Methods of treating subterranean formations using hydrophobically modified polymers and compositions of the same

• US 20040209780A1
• Filed: 04/18/2003
• Published: 10/21/2004
• Est. Priority Date: 04/18/2003
• Status: Abandoned Application

• Current Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Original Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Inventors: Harris, Phillip C., Funkhouser, Gary P., Heath, Stanley J.
• Application Number:
  US10/419,013
• Publication Number:
  US 20040209780A1
• Time in Patent Office: Days
• US Class Current: 507/117
• CPC Class Codes: C09K 8/602 containing surfactants
• CPC Class Codes: C09K 8/68 containing organic compounds
• CPC Class Codes: C09K 8/703 Foams
• CPC Class Codes: C09K 8/88 macromolecular compounds

Abstract

Methods for treating subterranean formations, hydrophobically modified polymer compositions and fracturing fluid compositions containing hydrophobically modified polymer are provided. The hydrophobically modified polymer compositions wherein a plurality of hydrophobic groups are formed on the polymer, are basically comprised of water, a charged polymer, and surfactant. The surfactant has a charge opposite to that of the polymer and is capable of forming ion-pair associations with the polymer.

Claims

1. A method of treating a subterranean formation comprising the steps of:

(a) preparing a treating fluid composition comprising water, a charged polymer, and a surfactant having a charge that is opposite to that of the charged polymer, said surfactant being capable of forming an ion-pair association with said polymer resulting in a hydrophobically modified polymer having a plurality of hydrophobic groups; and

(b) injecting said treating fluid composition into a well bore to treat said subterranean formation.

2. The method of claim 1 wherein said water is selected from the group of fresh water and salt water and is present in said hydrophobically modified polymer composition in an amount in the range of from about 95% to about 99.9% by weight thereof.

3. The method of claim 1 wherein said charged polymer is an anionic polymer selected from the group consisting of carboxymethyl guar, carboxymethylhydroxypropyl guar, carboxymethylhydroxyethyl cellulose, polyacrylic acid, polyacrylate copolymers, 2-acrylamido-2-methylpropanesulfonic acid and salts, and mixtures thereof.

4. The method of claim 1 wherein said charged polymer is a cationic polymer selected from the group consisting of cationic polyacrylamide copolymers, cationic guar, cationic cellulose derivatives, cationic polysaccharide derivatives, choline methacrylate and mixtures thereof.

5. The method of claim 1 wherein said charged polymer is present in said treating fluid composition in an amount in the range of from about 0.1% to about 2.0% by weight thereof.

6. The method of claim 1 wherein said charged polymer is cationic and said surfactant is an anionic surfactant selected from the group consisting of alpha olefin sulfonate, alkylether sulfates, alkyl phosphonates, alkane sulfonates, fatty acid salts, and arylsulfonic acid salts, and mixtures thereof.

7. The method of claim 1 wherein said charged polymer is anionic and said surfactant is a cationic surfactant selected from the group consisting of trimethylcocoammonium chloride, trimethyltallowammonium chloride, dimethyldicocoammonium chloride, bis(2-hydroxyethyl)tallowamine, bis(2-hydroxyethyl)erucylamine, bis(2-hydroxyethyl)coco-amine, cetylpyridinium chloride, and mixtures thereof.

8. The method of claim 1 wherein said surfactant is present in said treating fluid composition in an amount in the range of from about 0.05% to about 1.0% by weight thereof.

9. The method of claim 1 wherein said charged polymer is carboxymethylhydroxypropyl guar, and said surfactant is trimethyltallowammonium chloride.

10. The method of claim 1 wherein said treating fluid composition further comprises a viscosity-enhancing agent capable of enhancing the formation of micellar bonds between hydrophobic groups on said polymer and/or between hydrophobic groups on adjacent polymer molecules.

11. The method of claim 1 wherein said treating fluid further comprises a viscosity-enhancing agent selected from the group consisting of fatty alcohols, ethoxylated fatty alcohols and amine oxides having hydrophobic chain lengths of C₆ to C₂₂, and mixtures thereof.

12. The method of claim 11 wherein said viscosity-enhancing agent is present in said treating fluid composition in an amount in the range of from about 0.05% to about 1.0% by weight thereof.

13. A method of forming one or more fractures in a subterranean zone penetrated by a well bore comprising the steps of:

(a) preparing a fracturing fluid composition comprising water, a charged polymer, and a surfactant having a charge that is opposite to that of the charged polymer, said surfactant being capable of forming an ion-pair association with said polymer resulting in a hydrophobically modified polymer having a plurality of hydrophobic groups;

(b) introducing said fracturing fluid into said subterranean zone through said well bore under conditions effective to create at least one fracture therein.

