High density brine with low crystallization temperature

Patent metadata

Field	Value
Publication number	US-11149180-B2
Application number	US-201615276153-A
Country	US
Kind code	B2
Filing date	Sep 26, 2016
Priority date	Sep 30, 2015
Publication date	Oct 19, 2021
Grant date	Oct 19, 2021

Abstract

A wellbore fluid comprising a first aqueous base fluid and a plurality of silica nanoparticles suspended in the first aqueous base fluid. The nanoparticles are present in the fluid in an amount to have an effect of decreasing a crystallization temperature by at least 4 to 55° F. as compared to a second aqueous base fluid without the silica nanoparticles.

First claim

What is claimed:

1. A method for completing, treating, or drilling a wellbore, the method comprising:
pumping a wellbore fluid into the wellbore, the wellbore fluid comprising:
a first aqueous base fluid; and
a plurality of silica nanoparticles suspended in the first aqueous base fluid, wherein the silica nanoparticles are present in the first aqueous base fluid in an amount to have an effect of decreasing a crystallization temperature by at least 4 to 55° F. as compared to a second aqueous base fluid without the silica nanoparticles, wherein the silica nanoparticles have at least one dimension of less than 1 micron and the amount of the silica nanoparticles present in the first aqueous base fluid is from 1 to 35 wt % of a total weight of the wellbore fluid;
wherein the first aqueous based fluid is a high density halide brine having a density in the range of about 11 ppg to about 18 ppg; and

performing at least one completion, treating or drilling operation while the wellbore fluid is in the wellbore;
wherein, while performing the at least one completion, treating, or drilling operation, the plurality of silica nanoparticles suspended in the first aqueous base fluid of the wellbore fluid form a stable dispersion in the wellbore fluid that has a pH ranging from 2 to 6.

2. The method of claim 1 , wherein the high density halide brine selected from the group of alkali metal and/or alkaline earth metal halide brines.

3. The wellbore fluid of claim 2 , wherein the crystallization temperature is a true crystallization temperature (TCT) or a pressurized crystallization temperature (PCT).

4. The method of claim 2 , wherein the high density halide brine does not comprise zinc.

5. The method of claim 1 , further comprising:
mixing the plurality of silica nanoparticles with a brine to provide a premix fluid; and
removing water from the premix fluid to form the wellbore fluid having a density in the range of about 11 ppg to about 18 ppg.

6. The method of claim 5 , wherein removing water is performed by mixing the premix fluid with dry salts with the formation of the wellbore fluid with a desired density within the range.

7. The method of claim 1 , wherein the wellbore fluid is a drilling fluid and further comprises a gelling agent and a plurality of salt or mineral particulates and wherein the pumping occurs during drilling the wellbore.

8. The method of claim 1 , wherein the wellbore fluid is a fluid loss pill and further comprises a gelling agent and a plurality of salt or mineral particulates, and wherein the pumping occurs upon experiencing fluid loss in the wellbore during a completion operation.

9. The method of claim 1 , wherein the wellbore fluid is a gravel packing fluid and wherein the pumping occurs during gravel packing of the wellbore.

Assignees

• Mi Llc
• Schlumberger Technology Corp

Inventors

• Zhang Hui Joyce
• Wei Xia
• Young Steven

Classifications

• C09K8/5045 Primary

  containing inorganic compounds · CPC title

• C09K8/032

  Inorganic additives · CPC title

• C09K8/516

  characterised by their form or by the form of their components, e.g. encapsulated material · CPC title

• C09K8/05 Primary

  containing inorganic compounds only, e.g. mixtures of clay and salt · CPC title

• C09K8/572

  containing inorganic compounds · CPC title