Methods for completing a wellbore using high density brine containing colloidal particles

Patent metadata

Field	Value
Publication number	US-12221578-B2
Application number	US-202218045999-A
Country	US
Kind code	B2
Filing date	Oct 12, 2022
Priority date	May 30, 2015
Publication date	Feb 11, 2025
Grant date	Feb 11, 2025

Abstract

A wellbore fluid comprising an aqueous base fluid and a plurality of nanoparticles suspended in the aqueous base fluid. The nanoparticles are present in the wellbore fluid in an amount effective to have an effect of increasing the density by at least 0.2 lb/gal.

First claim

What is claimed:

1. A method for completing a wellbore, the method comprising:
pumping a wellbore fluid into the wellbore, the wellbore fluid comprising:
an aqueous base fluid comprising a brine;
a plurality of nanoparticles suspended in the aqueous base fluid, wherein the nanoparticles are present in the wellbore fluid in an amount of 30 wt % to 60 wt % of the total weight of the wellbore fluid;
polyvinylpyrrolidone in an amount of 0.5 to 1.5 v % of the total weight of the wellbore fluid to lower a true crystallization temperature of the wellbore fluid;
a polymer viscosifier; and
bridging solid particles having an average size greater than or equal to about 1 μm; and

performing at least one completion operation while the wellbore fluid is in the wellbore.

2. The method of claim 1 , wherein the nanoparticles are selected from the group of silica, iron carbonate, iron oxide, titanium oxide, tungsten oxide, zirconium oxide, and zirconium silicate.

3. The method of claim 2 , wherein the silica nanoparticles are selected from the group of colloidal silica nanoparticles and nano-sized precipitated silica.

4. The method of claim 1 , wherein the aqueous base fluid is selected from the group of alkali metal halides, alkaline earth metal halides, and alkali metal formates.

5. The method of claim 1 , wherein the wellbore fluid has a viscosity ranging from about 5 cP to about 150 cP at room temperature.

6. The method of claim 1 , wherein the wellbore fluid has a turbidity ranging from about 10 to about 300 nephelometric turbidity units.

7. The method of claim 1 , further comprising:
mixing the plurality of nanoparticles with the brine at a pH ranging from about 2 to about 10 with the formation of a premix fluid; and
removing water from the premix fluid to form the wellbore fluid with a desired density.

8. The method of claim 7 , wherein removing water is performed by mixing the premix fluid with dry salts with the formation of the wellbore fluid with a desired density.

9. The method of claim 1 , wherein the wellbore fluid has a density in the range of about 11 ppg to about 18 ppg.

10. The method of claim 1 , wherein pumping a wellbore fluid into the wellbore comprises pumping a wellbore fluid exhibiting a viscosity less than 20 cP at room temperature into the wellbore.

11. The method of claim 1 , wherein pumping a wellbore fluid into the wellbore comprises pumping a wellbore fluid comprising coated nanoparticles into the wellbore.

12. The method of claim 1 , wherein pumping a wellbore fluid into the wellbore comprises pumping a wellbore fluid comprising silica nanoparticles coated with hydrous oxides or silane into the wellbore.

13. The method of claim 1 , wherein pumping a wellbore fluid into the wellbore comprises pumping a wellbore fluid comprising silica nanoparticles coated with alumina into the wellbore.

14. The method of claim 1 , wherein pumping a wellbore fluid into the wellbore comprises pumping a wellbore fluid comprising silica nanoparticles coated with silane into the wellbore.

15. The method of claim 1 , wherein pumping a wellbore fluid into the wellbore comprises pumping a wellbore fluid comprising nanoparticles of iron carbonate, tungsten oxide, zirconium oxide, or zirconium silicate into the wellbore.

16. The method of claim 1 , wherein pumping a wellbore fluid into the wellbore comprises pumping a wellbore fluid comprising silica nanoparticles including sodium ions bonded to a silica matrix of the silica nanoparticles into the wellbore.

17. A method comprising: introducing a wellbore fluid into a wellbore, wherein the wellbore fluid has a turbidity ranging from about 10 to about 300 nephelometric turbidity units, the wellbore fluid comprising:
polyvinylpyrrolidone in an amount of 0.5 to 1.5 v % of the total weight of the wellbore fluid;
an aqueous base fluid comprising a brine; and
a plurality of nanoparticles suspended in the aqueous base fluid, wherein the nanoparticles are selected from the group of silica, iron carbonate, iron oxide, titanium oxide, tungsten oxide, zirconium oxide, zirconium silicate; wherein the nanoparticles are present in the wellbore fluid in an amount of 30 wt. % to 60 wt. % of the total weight of the wellbore fluid,
wherein the wellbore fluid is a Newtonian fluid and exhibits a viscosity less than 20 cP at room temperature.

Assignees

• Schlumberger Technology Corp

Inventors

• Zhang Hui
• Wei Xia
• Price Hoelscher Brandi Katherine
• Young Steven

Classifications

• C09K8/92

  characterised by their form or by the form of their components, e.g. encapsulated material (C09K8/70 takes precedence) · CPC title

• C09K8/845

  containing inorganic compounds · CPC title

• C09K8/36

  Water-in-oil emulsions · CPC title

• C09K8/04 Primary

  Aqueous well-drilling compositions · CPC title

• C09K2208/10

  Nanoparticle-containing well treatment fluids · CPC title