14. The method of claim 13 wherein said water is selected from the group of fresh water and salt water and is present in said fracturing fluid composition in an amount in the range of from about 95% to about 99.9% by weight thereof.

15. The method of claim 13 wherein said charged polymer is an anionic polymer selected from the group consisting of carboxymethyl guar, carboxymethylhydroxypropyl guar, carboxymethylhydroxyethyl cellulose, polyacrylic acid, polyacrylate copolymers, 2-acrylamido-2-methylpropanesulfonic acid and salts and mixtures thereof.

16. The method of claim 13 wherein said charged polymer is a cationic polymer selected from the group consisting of cationic polyacrylamide copolymers, cationic guar, cationic cellulose derivatives, cationic polysaccharide derivatives, choline methacrylate and mixtures thereof.

17. The method of claim 13 wherein said charged polymer is present in said fracturing fluid composition in an amount in the range of from about 0.1% to about 2.0% by weight thereof.

18. The method of claim 13 wherein said charged polymer is cationic and said surfactant is an anionic surfactant selected from the group consisting of alpha olefin sulfonate, alkylether sulfates, alkyl phosphonates, alkane sulfonates, fatty acid salts, and arylsulfonic acid salts, and mixtures thereof.

19. The method of claim 13 wherein said charged polymer is anionic and said surfactant is a cationic surfactant selected from the group consisting of trimethylcocoammonium chloride, trimethyltallowammonium chloride, dimethyldicocoammonium chloride, bis(2-hydroxyethyl)tallowamine, bis(2-hydroxyethyl)erucylamine, bis(2-hydroxyethyl)coco-amine, cetylpyridinium chloride, and mixtures thereof.

20. The method of claim 13 wherein said surfactant is present in said fracturing fluid composition in an amount in the range of from about 0.05% to about 1.0% by weight thereof.

21. The method of claim 13 wherein said charged polymer is carboxymethylhydroxypropyl guar, and said surfactant is trimethyltallowammonium chloride.

22. The method of claim 13 wherein said fracturing fluid composition further comprises a viscosity-enhancing agent capable of enhancing the formation of micellar bonds between hydrophobic groups on said polymer and/or between hydrophobic groups on adjacent polymer molecules.

23. The method of claim 13 wherein said fracturing fluid further comprises a viscosity-enhancing agent selected from the group consisting of fatty alcohols, ethoxylated fatty alcohols and amine oxides having hydrophobic chain lengths of C₆ to C₂₂, and mixtures thereof.

24. The method of claim 23 wherein said viscosity-enhancing agent is added to said fracturing fluid composition in an amount in the range of from about 0.05% to about 1.0% by weight thereof.

25. The method of claim 13 wherein said fracturing fluid composition further comprises a proppant material.

26. The method of claim 25 wherein said proppant is selected from the group consisting of sand, graded gravel, glass beads, sintered bauxite, resin coated sand ceramics, and intermediate strength ceramics.

27. The method of claim 25 wherein said proppant is present in said fracturing fluid composition in an amount in the range of from about 0.5 lb/gal to about 24 lb/gal thereof.

28. A method of forming one or more fractures in a subterranean zone penetrated by a well bore comprising the steps of:

(a) preparing a foamed fracturing fluid composition comprising water, a charged polymer, a surfactant having a charge that is opposite to that of the charged polymer, said surfactant being capable of forming an ion-pair association with said polymer resulting in a hydrophobically modified polymer having a plurality of hydrophobic groups, a foaming agent and sufficient gas to form a foam; and

(b) introducing said foamed fracturing fluid into said subterranean zone through said well bore under conditions effective to create at least one fracture therein.

29. The method of claim 28 wherein said foaming agent is a cationic surfactant selected from the group consisting of trimethylcocoammonium chloride, trimethyltallowammonium chloride, dimethyldicocoammonium chloride, bis(2-hydroxyethyl)tallowamine, bis(2-hydroxyethyl)erucylamine, bis(2-hydroxyethyl)coco-amine, cetylpyridinium chloride, and mixtures thereof.

30. The method of claim 28 wherein said foaming agent is an anionic surfactant selected from the group consisting of alpha olefin sulfonate, alkylether sulfates, alkyl phosphonates, alkane sulfonates, fatty acid salts, arylsulfonic acid salts and mixtures thereof.

