Compositions for enhanced oil recovery

Abstract

Disclosed herein are compositions and methods for increasing recovery of hydrocarbon compounds from hydrocarbon-containing subterranean fractured rock formations. Novel emulsions and fracturing fluids are provided. The fracturing fluids convert oil-wet rocks to water-wet, yet exhibit a low tendency of composition components to sorb to the rock. The fracturing fluids do not cause formation of emulsions with hydrocarbon compounds within the subterranean fractured rock formations.

What is claimed is: 
     
         1 . A composition comprising
 about 98 wt % to 99.999 wt % of a water source comprising high total dissolved solids;
 one or more oil phase surfactants, the oil phase surfactants characterized as nonionic and having a combined HLB of less than about 9; 
   one or more coupling agents;   one or more water phase surfactants, wherein the water phase surfactants are nonionic, soluble or dispersible in water, and chemically different from the one or more oil phase surfactants;   one or more ionic surfactants; and   one or more clay stabilizers.   
     
     
         2 . The composition of  claim 1  wherein the water source comprises about 10 wt % to 35 wt % non-polymeric solids. 
     
     
         3 . The composition of  claim 1  wherein the water source is a high temperature water source. 
     
     
         4 . The composition of  claim 1  further comprising one or more additives, the additives comprising one or more viscosifying agents, solvents, alkali, flow back aids, non-emulsifiers, friction reducers, breakers, crosslinking agents, biocides, proppants, or mixtures thereof. 
     
     
         5 . The composition of  claim 1  wherein the oil phase surfactant comprises one or more alkoxylated alcohols, alkoxylated alkylphenols, glycerol esters, glycol esters, polyethylene glycol esters, polyglycerol esters, sorbitol esters, and mixtures thereof. 
     
     
         6 . The composition of  claim 1  wherein the coupling agent comprises one or more linear, branched, or cyclic aliphatic alcohols having 1 to 6 carbon atoms, diols having 1 to 6 carbon atoms, alkyl ethers of alkylene glycols wherein the alkyl moiety has 1 to 6 carbon atoms, polyalkylene glycols, and mixtures thereof. 
     
     
         7 . The composition of  claim 1  wherein the water phase surfactant comprises one or more alkoxylated alcohols or alkoxylated alkyl phenols having an HLB greater than about 10, and mixtures thereof. 
     
     
         8 . The composition of  claim 1  wherein the ionic surfactant comprises one or more alkylbenzene sulfonic acids, alkyl benzene sulfonates, alkyl sulfonates, alkyl sulfates, alkyl ether sulfates, alkyl ammonium halides, alkyl aryl ammonium halides, imidazolium, cocoamidopropyl betaine, cocodimethyl betaine, alkyl amine oxides, and mixtures thereof. 
     
     
         9 . A composition comprising about 98 wt % to 99.999 wt % of a water source comprising high total dissolved solids;
 one or more coupling agents,   one or more water soluble or dispersible nonionic surfactants,   one or more zwitterionic surfactants,   one or more anionic surfactants, and   optionally one or more additional ionic surfactants.   
     
     
         10 . The composition of  claim 9  wherein the water source comprises about 10 wt % to 35 wt % non-polymeric solids. 
     
     
         11 . The composition of  claim 9  wherein the water source is a high temperature water source. 
     
     
         12 . The composition of  claim 9  further comprising one or more additives, the additives comprising one or more viscosifying agents, solvents, alkali, flow back aids, non-emulsifiers, friction reducers, breakers, crosslinking agents, biocides, proppants, or mixtures thereof. 
     
     
         13 . A method of increasing recovery of crude oil from a subterranean hydrocarbon-containing formation, the method comprising:
 forming an emulsion, the emulsion comprising
 a. one or more oil phase surfactants, the oil phase surfactants characterized as nonionic and having a combined HLB of less than about 9, 
 b. a coupling agent, 
 c. one or more water phase surfactants, wherein the water phase surfactants are nonionic, soluble or dispersible in water, and chemically different from the one or more oil phase surfactants, 
 d. one or more ionic surfactants, 
 e. one or more clay stabilizers, and 
 f. about 40 wt % to 80 wt % water; 
   contacting the emulsion with a high total dissolved solids water source to form a fracturing fluid;   injecting the fracturing fluid into a subterranean hydrocarbon-containing formation; and   collecting a hydrocarbon from the subterranean hydrocarbon-containing formation.   
     
     
         14 . The method of  claim 13  wherein a portion of the subterranean hydrocarbon containing formation at a temperature of about 60° C. to 120° C. 
     
     
         15 . The method of  claim 13  wherein the water source comprises about 5 wt % to 30 wt % total dissolved solids. 
     
     
         16 . The method of  claim 13  wherein the contacting is carried out contemporaneously with the injecting. 
     
     
         17 . The method of  claim 13  wherein the contacting is carried out prior to the injecting. 
     
     
         18 . The method of  claim 13  wherein the injecting is into a first wellbore connected to the subterranean hydrocarbon-containing formation, and the collecting is from a second wellbore that is connected to the subterranean hydrocarbon-containing formation. 
     
     
         19 . The method of  claim 13  wherein the injecting is into a wellbore connected to the subterranean hydrocarbon-containing formation, and the collecting is from the same wellbore. 
     
     
         20 . A method of increasing recovery of crude oil from a subterranean hydrocarbon-containing formation, the method comprising:
 forming an emulsion, the emulsion comprising one or more coupling agents, one or more water soluble or dispersible nonionic surfactants, one or more zwitterionic surfactants, one or more anionic surfactants, and optionally one or more additional ionic surfactants;   contacting the emulsion with a high total dissolved solids water source to form a fracturing fluid, the fracturing fluid comprising about 98 wt % to 99.99 wt % of the high total dissolved solids water source;   injecting the fracturing fluid into a subterranean hydrocarbon-containing formation; and   collecting a hydrocarbon from the subterranean hydrocarbon-containing formation.   
     
     
         21 . The method of  claim 20  wherein at least a portion of the subterranean hydrocarbon containing formation at a temperature of about 60° C. to 120° C. 
     
     
         22 . The method of  claim 20  wherein the water source comprises about 5 wt % to 30 wt % total dissolved solids. 
     
     
         23 . The method of  claim 20  wherein the contacting is carried out contemporaneously with the injecting. 
     
     
         24 . The method of  claim 20  wherein the contacting is carried out prior to the injecting. 
     
     
         25 . The method of  claim 20  wherein the injecting is into a first wellbore connected to the subterranean hydrocarbon-containing formation, and the collecting is from a second wellbore that is connected to the subterranean hydrocarbon-containing formation. 
     
     
         26 . The method of  claim 20  wherein the injecting is into a wellbore connected to the subterranean hydrocarbon-containing formation, and the collecting is from the same wellbore.