Method and system for operating a downhole tool, for fracturing a formation and/or for completing a wellbore
View Patent ↗Systems and methods for use in wellbore completion and/or for operating a downhole tool, such as a downhole tool associated with well fracturing, include a tool assembly having a lower packer, an upper packer, a first downhole tool in the form of a flow control device, a second downhole tool in the form of a fracture tool, a plurality of production tools and a plurality of screens. Each tool assembly includes or is associated with a downhole actuator in the form of a shifting tool which is operable to actuate one or more of the first downhole tool, second downhole tool or production tools in use. The actuator may be disposed on, or operatively associated with a string, such as a tubular string. All operations are performed with a body of the shifting tool in tension.
1. A method for operating a downhole tool, the method comprising the steps of:
(a) running an actuator and a downhole tool downhole simultaneously, the downhole tool disposed on tubing, the actuator operatively associated with an inner string located in the tubing, the actuator and the downhole tool being arranged so that, on running the actuator and the downhole tool downhole, the actuator is located downhole from the downhole tool;
(b) pulling the actuator uphole using the inner string operatively associated with the actuator;
(c) engaging the downhole tool with the actuator;
(d) pulling the actuator uphole to perform a first operation of the downhole tool;
(e) changing the configuration of at least one of the downhole tool and the actuator; and
(f) pulling the actuator to perform a second operation of said downhole tool.
2. The method according to claim 1 , comprising:
(g) maintaining at least one of a body of the actuator and the inner string operatively associated the actuator in tension throughout steps (b) to (f).
3. The method according to claim 2 , wherein step (g) includes at least one of:
maintaining a minimum tensile force on the inner string of between 0 lbs (0 N) and 20,000 lbs (990 kN) throughout steps (b) to (f); and
maintaining a minimum tensile force on the inner string of at least 20 lbs (89 N) throughout steps (b) to (f).
4. The method according to claim 2 , including the steps of providing a plurality of downhole tools arranged in series and successively operating the downhole tools by repeating steps (b) to (g).
5. The method according to claim 1 , including the steps of providing a plurality of the downhole tools arranged in series and successively operating the downhole tools by repeating steps (b) to (f).
6. The method according to claim 1 , including pulling the inner string with a predetermined minimum tensile force to perform at least one of the first operation of the downhole tool and the second operation of the downhole tool.
7. The method according to claim 1 , wherein the first operation of step (d) includes at least one of:
moving a first portion of the downhole tool relative to a second portion of the downhole tool;
opening a circulation path downhole;
opening a circulation path downhole and then pumping fracturing fluid downhole and directing fracturing fluid out through at least one port of the downhole tool; and
circulating fluid in an annulus between an inner diameter of the downhole tool and an outer portion of the inner string.
8. The method according to claim 1 , wherein prior to step (e) the method includes locking the actuator and the downhole tool in a configuration in which performance of the second operation is restricted.
9. The method according to claim 1 , wherein changing the configuration of at least one of the downhole tool and the actuator according to step (e) includes at least one of:
circulating fluid downhole to cause a pressure differential across a portion of at least one of the downhole tool and the actuator to thereby change the configuration of the downhole tool and/or the actuator; and
changing the configuration of at least one of the actuator and the downhole tool mechanically.
10. The method according to claim 1 , wherein pulling the actuator to perform the second operation of said downhole tool according to step (f) includes at least one of:
moving a third portion of the downhole tool relative to a fourth portion of the downhole tool; and
closing a fluid flow path in the downhole tool.
11. The method according to claim 1 , comprising step (h), wherein step (h) includes pulling on the inner string and thereby disengaging the actuator from the downhole tool.
12. The method according to claim 1 , including circulating fluid downhole and thereby unlocking the actuator and the downhole tool.
13. The method according to claim 1 , wherein performance of the first operation of the downhole tool by pulling the actuator uphole activates a lock provided on at least one of the downhole tool and the actuator to restrict performance of the second operation of the downhole tool, and wherein changing the configuration of at least one of the actuator and the downhole tool deactivates the lock.
14. A system for operating a downhole tool, the system comprising:
an actuator for coupling to a string, the actuator configured to pass through a downhole tool, wherein the actuator and the downhole tool are configured for running downhole simultaneously such that on running the actuator and the downhole tool downhole the actuator is located downhole from the downhole tool and wherein the actuator is selectively engagable with the downhole tool, such that in an engaged position a predetermined minimum tensile force applied to the actuator is transferred to the downhole tool to perform a first operation of said downhole tool and a second operation of said downhole tool; and
a lock provided on at least one of the downhole tool and the actuator, wherein the lock is operable between an activated configuration in which performance of the second operation of the downhole tool is restricted and a deactivated configuration, wherein the lock is activated on performance of the first operation of the downhole tool and deactivated by changing the configuration of at least one of the actuator and the downhole tool.
15. The system according to claim 14 , wherein at least one of a body of the actuator and the string is arranged to be maintained in tension in use and/or throughout operation of the downhole tool.
16. The system according to claim 14 , wherein at least one of:
the lock is configured to be activated on initial engagement of the actuator and the downhole tool; and
the lock is configured to be deactivated by a pressure differential controllable by circulation of fluid downhole or by mechanically changing the configuration of at least one of the downhole tool and the actuator.
17. The system according to claim 14 , wherein at least one of:
a first portion of the downhole tool is movable relative to a second portion of the downhole tool, the first operation of the downhole tool causing the first portion of the downhole tool to move relative to the second portion of the downhole tool;
the first operation of the downhole tool causes a circulation path to open in the downhole tool;
a third portion of the downhole tool is movable relative to a fourth portion of the downhole tool, the second operation of the downhole tool causing the third portion of the downhole tool to move relative to the fourth portion of the downhole tool; and
the second operation of the downhole tool causes a flow path between a throughbore and an exterior of the downhole tool to close.
