KOBE SUB WITH INFLOW CONTROL, WELLBORE TUBING STRING AND METHOD

• US 20140151052A1
• Filed: 06/20/2012
• Published: 06/05/2014
• Est. Priority Date: 06/20/2011
• Status: Abandoned Application

• Current Assignee: Packers Plus Energy Services (USA), Inc.
• Original Assignee: Packers Plus Energy Services (USA), Inc.
• Inventors: Themig, Daniel Jon, Coon, Robert Joe
• Application Number:
  US13/883,218
• Publication Number:
  US 20140151052A1
• Time in Patent Office: Days
• US Class Current: 166/308.1
• CPC Class Codes: E21B 17/18 Pipes provided with plural fluid passages E21B17/203 takes precedence
• CPC Class Codes: E21B 29/00 Cutting or destroying pipes, packers, plugs or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground
• CPC Class Codes: E21B 34/063 Valve or closure with destructible element, e.g. frangible disc E21B34/103 takes precedence
• CPC Class Codes: E21B 34/14 operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools E21B34/066 takes precedence
• CPC Class Codes: E21B 43/2605 using gas or liquefied gas
• CPC Class Codes: E21B 43/27 by use of eroding chemicals, e.g. acids

Abstract

A kobe sub includes a kobe installed in a port of the sub, the kobe includes a cap portion accessible in the inner bore, a base mounted in the port and connected to the cap portion, a channel extending through the base and closed by the cap portion; and an inflow controller positioned to control fluid flowing through the channel toward the inner bore when the cap portion is opened; and a port opening tool for opening the cap portion. The kobe may be employed with a frac port.

Claims

1. A kobe sub comprising:

a tubular body connectable into a wellbore tubing string, the tubular body including a wall including an outer surface and an inner surface defining an inner bore and a port through the wall;

a kobe installed in the port with a cap portion accessible in the inner bore, a base mounted in the port and connected to the cap portion, a channel extending through the base and closed by the cap portion; and

an inflow controller positioned to control fluid flowing through the channel toward the inner bore when the cap portion is opened.

2. The kobe sub of claim 1 wherein the inflow controller is selected to filter oversize solids from the fluid flowing.

3. The kobe sub of claim 1 wherein the inflow controller is selected to control flow characteristics of the fluid flowing.

4. The kobe sub of claim 1 wherein the inflow controller is positioned in the channel.

5. The kobe sub of claim 1 wherein the inflow controller is a part of the channel.

6. The kobe sub of claim 1 further comprising a tool sized to move through the inner bore to contact and open the cap portion.

7. The kobe sub of claim 6 wherein the tool is a cutter sleeve installed in the inner bore.

8. The kobe sub of claim 1 further comprising an injection port through the wall and a closure for the injection port moveable between a closed position closing the injection port and an open position retracted from the injection port.

9. A tubing string system for installation in a wellbore comprising:

a tubular body including a tubular wall with an outer surface and an inner surface defining an inner bore and a port through the tubular wall;

a kobe installed in the port with a cap portion accessible in the inner bore, a base mounted in the port and connected to the cap portion, a channel extending through the base and closed by the cap portion; and

an inflow controller positioned to control fluid flowing through the channel toward the inner bore when the cap portion is opened; and

a port opening tool for opening the cap portion.

10. The tubing string system of claim 9 wherein the inflow controller is selected to filter oversize solids from the fluid flowing.

11. The tubing string system of claim 9 wherein the inflow controller is selected to control flow characteristics of the fluid flowing.

12. The tubing string system of claim 9 wherein the inflow controller is positioned in the channel.

13. The tubing string system of claim 9 wherein the inflow controller is a part of the channel.

14. The tubing string system of claim 9 wherein the port opening tool is a cutter sleeve installed in the inner bore.

15. The tubing string system of claim 9 further comprising an injection port through the wall and a closure for the injection port moveable between a closed position closing the injection port and an open position retracted from the injection port.

16. The tubing string system of claim 15 wherein the closure is moveable to the open position without also opening the cap portion.

17. The tubing string system of claim 9 further comprising a first packer positioned uphole from the port and a second packer positioned downhole from the port.

18. The tubing string system of claim 9 further comprising a second stage of the tubing string positioned uphole from the first packer and including a second port through the tubular wall;

a second kobe installed in the second port with a second cap portion accessible in the inner bore, a second base mounted in the second port and connected to the second cap portion, a second channel extending through the second base and closed by the second cap portion; and

a second inflow controller positioned to control fluid flowing through the second channel toward the inner bore when the second cap portion is opened.

19. The tubing string system of claim 18 further comprising in the second stage:

a second injection port through the wall and a second closure for the second injection port moveable between a closed position closing the injection port and an open position retracted from the injection port.

20. A method for forming a fluid channel through a tubing string wall, the method comprising:

installing a tubing string in a wellbore, the tubing string including a tubular wall including an outer surface and an inner surface defining an open inner bore and a port through the wall;

a kobe installed in the port with a cap portion accessible in the inner bore, a base mounted in the port and connected to the cap portion, a channel extending through the base and closed by the cap portion; and

an inflow controller positioned to control fluid flowing through the channel toward the inner bore when the cap portion is opened;

manipulating a port opening tool in the inner bore to open the cap portion and to allow fluid flow through the inflow controller and the channel into the inner bore.

21. The method of claim 20 wherein manipulating includes running a mill through the inner bore.

22. The method of claim 20 wherein manipulating includes running a cutter sleeve through the inner bore.

23. The method of claim 20 wherein manipulating includes running a sleeve shifting tool through the inner bore.

24. The method of claim 20 wherein manipulating also closes an injection port in the tubing string.

25. The method of claim 20 further comprising opening an injection port in the tubing string and injecting wellbore treatment fluid therethrough to treat the formation.

26. The method of claim 20 further comprising pressuring up the string before the manipulating the port opening tool.

27. A method for fluid treatment of a borehole, the method comprising:

running a tubing string into a wellbore to a desired position for treating the wellbore;

opening a frac port by application of a force to a closure for the frac port;

injecting stimulating fluids through the frac port;

closing the frac port;

opening a fluid inflow control port by opening an inner cap over the fluid inflow control port; and

permitting fluid to pass from the wellbore into the tool through the fluid inflow control port.

28. The method of claim 27 wherein opening a fluid inflow control port includes running a mill through the inner bore.

29. The method of claim 27 wherein opening a fluid inflow control port includes running a cutter sleeve through the inner bore.

30. The method of claim 27 wherein opening a fluid inflow control port includes running a sleeve shifting tool through the inner bore.

31. The method of claim 27 wherein opening a fluid inflow control port also closes an injection port in the tubing string.

32. The method of claim 27 further comprising pressuring up the string before opening the frac port.