Diversion pill and methods of using the same

Abstract

The invention provides a method made of steps of method injecting into a wellbore, a composition comprising an aqueous solution, a viscosifying agent, a degradable material, and sized salt particulates; and allowing viscosity of the composition to increase and form a plug at dynamic reservoir conditions.

1 . A method comprising:
 a. injecting into a wellbore, a composition comprising an aqueous solution, a viscosifying agent, a degradable material, and sized salt particulates; and   b. allowing viscosity of the composition to increase and form a plug at dynamic reservoir conditions.   
     
     
         2 . The method of  claim 1 , wherein the aqueous solution is brine. 
     
     
         3 . The method of  claim 1 , wherein the viscosifying agent is a viscoelastic surfactant. 
     
     
         4 . The method of  claim 3 , wherein the viscoelastic surfactant is a mixture of erucylamidopropyl betaine and copolymer of polyvinyl acetate/polyvinyl alcohol. 
     
     
         5 . The method of  claim 1 , wherein the degradable material is degradable fiber. 
     
     
         6 . The method of  claim 5 , wherein the degradable fiber is a PLA fiber. 
     
     
         7 . The method of  claim 1 , wherein the sized salt particulates are sized sodium chloride particulates. 
     
     
         8 . The method of  claim 1 , wherein the sized salt particulates are present in an amount of about 5% to about 30% by weight of the composition. 
     
     
         9 . The method of  claim 8 , wherein the sized salt particulates are present in an amount of about 10% to about 20% by weight of the composition. 
     
     
         10 . The method of  claim 1 , wherein the dynamic reservoir conditions include a shear rate above about 1 s −1 . 
     
     
         11 . The method of  claim 10 , wherein the dynamic reservoir conditions include a shear rate above about 10 s −1 . 
     
     
         12 . The method of  claim 1 , wherein the composition further comprises a breaker. 
     
     
         13 . A method of diverting a treatment fluid in a wellbore comprising:
 a. injecting into the wellbore the treatment fluid to treat a first zone;   b. injecting into the wellbore, a composition comprising an aqueous solution, a viscosifying agent, a degradable material, and sized salt particulates;   c. allowing viscosity of the composition to increase and form a plug at dynamic reservoir conditions; and   d. diverting the treatment fluid from first zone to a second zone with the plug.   
     
     
         14 . The method of  claim 13 , wherein formation of the plug is done during continuous injection of the treatment fluid. 
     
     
         15 . The method of  claim 13 , wherein the treatment fluid is a fracturing fluid. 
     
     
         16 . The method of  claim 13 , wherein the aqueous solution is brine. 
     
     
         17 . The method of  claim 16 , wherein the brine is near saturation. 
     
     
         18 . The method of  claim 16 , wherein the brine is saturated. 
     
     
         19 . The method of  claim 13 , wherein the viscosifying agent is a viscoelastic surfactant. 
     
     
         20 . The method of  claim 19 , wherein the viscoelastic surfactant is a mixture of erucylamidopropyl betaine and copolymer of polyvinyl acetate/polyvinyl alcohol. 
     
     
         21 . The method of  claim 13 , wherein the degradable material is degradable fiber. 
     
     
         22 . The method of  claim 21 , wherein the degradable fiber is a PLA fiber. 
     
     
         23 . The method of  claim 13 , wherein the sized salt particulates are sized sodium chloride particulates. 
     
     
         24 . The method of  claim 13 , wherein the sized salt particulates are present in an amount of about 5% to about 30% by weight of the composition. 
     
     
         25 . The method of  claim 24 , wherein the sized salt particulates are present in an amount of about 10% to about 20% by weight of the composition. 
     
     
         26 . The method of  claim 13 , wherein the dynamic reservoir conditions include a shear rate above about 1 s −1 . 
     
     
         27 . The method of  claim 26 , wherein the dynamic reservoir conditions include a shear rate above about 10 s −1 . 
     
     
         28 . A method of fracturing a subterranean formation in a wellbore comprising:
 a. injecting into the wellbore a fracturing fluid to create a fracture in the subterranean formation;   b. injecting into the wellbore, a composition comprising an aqueous solution, a viscosifying agent, a degradable material, and sized salt particulates;   c. allowing viscosity of the composition to increase and form a plug at dynamic reservoir conditions; and   d. diverting the fracturing fluid with the plug to create a second fracture in the subterranean formation.