Enhancing foam rheological properties using water-soluble thickener

Abstract

An aqueous wellbore fluid may include a surface active agent package in an amount ranging from 1 to 20 gpt, a thickener in an amount ranging from 0.01 to 0.3 wt. %, and an aqueous base fluid. The surface active agent package may include an α-olefin sulfonate, a terpenoid, and isopropyl alcohol. The thickener may include a biopolymer.

1 . A generated foam, comprising:
 An aqueous wellbore fluid, comprising:
 a surface active agent package that comprises an α-olefin sulfonate, a terpenoid, and isopropyl alcohol, wherein the surface active agent package is present in an amount ranging from 1 to 20 gpt (gallons per thousand gallons) of the aqueous wellbore fluid; 
 a thickener that comprises a biopolymer, wherein the thickener is present in an amount ranging from 0.01 to 0.3 wt. % (weight percent) of the aqueous wellbore fluid; and 
 an aqueous base fluid; and 
   a gas selected from the group consisting of carbon dioxide, methane, nitrogen, and combinations thereof, where the gas is present in an amount such that the generated foam has a quality in a range of from about 50 to about 99%.   
     
     
         2 . The generated foam of  claim 1 , wherein the surface active agent package comprises the α-olefin sulfonate in an amount in the range of 20 to 30 wt. %. 
     
     
         3 . The generated foam of  claim 1 , wherein the surface active agent package comprises the isopropyl alcohol in an amount in the range of 20 to 30 wt. %. 
     
     
         4 . The generated foam of  claim 1 , wherein the surface active agent package comprises the terpenoid in an amount in the range of 10 to 20 wt. %. 
     
     
         5 . The generated foam of  claim 1 , wherein the thickener is hydroxyethylcellulose. 
     
     
         6 . The generated foam of  claim 1 , wherein the terpenoid is citrus terpenes. 
     
     
         7 . The generated foam of  claim 1 , wherein the wellbore fluid has a viscosity at 25° C. of 30 cP (centipoise) or less. 
     
     
         8 . The generated foam of  claim 1 , wherein the wellbore fluid has a viscosity at 50° C. of 20 cP or less. 
     
     
         9 . A method for recovering hydrocarbons from a hydrocarbon-containing formation, the method comprising:
 injecting into the hydrocarbon-containing formation a wellbore fluid that comprises a surface active agent package, a thickener, and an aqueous base fluid, wherein the surface active agent package comprises an α-olefin sulfonate, a terpenoid, and isopropyl alcohol, and wherein the wellbore fluid comprises the surface active agent package in an amount in the range of 1 to 20 gpt and the thickener in an amount in the range of 0.01 to 0.3 wt. %;   injecting into the hydrocarbon-containing formation a gas that mixes with the wellbore fluid, generating a foam in the formation;   introducing a fluid into the hydrocarbon-containing formation, thereby displacing hydrocarbons from the hydrocarbon-containing formation; and   recovering the hydrocarbons.   
     
     
         10 . The method of  claim 9 , wherein the wellbore fluid and the gas are co-injected. 
     
     
         11 . The method of  claim 9 , wherein the gas is injected after the wellbore fluid. 
     
     
         12 . The method of  claim 9 , wherein the hydrocarbon-containing formation comprises a zone of high permeability and a zone of low permeability. 
     
     
         13 . The method of  claim 9 , wherein the generated foam may have a viscosity that is 1.1 to 10 times that of the wellbore fluid before foaming. 
     
     
         14 . The method of  claim 9 , wherein the surface active agent package comprises the α-olefin sulfonate in an amount in the range of 20 to 30 wt. %. 
     
     
         15 . The method of  claim 9 , wherein the surface active agent package comprises the isopropyl alcohol in an amount in the range of 20 to 30 wt. %. 
     
     
         16 . The method of  claim 9 , wherein the surface active agent package comprises the terpenoid in an amount in the range of 10 to 20 wt. %. 
     
