Well treatment compositions and methods utilizing nano-particles

• US 9,199,879 B2
• Filed: 04/27/2012
• Issued: 12/01/2015
• Est. Priority Date: 05/10/2007
• Status: Active Grant

• Current Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Original Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Inventors: Thaemlitz, Carl J., Roddy, Craig W., Covington, Ricky L., Chatterji, Jiten, Brenneis, D. Chad
• Primary Examiner(s): Figueroa, John J
• Application Number:
  US13/458,112
• Publication Number:
  US 20120211227A1
• Time in Patent Office: 1,313 Days
• Field of Search: None
• US Class Current: 1/1
• CPC Class Codes: C04B 14/047 Zeolites
• CPC Class Codes: C04B 14/062 Microsilica, e.g. colloïdal silica preparing microsilica slurries or suspensions C04B18/148
• CPC Class Codes: C04B 14/08 Diatomaceous earth
• CPC Class Codes: C04B 14/104 Bentonite, e.g. montmorillonite
• CPC Class Codes: C04B 14/108 Shale, slate colliery shale C04B18/125
• CPC Class Codes: C04B 14/30 Oxides other than silica ferrites C04B14/363
• CPC Class Codes: C04B 14/303 Alumina
• CPC Class Codes: C04B 14/308 Iron oxide
• CPC Class Codes: C04B 14/368 Baryte
• CPC Class Codes: C04B 18/08 Flue dust , i.e. fly ash
• CPC Class Codes: C04B 18/141 Slags
• CPC Class Codes: C04B 18/162 Cement kiln dust; Lime kiln dust
• CPC Class Codes: C04B 20/0024 expanded in situ, i.e. the material is expanded or made hollow after primary shaping of the mortar, concrete or artificial stone mixture C04B16/085 takes precedence
• CPC Class Codes: C04B 20/008 Micro- or nanosized fillers, e.g. micronised fillers with particle size smaller than that of the hydraulic binder colloidal silica C04B14/062 ; silica fume C04B18/146
• CPC Class Codes: C04B 2111/00146 Sprayable or pumpable mixtures
• CPC Class Codes: C04B 24/36 Bituminous materials, e.g. tar, pitch C04B24/243 takes precedence
• CPC Class Codes: C04B 24/42 Organo-silicon compounds
• CPC Class Codes: C04B 28/02 containing hydraulic cements other than calcium sulfates
• CPC Class Codes: C04B 28/08 Slag cements
• CPC Class Codes: C04B 38/10 by using foaming agents C04B38/02 takes precedenceor by using mechanical means, e.g. adding preformed foam
• CPC Class Codes: C09K 2208/10 : Nanoparticle-containing well treatment fluids
• CPC Class Codes: C09K 8/032 : Inorganic additives
• CPC Class Codes: C09K 8/46 : containing inorganic binders, e.g. Portland cement
• CPC Class Codes: C09K 8/473 : Density reducing additives, e.g. for obtaining foamed cement compositions
• CPC Class Codes: C09K 8/487 : Fluid loss control additives; Additives for reducing or preventing circulation loss
• CPC Class Codes: C09K 8/502 : Oil-based compositions
• CPC Class Codes: C09K 8/5045 : containing inorganic compounds
• CPC Class Codes: C09K 8/516 : characterised by their form or by the form of their components, e.g. encapsulated material
• CPC Class Codes: Y02W 30/91 : Use of waste materials as fillers for mortars or concrete

Abstract

Disclosed embodiments relate to well treatment fluids and methods that utilize nano-particles. Exemplary nano-particles are selected from the group consisting of particulate nano-silica, nano-alumina, nano-zinc oxide, nano-boron, nano-iron oxide, and combinations thereof. Embodiments also relate to methods of cementing that include the use of nano-particles. An exemplary method of cementing comprises introducing a cement composition into a subterranean formation, wherein the cement composition comprises cement, water and a particulate nano-silica. Embodiments also relate to use of nano-particles in drilling fluids, completion fluids, simulation fluids, and well clean-up fluids.

Claims

1. A method of completing a well comprising:

including nano-particles in a completion fluid, wherein the nano-particles are selected from the group consisting of nano-silica, nano-alumina, nano-zinc oxide, nano-boron, nano-iron oxide, nano-barium sulphate, nano-manganese tetraoxide, nano-magnesium oxide, nano-calcium carbonate, nano-graphite, nano-barium oxide, nano-cerium oxide, nano-lanthium oxide, nano-titanium dioxide, nano-clay, nano-aluminosilicate, and any combination thereof;

wherein the nano-particles are present in the completion fluid in an amount in a range of from about 10% to about 70% by weight of the completion fluid; and

wherein the completion fluid has a density in a range of about 7.5 pounds per gallon to about 22 pounds per gallon;

introducing the completion fluid into a well bore; and

using the completion fluid in completing the well, wherein micron-sized or larger particles are not present in the completion fluid when completing the well such that the completion fluid does not plug production screens or other downhole equipment.

2. The method of claim 1 wherein the nano-particles have a particle size in a range of from about 1 nanometer to less than 1 micron.

3. The method of claim 1 wherein the nano-particles have a particle size in a range of from about 1 nanometer to about 100 nanometers.

