Packer fluids including ethylene glycol

Patent metadata

Field	Value
Publication number	US-2025333637-A1
Application number	US-202418650920-A
Country	US
Kind code	A1
Filing date	Apr 30, 2024
Priority date	Apr 30, 2024
Publication date	Oct 30, 2025
Grant date	—

Abstract

The present disclosure relates to packer fluids including water and ethylene glycol, to methods for treating a wellbore with such packer fluids, and to wellbores including such packer fluids disposed in an annulus thereof.

First claim

What is claimed is:

1 . A method of treating a wellbore, comprising
providing a packer fluid comprising water and ethylene glycol, present in the packer fluid in a weight ratio of about 100:1 to about 1:1; and injecting the packer fluid into an annulus of the wellbore.

2 . The method of claim 1 , wherein the water and ethylene glycol are present in the packer fluid in a weight ratio of about 20:1 to about 1:1.

3 . The method of claim 1 , wherein the water and ethylene glycol are present in the packer fluid in a weight ratio of about 10:1 to about 1.5:1.

4 . The method of claim 1 , wherein the packer fluid comprises
about 50 wt % to about 95 wt % water; and about 5 wt % to about 50 wt % ethylene glycol.

5 . The method of claim 1 , wherein the packer fluid comprises
about 60 wt % to about 90 wt % water; and about 10 wt % to about 40 wt % ethylene glycol.

6 . The method of claim 1 , wherein the packer fluid further comprises a weighting agent.

7 . The method of claim 6 , wherein the weighting agent comprises hematite, barite, manganese tetroxide, marble dust, or any combination thereof.

8 . The method of claim 7 , wherein the weighting agent comprises barite.

9 . The method of claim 7 , wherein the weighting agent comprises marble dust.

10 . The method of claim 9 , wherein an average particle size of the marble dust is about 1 μm to about 100 μm.

11 . The method of claim 9 , wherein an average particle size of the marble dust is about 5 μm to about 50 μm.

12 . The method of claim 6 , wherein the packer fluid comprises
about 25 wt % to about 70 wt % water; about 2 wt % to about 25 wt % ethylene glycol; and about 25 wt % to about 73 wt % weighting agent.

13 . The method of claim 6 , wherein the packer fluid comprises
about 30 wt % to about 55 wt % water; about 5 wt % to about 20 wt % ethylene glycol; and about 35 wt % to about 65 wt % weighting agent.

14 . The method of claim 1 , wherein the packer fluid comprises less than about 5 wt % of a salt.

15 . The method of claim 1 , wherein the packer fluid is substantially free from salts.

16 . The method of claim 1 , wherein the annulus comprises a brine before injecting the packer fluid, and injecting the packer fluid displaces the brine from the annulus.

17 . The method of claim 1 , wherein the annulus comprises a tubing-casing anulus.

18 . The method of claim 1 , wherein the annulus comprises a casing-casing anulus.

19 . A method of preventing corrosion in a wellbore, comprising
providing a packer fluid comprising water and ethylene glycol, present in the packer fluid in a weight ratio of about 100:1 to about 1:1; and contacting a metal surface of the wellbore with the packer fluid.

20 . The method of claim 19 , wherein the water and ethylene glycol are present in the packer fluid in a weight ratio of about 20:1 to about 1:1.

21 . The method of claim 19 , wherein the packer fluid comprises
about 50 wt % to about 95 wt % water; and about 5 wt % to about 50 wt % ethylene glycol.

22 . The method of claim 19 , wherein the packer fluid is substantially free from salts.

23 . The method of claim 19 , wherein the metal surface comprises a surface of an annulus of the wellbore.

24 . A wellbore comprising:
an annulus; a packer disposed within the annulus; and a packer fluid disposed within the annulus and adjacent the packer;
wherein the packer fluid comprises water and ethylene glycol, present in the packer fluid in a weight ratio of about 100:1 to about 1:1.

25 . The wellbore of claim 24 , wherein the packer fluid comprises
about 50 wt % to about 95 wt % water; and about 5 wt % to about 50 wt % ethylene glycol.

26 . The method of claim 24 , wherein the packer fluid further comprises a weighting agent.

27 . The method of claim 26 , wherein the packer fluid comprises
about 25 wt % to about 50 wt % water; about 2 wt % to about 25 wt % ethylene glycol; and about 25 wt % to about 73 wt % weighting agent.

28 . The method of claim 24 , wherein the packer fluid comprises less than about 5 wt % of a salt.

29 . The method of claim 24 , wherein the packer fluid is substantially free from salt.

Assignees

• Saudi Arabian Oil Co

Inventors

• Abushullaih Hamzah Nader
• Al-Yami Abdullah Saleh Hussain
• Al Safran Ali Mohammed Hussain
• Aljohar Abdulwahab S
• Wagle Vikrant

Classifications

• C09K2208/32

  Anticorrosion additives · CPC title

• C09K8/54 Primary

  Compositions for in situ inhibition of corrosion in boreholes or wells · CPC title