Use of nanoparticles in cleaning well bores

• US 10,077,636 B2
• Filed: 10/31/2013
• Issued: 09/18/2018
• Est. Priority Date: 03/27/2013
• Status: Active Grant

• Current Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Original Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Inventors: Marr, Alan William, Hall, Lee Jeremy, Livanec, Philip Wayne
• Primary Examiner(s): Tran, Binh X
• Assistant Examiner(s): Cathey, Jr., David
• Application Number:
  US14/068,901
• Publication Number:
  US 20140290958A1
• Time in Patent Office: 1,783 Days
• Field of Search: None
• CPC Class Codes: C09K 2208/10 Nanoparticle-containing well treatment fluids
• CPC Class Codes: C09K 8/524 organic depositions, e.g. paraffins or asphaltenes
• CPC Class Codes: E21B 37/06 using chemical means for preventing or limiting , e.g. eliminating, the deposition of paraffins or like substances

Abstract

Embodiments relate to removing residue from a well bore and well bore equipment with a treatment fluid composition, and in some embodiments, to treatment fluid compositions that comprise nanoparticles. An embodiment provides a method of removing drilling fluid residue from the surfaces of well equipment. The method comprising: applying a solid nanoparticle film to at least a portion of the surfaces of the well equipment with a treatment fluid comprising solid nanoparticles; and allowing the solid nanoparticles to interact with the surfaces of the well equipment and the drilling fluid residue adhered to the surfaces of the well equipment to remove at least a portion of the drilling fluid residue from the surfaces of the well equipment.

Claims

1. A method of removing drilling fluid residue from surfaces of well equipment, the method comprising:

providing solid nanoparticles that are functionalized, wherein the solid nanoparticles comprise Fe₂O₃ or CaCO₃ wherein the solid nanoparticles are functionalized with polyvinyl pyrrolidone or polyethyleneimine, wherein the solid nanoparticles have an average particle size of about 5 nm to about 50 nm, wherein the solid nanoparticles have a roundness of greater than 0.7 measured on the Krumbein scale, and wherein the solid nanoparticles have a sphericity of greater than 0.7 measured on the Krumbein scale;

including the solid nanoparticles in a treatment fluid;

applying a solid nanoparticle film to at least a portion of the surfaces of the well equipment with the treatment fluid; and

allowing the solid nanoparticle film to interact with the surfaces of the well equipment and the drilling fluid residue adhered to the surfaces of the well equipment to remove at least a portion of the drilling fluid residue from the surfaces of the well equipment, wherein through surface energies and Brownian motion, the solid nanoparticle film exerts a disjointing force on the drilling fluid residue that forms a wedge driving separation of the drilling fluid residue from the surfaces of the well equipment.

2. The method of claim 1 further comprising pumping the treatment fluid through a pipe string and into an annulus between the pipe string and a casing that is fixed in the subterranean formation.

3. The method of claim 1 further comprising monitoring the amount of the solid nanoparticles present in the treatment fluid;

and adding additional solid nanoparticles to the treatment fluid in response to the step of monitoring.

4. The method of claim 1 wherein the treatment fluid is placed in the well bore to interact with the drilling fluid residue present at a specific location therein.

5. The method of claim 1 wherein the treatment fluid is placed into the well bore after drilling of the well bore.

6. The method of claim 1 wherein the concentration of solid nanoparticles in the treatment fluid is between about 0.1% and about 5% by volume of the treatment fluid.

7. The method of claim 1 wherein the well equipment comprises equipment selected from the group consisting of a pipe string, a drill pipe, a drill collars, a drill bit, a mud motor, a directional drill, a casing, a liner, a shaker, a shaker screen, a centrifuge, a metal line, a fitting, an impeller, and any combination thereof.

8. A method of removing drilling fluid residue from surfaces of well equipment, the method comprising:

providing solid nanoparticles that are functionalized, wherein the solid nanoparticles comprise nano-silica or nano-alumina wherein the solid nanoparticles are functionalized with trichlorosilane, wherein the solid nanoparticles have an average particle size of about 5 nm to about 50 nm, wherein the solid nanoparticles have a roundness of greater than 0.7 measured on the Krumbein scale, and wherein the solid nanoparticles have a sphericity of greater than 0.7 measured on the Krumbein scale;

including the solid nanoparticles in a treatment fluid;

applying a solid nanoparticle film to at least a portion of the surfaces of the well equipment with the treatment fluid; and

allowing the solid nanoparticle film to interact with the surfaces of the well equipment and the drilling fluid residue adhered to the surfaces of the well equipment to remove at least a portion of the drilling fluid residue from the surfaces of the well equipment, wherein through surface energies and Brownian motion, the solid nanoparticle film exerts a disjointing force on the drilling fluid residue that forms a wedge driving separation of the drilling fluid residue from the surfaces of the well equipment.

9. The method of claim 8 further comprising pumping the treatment fluid through a pipe string and into an annulus between the pipe string and a casing that is fixed in the subterranean formation.

10. The method of claim 8 further comprising monitoring the amount of the solid nanoparticles present in the treatment fluid;

and adding additional solid nanoparticles to the treatment fluid in response to the step of monitoring.

11. The method of claim 8 wherein the treatment fluid is placed in the well bore to interact with the drilling fluid residue present at a specific location therein.

12. The method of claim 8 wherein the treatment fluid is placed into the well bore after drilling of the well bore.

13. The method of claim 8 wherein the concentration of solid nanoparticles in the treatment fluid is between about 0.1% and about 5% by volume of the treatment fluid.

14. The method of claim 8 wherein the well equipment comprises equipment selected from the group consisting of a pipe string, a drill pipe, a drill collars, a drill bit, a mud motor, a directional drill, a casing, a liner, a shaker, a shaker screen, a centrifuge, a metal line, a fitting, an impeller, and any combination thereof.