4. The method of claim 1 wherein the completion fluid comprises at least one base fluid selected from the group consisting of an oil-based fluid, a water-based fluid, and a combination thereof.

5. The method of claim 1 wherein the completion fluid comprises at least one oil-based fluid selected from the group consisting of an olefin, an internal olefin, an alkane, an aromatic solvent, a cycloalkane, liquefied petroleum gas, kerosene, diesel oil, crude oil, heavy oil, gas oil, fuel oil, paraffin oil, mineral oil, low toxicity mineral oil, an ester, an amide, a polyolefin, a polydiorganosiloxane, a siloxane, an organosiloxane, an ether, an acetal, a dialkylcarbonate, a hydrocarbon, and any combination thereof.

6. The method of claim 1 wherein the completion fluid further comprises at least one additive selected from the group consisting of a salt, a surfactant, a fluid-loss-control additive, a gas, nitrogen, carbon dioxide, a surface-modifying agent, a foamer, a corrosion inhibitor, a scale inhibitor, a clay-control agent, a biocide, a friction reducer, an antifoam agent, a dispersant, a flocculant, H₂S scavenger, CO₂ scavenger, an oxygen scavenger, a lubricant, a viscosifier, a breaker, a wetting agent, and any combination thereof.

7. The method of claim 1 further comprising running downhole equipment into the well while the completion fluid is in the well.

8. The method of claim 1 further comprising running a wire-wrapped screen into the well while the completion fluid is in the well.

9. A method of completing a well comprising:

providing a cement-free completion fluid comprising nano-particles, wherein the nano-particles are selected from the group consisting of nano-silica, nano-alumina, nano-zinc oxide, nano-boron, nano-iron oxide, nano-barium sulphate, nano-manganese tetraoxide, nano-magnesium oxide, nano-calcium carbonate, nano-graphite, nano-barium oxide, nano-cerium oxide, nano-lanthium oxide, nano-titanium dioxide, nano-clay, nano-aluminosilicate, and any combination thereof;

wherein the nano-particles are present in the completion fluid in an amount in a range of from about 10% to about 70% by weight of the completion fluid; and

wherein the completion fluid has a density in a range of about 7.5 pounds per gallon to about 22 pounds per gallon;

introducing the cement-free completion fluid into a well bore and;

using the cement-free completion fluid in completing the well, wherein micron-sized or larger particles are not present in the cement-free completion fluid when completing the well such that the cement-free completion fluid does not plug production screens or other downhole equipment.

10. The method of claim 9 wherein the nano-particles have a particle size in a range of from about 1 nanometer to less than 1 micron.

11. The method of claim 9 wherein the nano-particles have a particle size of from about 1 nanometer to about 100 nanometers.

12. The method of claim 9 wherein the completion fluid comprises at least one base fluid selected from the group consisting of an oil-based fluid, a water-based fluid, or a combination thereof.

13. The method of claim 9 wherein the completion fluid comprises at least one oil-based fluid selected from the group consisting of an olefin, an internal olefin, an alkane, an aromatic solvent, a cycloalkane, liquefied petroleum gas, kerosene, diesel oil, crude oil, heavy oil, gas oil, fuel oil, paraffin oil, mineral oil, low toxicity mineral oil, an ester, an amide, a polyolefin, a polydiorganosiloxane, a siloxane, an organosiloxane, an ether, an acetal, a dialkylcarbonate, a hydrocarbon, and any combination thereof.

14. The method of claim 9 wherein the completion fluid further comprises at least one additive selected from the group consisting of a salt, a surfactant, a fluid-loss-control additive, a gas, nitrogen, carbon dioxide, a surface-modifying agent, a foamer, a corrosion inhibitor, a scale inhibitor, a clay-control agent, a biocide, a friction reducer, an antifoam agent, a dispersant, a flocculant, H₂S scavenger, CO₂ scavenger, an oxygen scavenger, a lubricant, a viscosifier, a breaker, a wetting agent, and any combination thereof.

15. The method of claim 9 further comprising running downhole equipment into the well bore while the completion fluid is in the well bore.

16. The method of claim 9 further comprising running a wire-wrapped screen into the well bore while the completion fluid is in the well bore.

17. A method of completing a well comprising:

including nano-particles having a particle size of from about 1 nanometer to about 100 nanometers in a cement-free completion fluid, wherein the nano-particles comprise at least one nano-particle selected from the group consisting of nano-alumina, nano-zinc oxide, nano-boron, nano-iron oxide, nano-silica, nano-barium sulphate, nano-manganese tetraoxide, nano-magnesium oxide, nano-calcium carbonate, nano-graphite, nano-barium oxide, nano-cerium oxide, nano-lanthium oxide, nano-titanium dioxide, nano-clay, nano-aluminosilicate, and any combination thereof;

wherein the nano-particles are present in the completion fluid in an amount in a range of from about 10% to about 70% by weight of the completion fluid; and

wherein the completion fluid has a density in a range of about 7.5 pounds per gallon to about 22 pounds per gallon;

introducing the cement-free completion fluid into a well bore;

using the cement-free completion fluid in completing the well, wherein micron-sized or larger particles are not present in the cement-free completion fluid such that the cement-free completion fluid does not plug production screens or other downhole equipment; and

running downhole equipment into the cement-free completion fluid in the well.