Method for stabilizing wellbore, stabilized wellbore and wellbore stabilizing fluid

Patent metadata

Field	Value
Publication number	US-2024240072-A1
Application number	US-202418620446-A
Country	US
Kind code	A1
Filing date	Mar 28, 2024
Priority date	Mar 17, 2022
Publication date	Jul 18, 2024
Grant date	—

Abstract

A method for stabilizing a wellbore includes introducing a hardening agent into the wellbore, mixing the hardening agent with a carrier fluid in the wellbore to produce a wellbore stabilizing fluid, and treating a wellbore wall of the wellbore by contacting the wellbore stabilizing fluid to a surface of the wellbore wall for at least 48 hours. A wellbore stabilizing fluid includes a hardening agent and a carrier fluid. The hardening agent is selected from one of 10 to 100 g/L of the calcium hydroxide nanocrystals, 5 to 99.9% by volume of tetraethyl orthosilicate (TEOS), and 10 to 50 g/L of zinc sulfate. A stabilized wellbore includes a wellbore having a wellbore wall treated with a wellbore stabilizing fluid comprising a hardening agent. The Young's modulus of the treated wellbore wall is at least 5% higher than a Young's modulus of a non-treated wellbore wall.

First claim

1 . A method for stabilizing a wellbore, the method comprising a treatment cycle of:
introducing a hardening agent into the wellbore; mixing the hardening agent with a carrier fluid in the wellbore to produce a wellbore stabilizing fluid; and treating a wellbore wall of the wellbore by contacting the wellbore stabilizing fluid to a surface of the wellbore wall and maintaining the contacting for at least 48 hours.

2 . The method of claim 1 , wherein hardening agent comprises zinc sulfate.

3 . The method of claim 2 , wherein the hardening agent comprises
10 g/L to 50 g/L of zinc sulfate.

4 . The method of claim 1 , wherein the wellbore stabilizing fluid further comprises a solvent comprising at least one of ethanol and isopropanol.

5 . The method of claim 1 , wherein the method further comprises repeating the treatment cycle of the introducing the hardening agent, the mixing, and the treating at least once.

6 . (canceled)

7 . The method of claim 1 , wherein the method is conducted at an elevated temperature ranging from 40° C. to 100° C.

8 . The method of claim 1 , wherein a Young's modulus of the wellbore wall after the treating is at least 5% higher than a Young's modulus of the wellbore wall before the treating.

9 . (canceled)

10 . (canceled)

11 . A stabilized wellbore, comprising:
a wellbore having a wellbore wall treated with a wellbore stabilizing fluid comprising a hardening agent, wherein a Young's modulus of the wellbore wall treated with the wellbore stabilizing fluid is at least 5% higher than a Young's modulus of a wellbore wall of a wellbore not treated by the wellbore stabilizing fluid.

12 . The stabilized wellbore of claim 11 , wherein the hardening agent comprises zinc sulfate.

13 . The stabilized wellbore of claim 12 , wherein the hardening agent comprises
10 g/L to 50 g/L of zinc sulfate.

14 . (canceled)

Assignees

• Saudi Arabian Oil Co
• Univ King Fahd Pet & Minerals

Inventors

• Desouky Mahmoud H
• Aljawad Murtada Saleh
• Solling Theis
• Altammar Murtadha J
• Alruwaili Khalid Mohammed

Classifications

• C04B7/345

  Hydraulic cements not provided for in one of the groups C04B7/02 - C04B7/34 · CPC title

• E21B33/138 Primary

  Plastering the borehole wall; Injecting into the formation · CPC title

• C04B26/32

  containing silicon · CPC title

• C04B2103/0093

  Organic cosolvents · CPC title

• C04B2/02

  Lime {(obtaining Ca(OH)2 otherwise than by simple slaking of quick lime C01F11/02)} · CPC title