METHOD OF TREATING A SUBTERRANEAN FORMATION USING A RHEOLOGY MODEL FOR FLUID OPTIMIZATION

• US 20100314110A1
• Filed: 08/03/2010
• Published: 12/16/2010
• Est. Priority Date: 01/24/2006
• Status: Active Grant

• Current Assignee: Michael D. Parris, Murtaza Ziauddin, Thomas Lindvig
• Original Assignee: Michael D. Parris, Murtaza Ziauddin, Thomas Lindvig
• Inventors: Lindvig, Thomas, Parris, Michael D., Ziauddin, Murtaza
• Granted Patent: US 8,191,632 B2
• Time in Patent Office: Days
• US Class Current: 166/278
• CPC Class Codes: C09K 2208/08 Fiber-containing well treatment fluids
• CPC Class Codes: C09K 8/52 Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
• CPC Class Codes: C09K 8/685 containing cross-linking agents
• CPC Class Codes: C09K 8/74 combined with additives added for specific purposes

Abstract

Subterranean formation treatment methods incorporating a rheology model which enables prediction of fluid rheology properties during a treatment operation, where the foundation of the model is a description of the reaction chemistry which describes how the number of crosslinks and broken polymer linkages develops in time under the influence of crosslinkers, breakers, and/or thermally induced effects and pressure effects. In one aspect, when used as a tool for simulating the fluid viscosity, the model can help optimizing the fluid design and optional breaker schedule for a hydraulic fracturing treatment.

Claims

1-21. -21. (canceled)

22. A method for treating a subterranean formation, the method comprising:

a. calculating a formation treatment plan comprising treatment fluid comprising a polymer and a crosslinker using a fluid rheology model comprising;

i. inputting a concentration of polymer and a concentration of crosslinker,

ii. inputting temperature, formation pressure, and shear rate profiles over the course of the treatment,

iii. determining a fluid rheology based upon the input values from i. and ii over the course of the treatment;

b. implementing the formation treatment plan comprising preparing and injecting the treatment fluid into a wellbore; and

c. treating the subterranean formation.

23. The method of claim 22, further comprising inputting a concentration of breaker.

24. The method of claim 22, further comprising inputting the concentration of one or more pH modifiers over the course of the treatment.

25. The method of claim 22, wherein in the determining the fluid rheology is based upon incorporating a concentration of polymer and optimal clean-up after treatment.

26. The method of claim 22, further comprising inputting a concentration of a crosslinking delay agent over the course of the treatment.

27. The method of claim 22, further comprising monitoring the treatment fluid and evaluating the fluid performance downhole based upon real-time monitoring of the fluid composition at the surface.

28. The method of claim 22, further comprising inputting fluid pumping rate, wellbore configuration, and fluid travel time to a treatment zone.

29. The method of claim 22, wherein the formation treatment plan comprises fracturing a subterranean formation.

30. The method of claim 22, wherein the formation treatment plan comprises monitoring fluid placement during a treatment selected from the group consisting of fracturing treatments, acidizing treatments, wellbore cleanout operations, gravel packing operations, acid diversion treatments, and fluid loss control operations.

31. The method of claim 22, wherein the polymer is selected from the group consisting of guar, hydropropyl guar (HPG), carboxymethyl guar (CMG), carboxymethylhydroxypropyl guar, cellulose, hydroxyethylcellulose (HEC), hydroxypropylcellulose (HPC), carboxymethylhydroxyethylcellulose (CMHEC), xanthan, diutan, whelan gum, polyacrylamide, polyacrylate polymers, and wherein the crosslinker is a zirconium, titanium or borate based crosslinker.

32. The method of claim 22, wherein the polymer is guar and the crosslinker is a borate based crosslinker.

33. The method of claim 22, further comprising considering pressure effects on a borate-based crosslinker in determining the fluid rheology.

34. The method of claim 22, wherein the fluid further comprises a proppant, and wherein the calculating a plan comprises inputting a concentration of proppant.

35. The method of claim 22, wherein a concentration of polymer ranges from about 15 to about 40 pounds per thousand gallons.

36. The method of claim 22, wherein the concentration of polymer is about 15 pounds per thousand gallons or less.

37. A method for treating a subterranean formation, the method comprising:

a. calculating a formation treatment plan comprising treatment fluid comprising a polymer and a crosslinker using a fluid rheology model comprising;

i. a concentration of polymer and a concentration of crosslinker,

ii. temperature, formation pressure, and shear rate profiles over the course of the treatment,

iii. a fluid rheology estimate based upon the input values from i. and ii;

b. implementing the formation treatment plan to form and introduce the treatment fluid into a wellbore; and

c. treating the subterranean formation.

38. The method of claim 37, wherein the model further comprises a concentration of breaker.

39. The method of claim 37, wherein the model further comprises a concentration of one or more pH modifiers over the course of the treatment.

40. The method of claim 37, wherein the model further comprises a concentration of a crosslinking delay agent over the course of the treatment.

41. The method of claim 37, further comprising monitoring the treatment fluid and evaluating the fluid performance downhole based upon real-time monitoring of the fluid composition at the surface.

42. A method for treating a subterranean formation, the method comprising:

a. calculating a formation treatment plan comprising treatment fluid comprising a polymer and a crosslinker using a fluid rheology model comprising;

i. inputting a concentration of polymer, a concentration of crosslinker, a concentration of breaker, concentration of one or more pH modifiers, and a crosslinking delay agent,

ii. inputting temperature, formation pressure, and shear rate profiles over the course of the treatment,

iii. determining a fluid rheology based upon the input values from i. and ii over the course of the treatment;

b. implementing the formation treatment plan comprising preparing and injecting the treatment fluid into a wellbore.