31. The method of claim 28 wherein said gas is selected from the group consisting of air, nitrogen, carbon dioxide and mixtures thereof.

32. A treating fluid composition for treating a subterranean formation wherein said treating fluid composition comprises:

water;

a charged polymer; and

a surfactant having a charge that is opposite to that of the charged polymer, said surfactant being capable of forming an ion-pair association with said polymer resulting in a hydrophobically modified polymer having a plurality of hydrophobic groups.

33. The composition of claim 32 wherein said water is selected from the group of fresh water and salt water and is present in said treating fluid composition in an amount in the range of from about 95% to about 99.9% by weight thereof.

34. The composition of claim 32 wherein said charged polymer is an anionic polymer selected from the group consisting of carboxymethyl guar, carboxymethylhydroxypropyl guar, carboxymethylhydroxyethyl cellulose, polyacrylic acid, polyacrylate copolymers, 2-acrylamido-2-methylpropanesulfonic acid and salts, and mixtures thereof.

35. The composition of claim 32 wherein said charged polymer is a cationic polymer selected from the group consisting of cationic polyacrylamide, cationic guar, cationic cellulose derivatives, cationic polysaccharide derivatives, choline methacrylate and mixtures thereof.

36. The composition of claim 32 wherein said charged polymer is present in said treating fluid composition in an amount in the range of from about 0.1% to about 2.0% by weight thereof.

37. The composition of claim 32 wherein said charged polymer is cationic and said surfactant is an anionic surfactant selected from the group consisting of alpha olefin sulfonate, alkylether sulfates, alkyl phosphonates, alkane sulfonates, fatty acid salts, and arylsulfonic acid salts, and mixtures thereof. thereof.

38. The composition of claim 32 wherein said charged polymer is anionic and said surfactant is a cationic surfactant selected from the group consisting of trimethylcocoammonium chloride, trimethyltallowammonium chloride, dimethyldicocoammonium chloride, bis(2-hydroxyethyl)tallowamine, bis(2-hydroxyethyl)erucylamine, bis(2-hydroxyethyl)coco-amine, cetylpyridinium chloride, and mixtures thereof.

39. The composition of claim 32 wherein said surfactant is present in said treating fluid composition in an amount in the range of from about 0.05% to about 1.0% by weight thereof.

40. The composition of claim 32 wherein said charged polymer is carboxymethylhydroxypropyl guar, and said surfactant is trimethyltallowammonium chloride.

41. The composition of claim 32 further comprising a viscosity-enhancing agent capable of enhancing the formation of micellar bonds between hydrophobic groups on said polymer and/or between hydrophobic groups on adjacent polymer molecules.

42. The composition of claim 32 further comprising a viscosity-enhancing agent selected from the group consisting of fatty alcohols, ethoxylated fatty alcohols and amine oxides having hydrophobic chain lengths of C₆ to C₂₂, and mixtures thereof.

43. The composition of claim 42 wherein said viscosity-enhancing agent is present in said treating fluid composition in an amount in the range of from about 0.05% to about 1.0% by weight thereof.

44. The composition of claim 32 further comprising a proppant.

45. The composition of claim 44 wherein said proppant is selected from the group consisting of sand, graded gravel, glass beads, sintered bauxite, resin coated sand ceramics, and intermediate strength ceramics.

46. The composition of claim 44 wherein said proppant is present in said treating fluid composition in an amount in the range of from about 0.5 lb/gal to about 24 lb/gal thereof.

47. The composition of claim 32 further comprising an effective amount of a foaming agent and sufficient gas to form a foam.

48. The composition of claim 47 wherein said foaming agent is a cationic surfactant selected from the group consisting of trimethylcocoammonium chloride, trimethyltallowammonium chloride, dimethyldicocoammonium chloride, bis(2-hydroxyethyl)tallowamine, bis(2-hydroxyethyl)erucylamine, bis(2-hydroxyethyl)coco-amine, cetylpyridinium chloride, and mixtures thereof.

49. The composition of claim 47 wherein said foaming agent is an anionic surfactant selected from the group consisting of alpha olefin sulfonate, alkylether sulfates, alkyl phosphonates, alkane sulfonates, fatty acid salts, arylsulfonic acid salts and mixtures thereof.

50. The composition of claim 47 wherein said foaming agent is present in said composition in an amount in the range of from about 0.1% to 2.0% by weight thereof.

51. The composition of claim 47 wherein said gas is selected from the group consisting of air, nitrogen, carbon dioxide and mixtures thereof.