Method for diversion of hydraulic fracture treatments

Abstract

Disclosed herein are methods that include a method for treating a well bore including treating a subterranean formation with a first treatment fluid, wherein the first treatment fluid treats a first treated zone. A degradable diverting material may then be introduced into the subterranean formation. The subterranean formation may be treated with a second treatment fluid where the degradable diverting material diverts at least a portion of the second treatment fluid away from the first treated zone.

1 . A method for treating a well bore comprising:
 introducing a degradable diverting material into a subterranean formation; and   introducing a treatment fluid into the subterranean formation, wherein the degradable diverting material diverts at least a portion of the treatment fluid.   
   
   
       2 . The method of  claim 1  wherein the degradable diverting material comprises at least one substance selected from the group consisting of: a, a chitin, a chitosan; a protein, an aliphatic polyester a poly(lactide), a poly(lactic acid); a poly(glycolide), a poly(ε-caprolactones), a poly(hydroxybutyrate), a poly(anhydride), an aliphatic polycarbonate; a poly(orthoester), a poly(amino acid), a poly(ethylene oxide), a polyphosphazene, and a derivative thereof. 
   
   
       3 . The method of  claim 1  wherein the degradable diverting material comprises a particulate, wherein the particulate has a diameter of about 100 mesh to about one-quarter of one inch. 
   
   
       4 . The method of  claim 1  wherein the first treatment fluid comprises at least one fluid selected from the group consisting of: an acid solutions, a scale inhibitor material solutions, a water blocking material solutions, a clay stabilizer solutions, a chelating agent solutions, a surfactant solutions, a fracturing fluid, a paraffin removal solution, an oil based foam, a drilling fluid, and a derivative thereof. 
   
   
       5 . The method of  claim 1  further comprising:
 introducing a first treatment fluid to the subterranean formation prior to introducing the degradable diverting material into the subterranean formation.   
   
   
       6 . The method of  claim 1  further comprising:
 reintroducing the degradable diverting material into the subterranean formation after the second treatment fluid; and   treating the subterranean formation with a third treatment fluid, wherein the degradable diverting material diverts at least a portion of the third treatment fluid.   
   
   
       7 . The method of  claim 1  further comprising:
 degrading at least a portion of the degradable diverting material to allow it to be removed from the well bore.   
   
   
       8 . A method for fracturing a subterranean formation comprising:
 fracturing a portion of a subterranean formation with a fracturing fluid through a first perforation tunnel to create a first fracture;   introducing a degradable diverting material into the first perforation tunnel; and   fracturing the subterranean formation with the fracturing fluid through a second perforation tunnel to create a second fracture, wherein the degradable diverting material diverts at least a portion of the fracturing fluid away from the first perforation tunnel.   
   
   
       9 . The method of  claim 8  wherein the degradable diverting material comprises at least one substance selected from the group consisting of: a, a chitin, a chitosan; a protein, an aliphatic polyester a poly(lactide), a poly(lactic acid); a poly(glycolide), a poly(ε-caprolactones), a poly(hydroxybutyrate), a poly(anhydride), an aliphatic polycarbonate; a poly(orthoester), a poly(amino acid), a poly(ethylene oxide), a polyphosphazene, and a derivative thereof. 
   
   
       10 . The method of  claim 8  wherein the introducing a degradable diverting material into the first perforation tunnel occurs at a matrix flow rate. 
   
   
       11 . The method of  claim 8  further comprising:
 introducing the degradable diverting material into the subterranean formation after the second treatment fluid; and   treating the subterranean formation with a third treatment fluid, wherein the degradable diverting material diverts at least a portion of the third treatment fluid away from the first treated zone and the second treated zone.   
   
   
       12 . The method of  claim 8  further comprising:
 degrading at least a portion of the degradable diverting material to allow it to be removed from the well bore.   
   
   
       13 . The method of  claim 8  wherein the fracturing the subterranean formation comprises using a jetting tool to create or enhance the first fracture. 
   
   
       14 . The method of  claim 10  wherein the proppant particulate is substantially coated with a resin or tackifying agent. 
   
   
       15 . A method for fracturing a well bore comprising:
 fracturing a well bore with a fracturing fluid containing a plurality of proppant particulates through a first perforation tunnel to create a first fracture;   forming a proppant particulate plug in the well bore, wherein the plug covers the first perforation tunnel;   introducing a degradable diverting material into the proppant particulate plug at a sub-fracture pressure;   fracturing the subterranean formation with the fracturing fluid through a second perforation tunnel to create a second fracture, wherein the degradable diverting material diverts at least a portion of the fracturing fluid away from the first perforation tunnel covered by the proppant plug.   
   
   
       16 . The method of  claim 15  wherein the degradable diverting material comprises at least one substance selected from the group consisting of: a, a chitin, a chitosan; a protein, an aliphatic polyester a poly(lactide), a poly(lactic acid); a poly(glycolide), a poly(ε-caprolactones), a poly(hydroxybutyrate), a poly(anhydride), an aliphatic polycarbonate; a poly(orthoester), a poly(amino acid), a poly(ethylene oxide), a polyphosphazene, and a derivative thereof. 
   
   
       17 . The method of  claim 16  wherein the degradable diverting material comprises a plasticizer selected from the group defined by the formula: 
     
       
         
         
             
             
         
       
     
     wherein R comprises at least one substance selected from the group consisting of: hydrogen, alkyl, aryl, alkylaryl, acetyl, and a derivative thereof; where R′ comprises at least one substance selected from the group consisting of: hydrogen, alkyl, aryl, alkylaryl, acetyl, and a derivative thereof; wherein R and R′ cannot both be hydrogen; and wherein q is an integer between about 2 and 75. 
   
   
       18 . The method of  claim 15  further comprising:
 washing the well bore with a washing fluid.   
   
   
       19 . The method of  claim 15  further comprising:
 degrading at least a portion of the degradable diverting material to allow it to be removed from the well bore.   
   
   
       20 . The method of  claim 15  wherein the fracturing the subterranean formation comprises using a jetting tool to create or enhance the first fracture. 
   
   
       21 . The method of  claim 15  wherein the fracturing fluid comprises least one substance selected from the group consisting of: a fluid loss control additive, a gelling agent, a viscosifier, a gel stabilizer, a gas, a salt, a pH-adjusting agent, a corrosion inhibitor, a dispersant, a flocculent, an acid, a foaming agent, an antifoaming agent, an H 2 S scavenger, a lubricant, an oxygen scavenger, a weighting agent, a scale inhibitor, a surfactant, a catalyst, a clay control agent, a biocide, a friction reducer, a particulate, and a derivative thereof.