Downhole inflow control device with shut-off feature

• US 7,823,645 B2
• Filed: 08/21/2007
• Issued: 11/02/2010
• Est. Priority Date: 07/30/2004
• Status: Expired due to Fees

• Current Assignee: Baker Hughes Incorporated (Baker Hughes Company)
• Original Assignee: Baker Hughes Incorporated (Baker Hughes Company)
• Inventors: Coull, Craig, Henriksen, Knut, Helsengreen, Erik
• Primary Examiner(s): DANG, HOANG C
• Application Number:
  US11/842,688
• Publication Number:
  US 20080035350A1
• Time in Patent Office: 1,169 Days
• Field of Search: 166/313, 166/50
• US Class Current: 166/313
• CPC Class Codes: E21B 34/08 responsive to flow or pressure of the fluid obtained E21B34/10 takes precedence
• CPC Class Codes: E21B 34/10 operated by control fluid supplied from outside the borehole
• CPC Class Codes: E21B 43/12 Methods or apparatus for controlling the flow of the obtained fluid to or in wells E21B43/25 takes precedence; valve arrangements E21B34/00
• CPC Class Codes: E21B 43/14 Obtaining from a multiple-zone well

Abstract

A system and method for controlling inflow of fluid into a production string. In aspects, the invention provides a downhole sand screen and inflow control device with a gas or water shut-off feature that can be operated mechanically or hydraulically from the surface of the well. The device also preferably includes a bypass feature that allows the inflow control device to be closed or bypassed via shifting of a sleeve. In embodiments, the flow control device can be adaptive to changes in wellbore conditions such as chemical make-up, fluid density and temperature. Exemplary adaptive inflow control devices include devices configured to control flow in response to changes in gas/oil ratio, water/oil ratio, fluid density and/or the operating temperature of the inflow control device. In other aspects of the present invention, inflow control devices are utilized to control the flow of commingled fluids drained via two or more wellbores.

Claims

1. A method of selectively controlling fluid flow in a main wellbore drilled in a formation, comprising:

drilling a secondary wellbore adjacent to a main wellbore such that fluid produced from the secondary wellbore commingles with the fluid in the main wellbore, wherein the secondary wellbore does not intersect the main wellbore;

positioning an in-flow control device in a main wellbore; and

controlling the flow of the commingled fluid in the main wellbore with the in-flow control device.

2. The method of claim 1 further comprising positioning a plurality of in-flow control devices along the main wellbore.

3. The method of claim 1 further comprising positioning at least one in-flow control device in the secondary wellbore.

4. The method of claim 1 further comprising configuring the in-flow control device to control flow based on a nature of the commingled fluid.

5. The method of claim 1 further comprising configuring the in-flow control device to control flow based on a water cut of the commingled fluid.

6. The method of claim 1 further comprising configuring the in-flow control device to be sensitive to a density of the commingled fluid.

7. The method of claim 1 wherein the secondary well has a trajectory selected to direct a fluid to the main wellbore.

8. The method of claim 1 further comprising draining a formation using the secondary wellbore.

9. A method of selectively controlling fluid flow in a main wellbore drilled in a formation, comprising:

positioning an in-flow control device in a main wellbore, wherein a secondary wellbore that does not intersect the main wellbore produces a fluid that commingles with the fluid in the main wellbore, the in-flow control device being configured to control the flow of the commingled fluid.

10. The method of claim 9 further comprising positioning a plurality of in-flow control devices along the main wellbore.

11. The method of claim 9 further comprising positioning at least one in-flow control device in the secondary wellbore.

12. The method of claim 9 further comprising configuring the in-flow control device to control flow based on a nature of the commingled fluid.

13. The method of claim 9 further comprising configuring the in-flow control device to control flow based on a water cut of the commingled fluid.

14. The method of claim 9 further comprising configuring the in-flow control device to be sensitive to a density of the commingled fluid.

15. The method of claim 9 wherein the secondary well has a trajectory selected to direct a fluid to the main wellbore.

16. The method of claim 9 further comprising draining a formation using the secondary wellbore.

17. A method of selectively controlling fluid flow in a main wellbore, comprising:

drilling a secondary wellbore that is adjacent to but does not intersect the main wellbore;

producing a fluid from the secondary wellbore that commingles with the fluid in the main wellbore; and

controlling the flow of the commingled fluid in the main wellbore with an in-flow control device.

18. The method of claim 17 wherein the in-flow control device is configured to control flow based on a nature of the commingled fluid.

19. The method of claim 17 wherein the in-flow control device is configured to control flow based on a water cut of the commingled fluid.

20. The method of claim 17 wherein the in-flow control device is configured to be sensitive to a density of the commingled fluid.

21. The method of claim 17 wherein the secondary well has a trajectory selected to direct fluid to the main wellbore.

22. The method of claim 17 further comprising draining a formation using the secondary wellbore.