Method of conducting a coiled tubing operation

Patent metadata

Field	Value
Publication number	US-12064787-B2
Application number	US-201916282971-A
Country	US
Kind code	B2
Filing date	Feb 22, 2019
Priority date	Feb 22, 2019
Publication date	Aug 20, 2024
Grant date	Aug 20, 2024

Abstract

The disclosure relates to a method of conducting a coiled tubing operation. In one implementation, a method includes forming a tubing string, the tubing string having an outer surface. The method also includes applying a coating to an application portion of the outer surface of the tubing string. The application portion includes a portion of the tubing string that will be disposed in a horizontal section of a wellbore, and the coating has a surface energy lower than a surface energy of the outer surface of the tubing string to thereby reduce friction between the tubing string and a casing disposed in the horizontal section of the wellbore as the tubing string is lowered into the wellbore.

First claim

We claim:

1. A method of conducting a coiled tubing operation, comprising:
forming a coiled tubing string, the coiled tubing string having an outer surface and being formed from a metallic material;
selecting an application portion of the coiled tubing string that corresponds to a horizontal section of a wellbore and a vertical section of the wellbore once the coiled tubing string is positioned in a fully deployed state within the wellbore, wherein the application portion does not include axial length of the coiled tubing string corresponding in the fully deployed state to a curved section of the wellbore disposed between the horizontal and vertical sections;
applying a coating to the outer surface of the coiled tubing string only along the application portion, wherein the coating has a surface energy lower than a surface energy of the outer surface of the coiled tubing string to thereby reduce friction between the tubing coiled string and a casing disposed in the horizontal section of the wellbore as the coiled tubing string is lowered into the wellbore, wherein the coating has a thickness within a range of 0.002 inches to 0.02 inches after application; and
lowering the coiled tubing string into the wellbore to the fully deployed state such that the coating covers an entirety of the outer surface of the coiled tubing string in the horizontal section of the wellbore and all of the coiled tubing string in the vertical section of the wellbore, but the coiled tubing string in the curved section of the wellbore does not have the coating.

2. The method of claim 1 , further comprising creating an anchor profile on the outer surface of the coiled tubing string that is within the application portion and applying the coating to the anchor profile to help adhere the coating to the coiled tubing string.

3. The method of claim 2 , wherein creating the anchor profile comprises blasting the outer surface of the coiled tubing string with an abrasive material to create the anchor profile.

4. The method of claim 2 , wherein creating the anchor profile comprises mechanically displacing material on the outer surface of the coiled tubing string to create the anchor profile.

5. The method of claim 1 , wherein applying the coating comprises:
spraying a first element on the outer surface of the tubing string; and
spraying a second element on the outer surface of the tubing string such that the second element creates a chemical reaction with the first element, thereby curing the first element to the outer surface of the tubing string.

6. The method of claim 1 , wherein applying the coating comprises rolling the coating onto the outer surface of the tubing string such that the coating bonds to the outer surface of the tubing string.

7. The method of claim 1 , wherein applying the coating comprises:
mixing two or more materials to form the coating; and
spraying the coating on the outer surface of the tubing string such that the coating bonds to the outer surface of the tubing string.

8. The method of claim 1 , wherein applying the coating comprises extruding the coating onto the outer surface of the tubing string such that the coating bonds to the outer surface of the tubing string.

9. The method of claim 1 , wherein applying the coating is performed for a time period of up to 30 seconds.

10. The method of claim 1 , further comprising:
heating the coiled tubing string to a first temperature within a range of 350 degrees Fahrenheit to 800 degrees Fahrenheit prior to applying the coating; and
cooling the coiled tubing string to a second temperature within a range of 40 degrees Fahrenheit to 140 degrees Fahrenheit after applying the coating.

11. The method of claim 10 , wherein heating the coiled tubing string to the first temperature is performed for a time period of up to 30 seconds.

12. The method of claim 10 , wherein cooling the coiled tubing string to the second temperature is performed for a time period of up to 10 minutes.

13. The method of claim 1 , further comprising applying a second coating on top of the coating.

14. The method of claim 1 , wherein the coating includes a polymeric material.

15. A method of conducting a coiled tubing operation, comprising:
providing a coiled tubing string, the coiled tubing string having an outer surface and being formed from a metallic material;
selecting an application portion of the coiled tubing string that corresponds to a horizontal section of a particular wellbore and a vertical section of the particular wellbore once the coiled tubing string is positioned in a fully deployed state within the particular wellbore, wherein the application portion does not include axial length of the coiled tubing string corresponding in the fully deployed state to a curved section of the particular wellbore disposed between the horizontal and vertical sections;
applying a coating to the outer surface of the coiled tubing string only along the application portion of the coiled tubing string, wherein the coating has a surface energy lower than a surface energy of the outer surface of the coiled tubing string to thereby reduce friction between the coiled tubing string and a casing disposed in the horizontal section of the particular wellbore; and
lowering the coiled tubing string into the particular wellbore to the fully deployed state such that the coating covers an entirety of the outer surface of the coiled tubing string in the horizontal section of the particular wellbore and all of the coiled tubing string in the vertical section of the particular wellbore, but the coiled tubing string in the curved section of the particular wellbore does not have the coating.

16. The method of claim 15 , wherein the coating comprises polytetrafluroethylene.

Assignees

• Forum Us Inc

Inventors

• Perez Jessica Lorae Olson
• Lux Neal A
• Sheehan Alex Paul
• Galvan Irma Irais
• Mcclelland Garry F
• Rowland Raymond
• Hejducek Stephen Michael

Classifications

• E21B41/00

  Equipment or details not covered by groups E21B15/00 - E21B40/00 · CPC title

• E21B19/22

  Handling reeled pipe or rod units, e.g. flexible drilling pipes {(lifting or hauling appliances using two or more cooperating endless chains B66D3/003)} · CPC title

• E21B19/16

  Connecting or disconnecting pipe couplings or joints (E21B19/20 takes precedence) · CPC title

• B05D1/02

  performed by spraying · CPC title

• C23C24/06

  Compressing powdered coating material, e.g. by milling · CPC title