     
         17 . The method of  claim 9 , wherein the thickener is hydroxyethylcellulose. 
     
     
         18 . The method of  claim 9 , wherein the terpenoid is citrus terpenes. 
     
     
         19 . The method of  claim 9 , wherein the generated foam has a viscosity at 50° C. of 15 to 200 cP. 
     
     
         20 . The method of  claim 9 , wherein the generated foam has a viscosity at 100° C. of 10 to 140 cP. 
     
     
         21 . A method of preparing an aqueous wellbore fluid, comprising:
 mixing a surface active agent package, a thickener, and an aqueous base fluid,   wherein the surface active package comprises an α-olefin sulfonate, a terpenoid, and isopropyl alcohol and the thickener comprises a biopolymer,   wherein the wellbore fluid contains the surface active agent package in an amount ranging from 1 to 20 gpt, and   wherein the wellbore fluid contains the thickener in an amount ranging from 0.01 to 0.3 wt. %.   
     
     
         22 . The method of  claim 21 , wherein the surface active agent package comprises the α-olefin sulfonate in an amount in the range of 20 to 30 wt. %. 
     
     
         23 . The method of  claim 21 , wherein the surface active agent package comprises the isopropyl alcohol in an amount in the range of 20 to 30 wt. %. 
     
     
         24 . The method of  claim 21 , wherein the surface active agent package comprises the terpenoid in an amount in the range of 10 to 20 wt. %. 
     
     
         25 . The method of  claim 21 , wherein the thickener is hydroxyethylcellulose. 
     
     
         26 . The method of  claim 21 , wherein the terpenoid is citrus terpenes. 
     
     
         27 . The method of  claim 21 , wherein the wellbore fluid has a viscosity at 25° C. of 30 cP or less. 
     
     
         28 . The method of  claim 21 , wherein the wellbore fluid has a viscosity at 50° C. of 20 cP or less. 
     
     
         29 . A method for enhancing the recovery of hydrocarbons from a hydrocarbon-containing formation, the method comprising:
 injecting into the hydrocarbon-containing formation a wellbore fluid that comprises a surface active agent package, a thickener, and an aqueous base fluid, wherein the surface active agent package comprises an α-olefin sulfonate, a terpenoid, and isopropyl alcohol, and wherein the wellbore fluid comprises the surface active agent package in an amount in the range of 1 to 20 gpt and the thickener in an amount in the range of 0.01 to 0.3 wt. %; and   injecting into the hydrocarbon-containing formation a gas that mixes with the wellbore fluid, generating a foam in the formation.   
     
     
         30 . The method of  claim 29 , wherein the wellbore fluid and the gas are co-injected. 
     
     
         31 . The method of  claim 29 , wherein the gas is injected after the wellbore fluid. 
     
     
         32 . The method of  claim 29 , wherein the hydrocarbon-containing formation comprises a zone of high permeability and a zone of low permeability. 
     
     
         33 . The method of  claim 29 , wherein the generated foam may have a viscosity that is 1.1 to 10 times that of the wellbore fluid before foaming. 
     
     
         34 . The method of  claim 29 , wherein the surface active agent package comprises the α-olefin sulfonate in an amount in the range of 20 to 30 wt. %. 
     
     
         35 . The method of  claim 29 , wherein the surface active agent package comprises the isopropyl alcohol in an amount in the range of 20 to 30 wt. %. 
     
     
         36 . The method of  claim 29 , wherein the surface active agent package comprises the terpenoid in an amount in the range of 10 to 20 wt. %. 
     
     
         37 . The method of  claim 29 , wherein the thickener is hydroxyethylcellulose. 
     
     
         38 . The method of  claim 29 , wherein the terpenoid is citrus terpenes. 
     
     
         39 . The method of  claim 29 , wherein the generated foam has a viscosity at 50° C. of 15 to 200 cP. 
     
     
         40 . The method of  claim 29 , wherein the generated foam has a viscosity at 100° C. of 10 to 140 cP.