METHOD FOR MAKING A TREATMENT FLUID COMPRISING A DIVERTING AGENT IN FLAKE FORM, AND METHOD OF TREATING A WELL

• US 20200131428A1
• Filed: 07/14/2017
• Published: 04/30/2020
• Est. Priority Date: 08/01/2016
• Status: Active Grant

• Current Assignee: Independence Oilfield Chemicals, LLC (Innospec Incorporated)
• Original Assignee: Independence Oilfield Chemicals LLS
• Inventors: Dawson, Jeffrey C., Willingham, John R., Mitchell, Richard
• Granted Patent: US 10,982,128 B2
• Time in Patent Office: Days
• CPC Class Codes: C09K 2208/24 Bacteria or enzyme containing gel breakers
• CPC Class Codes: C09K 2208/26 Gel breakers other than bacteria or enzymes
• CPC Class Codes: C09K 8/512 containing cross-linking agents
• CPC Class Codes: C09K 8/514 of natural origin, e.g. polysaccharides, cellulose C09K8/512 takes precedence
• CPC Class Codes: C09K 8/516 characterised by their form or by the form of their components, e.g. encapsulated material
• CPC Class Codes: C09K 8/68 containing organic compounds
• CPC Class Codes: C09K 8/685 containing cross-linking agents
• CPC Class Codes: C09K 8/70 characterised by their form or by the form of their components, e.g. foams
• CPC Class Codes: C09K 8/80 Compositions for reinforcing fractures, e.g. compositions of proppants used to keep the fractures open
• CPC Class Codes: C09K 8/887 containing cross-linking agents
• CPC Class Codes: C09K 8/90 of natural origin, e.g. polysaccharides, cellulose
• CPC Class Codes: C09K 8/92 characterised by their form or by the form of their components, e.g. encapsulated material C09K8/70 takes precedence
• CPC Class Codes: E21B 33/138 Plastering the borehole wall; Injecting into the formation
• CPC Class Codes: E21B 43/267 reinforcing fractures by propping

Abstract

A method of treating a subterranean formation penetrated by a well-bore, for example to facilitate fracturing of the formation, comprises the steps of: (i) selecting a treatment fluid comprising a diverting agent (A) in a flaked form, for example guar gum in a flaked form. (ii) introducing the treatment fluid into the subterranean formation via the well-bore to plug a region of the formation. Thereafter, the formation may be fractured or re-fractured.

Claims

1. A method of treating a subterranean formation penetrated by a well-bore, the method comprising the steps of:

(i) selecting a treatment fluid comprising a diverting agent (A) in a flaked form; and

(ii) introducing the treatment fluid into the subterranean formation via the well-bore to plug a region of the formation.

2. The method according to claim 1, wherein, at least 50% of the number of flakes of diverting agent (A) when in dehydrated form have a first aspect ratio defined as the width/thickness of at least 2 and a second aspect ratio defined as the length/thickness of at least 5.

3. The method according to claim 1, wherein said diverting agent (A), in dehydrated form, has a D10 of at least 500 μ

m and less than 3000 μ

m; and

/or a D50 of at least 100 μ

m and less than 15000 μ

m.

4. The method according to claim 1, wherein said diverting agent (A) is a polysaccharide gum.

5. The method according to claim 1, wherein said diverting agent (A) comprises guar gum in a flaked form.

6. The method according to claim 1, wherein said treatment fluid includes at least 40 wt % water.

7. The method according to claim 1, wherein said treatment fluid includes a viscosifying agent arranged to suspend particulates in the treatment fluid.

8. The method according to claim 7, wherein said viscosifying agent is a metal-cross-linked polymer.

9. The method according to claim 7, wherein said viscosifying agent comprises a cross-linked polysaccharide.

10. The method according to claim 7, wherein said viscosifying agent comprises a cross-linked guar gum.

11. The method according to claim 1, further comprising the diverting agent (A) by thermal degradation at a temperature of greater than or equal to 275°

F.

12. The method according to claim 1, further comprising removing the diverting agent (A) by addition of a guar degrading substance at a temperature of below 200°

F.

13. The method according to claim 1, which includes treatment with a guar degrading substance.

14. The method according to claim 1, wherein said treatment fluid further comprises a diverting agent (B).

15. The method according to claim 14, wherein said diverting agent (B) is arranged to produce acid after decomposition.

16. The method according to claim 14, wherein said diverting agent (B) comprises a polyester.

17. The method according to claim 14, wherein said diverting agent (B) is polylactic acid.

18. The method according to claim 14, wherein, in said treatment fluid, a ratio (II) defined as the weight of diverting agent (A) divided by the weight of diverting agent (B) is in the range 1:

5 to 5;

1.

19. The method according to claim 14, further comprising the step of removal of the diverting agent (A) and diverting agent (B) by thermal degradation at a temperature of greater than or equal to 200°

F.

20. The method of claim 1, wherein said treatment fluid selected in step (i) has a pH greater than 7 and a pH of 12 or less.

21. The method of claim 1, wherein said treatment fluid is arranged to define a sealing composition which is introduced into the subterranean formation in the method.

22. The method of claim 1, wherein the method is used to divert fluid and proppant in a new well.

23. The method of claim 1, wherein the method is used to divert fluid and proppant in an old well in a refracturing mode.

24. The method of claim 1, which comprises a method of hydraulic stimulation of the subterranean formation.

25. The method of claim 1, wherein, at some stage in the method, said treatment fluid introduced into the formation in step (ii) includes one or a plurality of proppants.

26. A method of making a treatment fluid, the method comprising:

(a) selecting a diverting agent (A);

(b) selecting a diverting agent (B);

(c) selecting a viscosifying agent or a precursor of a viscosifying agent; and

(d) contacting diverting agent (A) and diverting agent (B) with the viscosifying agent or said precursor of said viscosifying agent.

27. The method according to claim 26, wherein, in step (c), a precursor is selected which is a guar gum.

28. The method according to claim 26, wherein the method includes the step of contacting said precursor with a cross-linking agent.

29. The method of claim 26, which includes the step of adjusting the pH of the treatment fluid to a pH of at least 9.

30. The method of claim 26, the method including the step of incorporating one or more proppants into the treatment fluid.