Well servicing fluid

• US 9,080,097 B2
• Filed: 05/28/2010
• Issued: 07/14/2015
• Est. Priority Date: 05/28/2010
• Status: Active Grant

• Current Assignee: Baker Hughes Holdings LLC (Baker Hughes Company)
• Original Assignee: Baker Hughes Incorporated (Baker Hughes Company)
• Inventors: Gupta, D. V. Satyanarayana, Cawiezel, Kay Elaine
• Primary Examiner(s): Bates, Zakiya W
• Assistant Examiner(s): RUNYAN, SILVANA C
• Application Number:
  US12/790,577
• Publication Number:
  US 20110290491A1
• Time in Patent Office: 1,873 Days
• US Class Current: 1/1
• CPC Class Codes: C09K 2208/10 Nanoparticle-containing well treatment fluids
• CPC Class Codes: C09K 8/665 containing inorganic compounds proppants C09K8/80
• CPC Class Codes: C09K 8/68 containing organic compounds
• CPC Class Codes: C09K 8/685 containing cross-linking agents
• 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 8/845 containing inorganic compounds

Abstract

A nano-dispersion well servicing fluid is formulated with components comprising: nanoparticles comprising at least one material chosen from aluminum oxides, aluminum hydroxides, aluminum hydroxyoxides, zirconium oxides, zirconium hydroxides, zirconium hydroxyoxides, wherein the concentration of nanoparticles is greater than 0.5% by weight based on the total weight of the nano-dispersion well servicing fluid. The well servicing fluid also comprises an aqueous base continuous phase. Methods of employing the nano-dispersion to service a wellbore are also disclosed.

Claims

1. A method of servicing a wellbore, the method comprising:

forming a nano-dispersion well servicing fluid by blending an aqueous base continuous phase and nanoparticles comprising at least one material chosen from aluminum oxides, aluminum hydroxides, aluminum hydroxyoxides, zirconium oxides, zirconium hydroxides, and zirconium hydroxyoxides, the concentration of the nanoparticles being greater than 0.5% by weight based on the total weight of the nano-dispersion well servicing fluid, the nanoparticles having a crystallized size of 100 nm or less in diameter prior to being dispersed, the nanoparticles forming a dispersion in the aqueous base, and the nanoparticles carrying a charge resulting in a Zeta potential in the well servicing fluid;

decreasing the Zeta potential of the well servicing fluid closer to zero and thereby increasing the viscosity; and

introducing the well servicing fluid with the increased viscosity into the wellbore.

2. The method of claim 1, wherein the nanoparticles comprise more than 50 wt. % boehmite.

3. The method of claim 1, wherein the nanoparticles have a crystallized size of about 5 to about 50 nm.

4. The method of claim 1, wherein the fluid has a Zeta potential ranging from about 0 to about 50.

5. The method of claim 1, wherein the fluid has a pH ranging from about 2 to about 14.

6. The method of claim 1, further comprising fracturing the wellbore with the well servicing fluid.

7. The method of claim 1, wherein the well servicing fluid is employed for gravel packing the wellbore.

8. The method of claim 1, wherein the concentration of nanoparticles ranges from about 2% to about 20% by weight based on the total weight of the nano-dispersion well servicing fluid.

9. The method of claim 1, wherein the fluid does not comprise a viscoelastic surfactant gelling agent in an amount effective to increase the viscosity of the fluid.

10. The method of claim 1, wherein the fluid has a first pH, and further wherein the Zeta potential of the fluid is decreased by increasing the first pH to a second pH greater than the first pH.

11. The method of claim 10, wherein adjusting the first pH comprises using a pH adjuster chosen from NaOH, KOH, Ca(OH)₂, sodium bicarbonate, potassium carbonate, and sodium carbonate.

12. The method of claim 1, wherein the fluid further comprises a proppant.

13. The method of claim 1, wherein the continuous phase is a liquid chosen from fresh water, brine, and produced water.

14. The method of claim 13, wherein a concentration of salt in the brine is 0.5% by weight or more, based on the total weight of the brine.

15. The method of claim 1, further comprising adjusting the Zeta potential of the fluid by adding a surfactant to the fluid.

16. The method of claim 15, wherein the surfactant is not a viscoelastic surfactant.

17. The method of claim 15, wherein the surfactant is added simultaneous with introducing the fluid into the wellbore.

18. The method of claim 1, further comprising adding an ester to the fluid to decrease the viscosity after decreasing the Zeta potential and increasing the viscosity.

19. The method of claim 18, wherein the ester is an ester of polycarboxylic acid.

20. The method of claim 18, wherein the ester is added simultaneous with introducing the fluid into the wellbore and provides a delayed increase in Zeta potential.

21. The method of claim 1, further comprising:

after introducing the well servicing fluid with the increased viscosity into the wellbore, increasing the Zeta potential of the fluid in the wellbore and thereby decreasing the viscosity; and

after decreasing the viscosity, recovering the well servicing fluid from the wellbore.

22. A method of servicing a wellbore, the method comprising:

forming a nano-dispersion well servicing fluid by blending an aqueous base continuous phase and nanoparticles comprising at least one material chosen from aluminum oxides, aluminum hydroxides, aluminum hydroxyoxides, zirconium oxides, zirconium hydroxides, and zirconium hydroxyoxides, the concentration of the nanoparticles being greater than 0.5% by weight based on the total weight of the nano-dispersion well servicing fluid, the nanoparticles having a crystallized size of 100 nm or less in diameter prior to being dispersed, and the nanoparticles forming a dispersion in the aqueous base;

including proppant operable for fracturing or gravel operable for gravel packing in the well servicing fluid;

introducing the well servicing fluid into the wellbore, the nanoparticles carrying a charge resulting in a Zeta potential in the well servicing fluid and the nanoparticles functioning independent of the proppant and gravel;

decreasing the Zeta potential of the well servicing fluid and thereby increasing the viscosity;

after decreasing the Zeta potential and increasing the viscosity, fracturing or gravel packing the wellbore;

after fracturing or gravel packing, increasing the Zeta potential of the well servicing fluid in the wellbore and thereby decreasing the viscosity; and

after decreasing the viscosity, recovering the well servicing fluid from the wellbore.

23. The method of claim 22, wherein the fluid does not comprise a viscoelastic surfactant gelling agent in an amount effective to increase the viscosity of the fluid.

24. The method of claim 22, wherein the fluid in the wellbore has a first pH, and further wherein the Zeta potential of the fluid is decreased by adjusting the first pH to a second pH greater than the first pH.

25. The method of claim 22, wherein introducing the well servicing fluid comprises introducing the well servicing fluid with the increased viscosity into the wellbore after the decreasing of the Zeta potential of the well servicing fluid and the increasing of the viscosity.