving composition into a fluid comprising hydrocarbon or condensate in a subterranean formation or well, and   lowering the fluid density to improve gas lift flow or increase production in the subterranean formation or well,   wherein the gas lift flow improving composition comprises a functionalized nanoparticle, wherein the nanoparticle has an average particle size from about 1 nm to about 1000 nm;
 a foaming surfactant comprising an amphoteric, anionic and/or nonionic surfactant; and 
 wherein the composition is dispersed in an aqueous medium. 
   
     
     
         4 . The method of  claim 3 , wherein the introducing step is injecting the composition into the subterranean formation or well. 
     
     
         5 . The method of  claim 3 , wherein the injectate or the composition is introduced into the subterranean formation or well with a drilling fluid, a fracturing fluid, or an injectate. 
     
     
         6 . The method of  claim 3 , wherein the fluid has a water cut less than about 39% or greater than 76%, and wherein the fluid has a total dissolved solid of less than about 300,000 mg/L. 
     
     
         7 . The method of  claim 3 , wherein the subterranean formation or well comprises a low permeability formation of less than 0.1 mD. 
     
     
         8 . The method of  claim 3 , further comprises recovering hydrocarbon from the treated subterranean formation or well, wherein the recovered hydrocarbon comprises an oil or a condensate. 
     
     
         9 . The method of  claim 3 , wherein the method results in an increase in recovered hydrocarbon in comparison to a subterranean formation or well-treated with an injectate or gas lift flow improving composition that is free of the functionalized nanoparticle. 
     
     
         10 . The method of  claim 6 , wherein the method results in an increase in recovered hydrocarbon in comparison to a subterranean formation or well-treated with an injectate or gas lift flow improving composition that is free of the functionalized nanoparticle. 
     
     
         11 . The method of  claim 7 , wherein the subterranean formation or well comprises a low permeability formation of less than 0.01 mD. 
     
     
         12 . The method of  claim 3 , wherein the ratio of the functionalized nanoparticle to the surfactant is about 1:1 or greater on an actives (ppm) basis, or between about 1:1 to about 1:100 on an actives (ppm) basis. 
     
     
         13 . The method of  claim 3 , wherein the foaming surfactant comprises an amphoteric alkyl betaine. 
     
     
         14 . The method of  claim 3 , wherein the aqueous medium comprises a coupler and/or a solvent. 
     
     
         15 . The method of  claim 3 , wherein the nanoparticle has an average particle size from about 1 nm to about 500 nm, or from about 1 nm to about 200 nm. 
     
     
         16 . The method of  claim 3 , wherein the nanoparticles are selected from silica and metal-based nanoparticles. 
     
     
         17 . The method of  claim 16 , wherein the silica is selected from the group consisting of colloidal silica, nanosilica, silicate nanoparticle, polyhedral oligomeric silsesquioxane nanoparticle, and silicon dioxide nanoparticle dispersion. 
     
     
         18 . The method of  claim 3 , wherein the nanoparticle is surface modified with a silane compound, and wherein the silane compound comprises one or more of 3-glycidoxypropyltrimethoxysilane, 3-glycidoxypropylmethyldimethoxysilane, 3-glycidoxypropylmethyldiethoxysilane, 3-glycidoxypropyltriethoxysilane, 2-(3,4-epoxycyclohexyl)propyltrimethoxysilane, 2-(3,4 epoxycyclohexyl)propyltriethoxysilane, 2-(3,4-epoxycyclohexyl)ethyltrimethoxysilane, 2-(3,4-epoxycyclohexyl)ethyltriethoxysilane, 2-(3,4-epoxycyclohexyl)methyltrimethoxysilane, 2-(3,4 epoxycyclohexyl)methyltriethoxysilane, [(3-ethyl-3 oxethanyl)methoxy]propyltrimethoxysilane, or [(3-ethyl-3-oxethanyl) methoxy]propyltriethoxysilane. 
     
     
         19 . The method of  claim 3 , wherein the nanoparticle has 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. 
     
     
         20 . The method of  claim 19 , wherein the trialkoxyorganosilane is an epoxy functional silane, hydroxylic hydrophilic silane, hydroxyl functional silane, or thiol functional silane.