Pressure activated down hole systems and methods

• US 9,033,056 B2
• Filed: 08/15/2012
• Issued: 05/19/2015
• Est. Priority Date: 08/15/2012
• Status: Active Grant

• Current Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Original Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Inventors: Acosta, Frank, Budler, Nicholas F., Szarka, David D.
• Primary Examiner(s): Harcourt, Brad
• Application Number:
  US13/585,954
• Publication Number:
  US 20140048281A1
• Time in Patent Office: 1,007 Days
• Field of Search: 166/373, 166/381, 166/383, 166/387
• US Class Current: 166/373
• CPC Class Codes: E21B 23/06 for setting packers
• CPC Class Codes: E21B 33/128 with a member expanded radially by axial pressure E21B33/122, E21B33/124 take precedence
• CPC Class Codes: E21B 41/00 Equipment or details not covered by groups E21B15/00 - E21B40/00

Abstract

Systems and methods for activating a down hole tool in a wellbore. A piston is moveable from a first position to a second position for activating the down hole tool. The piston includes a first side exposed to a first chamber, and a second side exposed to a second chamber. A rupture member has a first side exposed to the first chamber and a second side exposed to a third chamber. The rupture member is configured to rupture when a pressure differential between the first chamber and the third chamber reaches a predetermined threshold value, at which point the rupture member allows fluid communication between the first chamber and the third chamber. When the rupture member is intact, the piston is in the first position, and when the rupture member ruptures, the piston moves to the second position and activates the down hole tool.

Claims

1. A system for activating a down hole tool in a wellbore, the system comprising:

a piston moveable from a first position to a second position for activating the down hole tool, the piston including a first piston side exposed to a first chamber, and a second piston side exposed to a second chamber, wherein the first and second chambers are defined at least in part by a retainer element arranged about a base pipe; and

a rupture member having a first member side exposed to the first chamber and a second member side exposed to a third chamber defined by a housing arranged about the base pipe, the rupture member being configured to prevent fluid communication between the first chamber and the third chamber only until a pressure differential between the first chamber and the third chamber reaches a predetermined threshold value, at which point the rupture member ruptures and allows fluid communication between the first chamber and the third chamber,

wherein when the pressure differential is below the threshold value and the rupture member is intact, the piston is in the first position, and wherein when the pressure differential reaches the threshold value and the rupture member ruptures, the piston moves within the first chamber to the second position and activates the down hole tool.

2. The system of claim 1, wherein the piston is axially moveable.

3. The system of claim 1, wherein when the rupture member is intact, the pressure in the first chamber is substantially equal to pressure in the second chamber.

4. The system of claim 1, wherein one of the second chamber and the third chamber is in open fluid communication with a source of variable pressure, and wherein the first chamber and the other of the second chamber and the third chamber are substantially sealed.

5. The system of claim 4, wherein the source of variable pressure is an annulus of the wellbore.

6. The system of claim 5, wherein the system is coupled to the base pipe and is moveable into the wellbore with the base pipe, and wherein as the system is moved deeper into the wellbore, a hydrostatic pressure in the annulus increases, thereby increasing pressure in the second chamber.

7. The system of claim 4, wherein the second chamber is open to the source of variable pressure, and wherein changes in pressure in the second chamber are communicated to the first chamber by way of the piston such that the first chamber and the second chamber remain at substantially the same pressure until the rupture member ruptures.

8. The system of claim 1, wherein the piston is moveable within the first chamber in response to a pressure differential between the first chamber and the second chamber that occurs in response to rupturing of the rupture member.

9. A method for activating a down hole tool in a wellbore, comprising:

advancing the down hole tool into the wellbore to a location in an annulus, the down hole tool being coupled to a base pipe positioned within the wellbore and the base pipe cooperating with an inner surface of the wellbore to define the annulus therebetween;

increasing pressure in the annulus to a pressure above a threshold value, thereby rupturing a rupture member and creating a pressure differential between a first chamber on a first side of a movable piston and a second chamber on a second side of the movable piston, wherein the first and second chambers are defined at least in part by a retainer element arranged about the base pipe;

allowing a fluid to flow from the first chamber into a third chamber upon rupturing the rupture member, the third chamber being defined by a housing arranged about the base pipe, and the rupture member isolating the first and third chambers until the threshold value is reached; and

moving the piston in response to the pressure differential to activate the down hole tool.

10. The method of claim 9, wherein increasing pressure in the annulus further comprises preventing fluid flow past a cup assembly located below the down hole tool.

11. The method of claim 9, wherein rupturing the rupture member further comprises opening a fluid communication path between a hydrostatic chamber and an atmospheric chamber.

12. The method of claim 9, wherein moving the piston further comprises moving the piston axially.

13. The method of claim 9, wherein increasing pressure in the annulus further comprises operating equipment located up hole of the down hole tool.

14. A wellbore system, comprising:

a base pipe moveable along the wellbore, the base pipe including a sleeve assembly defining a first chamber, a second chamber, and a third chamber;

a moveable piston fluidly separating the first chamber and the second chamber;

a down hole tool disposed about the base pipe, the down hole tool operatively coupled to the piston and operable in response to movement of the piston; and

a rupture member fluidly separating the first chamber from the third chamber only until a pressure differential between the first chamber and the third chamber reaches a predetermined threshold value, at which point the rupture member ruptures and allows fluid communication between the first chamber and the third chamber, thereby reducing pressure in the first chamber and causing the piston to move toward the first chamber to operate the down hole tool.

15. The system of claim 14, further comprising a cup assembly coupled to the base pipe and located below the down hole tool, wherein the cup assembly allows fluid flow past the cup assembly in an up hole direction and restricts fluid flow past the cup assembly in a down hole direction.

16. The system of claim 14, wherein the down hole tool is an annular packer, the system further comprising a compression sleeve movably coupled to the base pipe adjacent the annular packer and coupled to a stem portion of the piston, and wherein movement of the piston toward the first chamber compresses the annular packer with the compression sleeve.

17. The system of claim 14, wherein the second chamber is in open fluid communication with an annulus of the wellbore.

18. The system of claim 14, wherein the rupture member is a burst disc.