18. A method for fracturing a formation including the steps of:
(a) coupling a mechanical shifting tool to an inner string and locating the shifting tool downhole simultaneously with a downhole tool, the downhole tool disposed on tubing, the mechanical shifting tool coupled to the inner string located in the tubing, the mechanical shifting tool and the downhole tool arranged so that, on locating the mechanical shifting tool and the downhole tool downhole, the mechanical shifting tool is located downhole from the downhole tool;
(b) applying a tensile force to the inner string and shifting tool to open at least one fracturing fluid flow path;
(c) pumping fracturing fluid downhole along the fracturing fluid flow path to thereby fracture a formation; and
(d) applying a tensile force to said inner string and the shifting tool to close the fluid flow path.
19. The method according to claim 18 , including maintaining at least one of a body of the mechanical shifting tool and the inner string in tension throughout steps (b) to (d).
20. The method according to claim 18 , including fracturing a formation in a plurality of zones by repeating steps (b)-(d) for successive zones.
21. The method according to claim 18 , including the steps of:
locating an alternative selective circulation path downhole along a tubing;
coupling a second shifting tool to the inner string and locating the second shifting tool downhole from the first shifting tool;
applying a tensile force to the inner string and shifting tools to open the circulation path with the first shifting tool;
flowing fluid along the alternative circulation path; and
applying a tensile force to the inner string and shifting tools to close the alternative circulation path with the second shifting tool.
22. The method according to claim 21 , wherein the alternative circulation path is a reverse circulation path and the step of flowing fluid along the alternative circulation path includes returning at least some fracturing fluid to surface.
23. The method according to claim 18 , including restricting performance of step (d) until fluid is circulated within an annulus between the inner string and a tubing.
24. The method according to claim 18 , wherein performance of the first operation of the downhole tool by pulling the actuator uphole activates a lock provided on at least one of the downhole tool and the actuator to restrict performance of the second operation of the downhole tool, and wherein changing the configuration of at least one of the actuator and the downhole tool deactivates the lock.
25. A downhole completion method, comprising:
deploying a downhole system into a wellbore, wherein the downhole system includes a completion system and an activator tool mounted within the completion system such that the completion system and the activator tool are deployed into the wellbore simultaneously, the completion system disposed on tubing, the activator tool operatively associated with an inner string located in the tubing, the activator tool and the completion system arranged so that, on deploying the activator tool and the completion system downhole, the activator tool is located downhole from at least a portion of the completion system; and
withdrawing the activator tool from the completion system using the inner string operatively associated with the activator tool to operate at least a the portion of the completion system.
26. The method according to claim 25 , comprising maintaining at least one of a body of the activator tool and the inner string operatively associated the activator tool in tension.
27. The method according to claim 25 , wherein performance of the first operation of the downhole tool by pulling the actuator uphole activates a lock provided on at least one of the downhole tool and the actuator to restrict performance of the second operation of the downhole tool, and wherein changing the configuration of at least one of the actuator and the downhole tool deactivates the lock.
28. A downhole completion system, comprising:
a downhole system deployable into a wellbore, wherein the downhole system includes a completion system and an activator tool mounted within the completion system such that the completion system and the activator tool are deployed into the wellbore simultaneously, the completion system disposed on tubing, the activator tool operatively associated with an inner string located in the tubing, the activator tool and completion system arranged so that, on deploying the activator tool and the completion system downhole, the activator tool is located downhole from at least a portion of the completion system,
wherein the activator tool is configured to be withdrawn from the completion system using the inner string operatively associated with the activator tool to operate at least the portion of the completion system.
29. The system of claim 28 , wherein at least one of a body of the activator tool and the inner string operatively associated with the activator tool is arranged to be maintained in tension in use.
30. The system of claim 28 , wherein the activator tool comprises an actuator according to claim 14 .
31. The system of claim 28 , wherein the activator tool is disposed on a tubular inner string.
32. The system of claim 28 , wherein the activator tool comprises at least one of an upper shifter assembly comprising a key moveable between a radially retracted position and a radially extended position and a lower shifter assembly.
33. The system of claim 28 , comprising an indicator, the indicator configured for electromagnetic coupling to an indicator of the downhole tool.
34. The system of claim 28 , comprising a lock assembly.
35. The system of claim 28 , comprising a downhole tool.
36. The system of claim 28 , comprising a plurality of downhole tools.
37. The system according to claim 28 , wherein the downhole tool and the actuator are provided with co-operable engagers for providing the selective engagement between the actuator and the downhole tool.
38. The system according to claim 28 , comprising a lock provided on at least one of the completion system and the activator tool, wherein the lock is operable between an activated configuration in which performance of a second operation of the completion system is restricted and a deactivated configuration, wherein the lock is activated on performance of a first operation of the completion system and deactivated by changing the configuration of at least one of the activator tool and the completion system.
39. A method for operating a downhole tool, the method comprising the steps of:
(a) locating an actuator downhole from a downhole tool;
(b) pulling the actuator uphole;
(c) engaging the downhole tool with the actuator;
(d) pulling the actuator uphole to perform a first operation of the downhole tool;
(e) changing the configuration of at least one of the downhole tool and the actuator; and
(f) pulling the actuator to perform a second operation of said downhole tool,
wherein performance of the first operation of the downhole tool by pulling the actuator uphole activates a lock provided on at least one of the downhole tool and the actuator to restrict performance of the second operation of the downhole tool, and wherein changing the configuration of at least one of the actuator and the downhole tool deactivates the lock.