Sealing a downhole tool

Patent metadata

Field	Value
Publication number	US-10047585-B2
Application number	US-201214433289-A
Country	US
Kind code	B2
Filing date	Oct 5, 2012
Priority date	Oct 5, 2012
Publication date	Aug 14, 2018
Grant date	Aug 14, 2018

Abstract

Techniques for sealing an annulus between a well tool and a tubular include moving the well tool through a wellbore in a run-in position, the well tool including a seal and a sleeve carried on the mandrel, and covering, in the run-in position, an exterior surface of the seal opposite an interior surface of the seal that faces the mandrel; landing the well tool in a tubular that includes a shoulder on an inner surface of the tubular and a seal bore on the inner surface of the tubular, the sleeve adjacent the shoulder upon landing the well tool; and receiving a force that moves a portion of the well tool further downhole to expose at least a part of the seal to the inner surface of the tubular to create a seal between an exterior surface of the well tool and the inner surface of the tubular.

First claim

What is claimed is:

1. A method of sealing an annulus between a well tool and a tubular, comprising:
moving the well tool through a wellbore in a run-in position, the well tool comprising a seal carried on a mandrel and a sleeve carried on the mandrel, and covering, in the run-in position, an exterior surface of the seal opposite an interior surface of the seal that faces the mandrel;
landing the well tool in the tubular that comprises a shoulder on an inner surface of the tubular and a seal bore on the inner surface of the tubular, the sleeve adjacent the shoulder upon landing the well tool; and
receiving a force that moves a portion of the well tool further downhole to expose at least a part of the seal to the inner surface of the tubular to create a seal between an exterior surface of the well tool and the inner surface of the tubular, wherein the sleeve includes:
an opening configured to allow a pin there-through, the pin extendable into a pin bore of the mandrel to thereby couple the sleeve to the mandrel, and
a through-channel configured to surround lateral edges of a dog carried on the mandrel, the dog engageable with an undercut of the tubular to thereby to make the well tool fixable to the tubular.

2. The method of claim 1 , wherein receiving a force that moves a portion of the well tool further downhole comprises:
receiving a force that shears the pin that couples the sleeve to the mandrel; and
receiving a force that urges the dog carried on the mandrel into the undercut on the inner surface of the tubular, the sleeve at a substantially fixed position between the dog and the shoulder.

3. The method of claim 2 , further comprising:
receiving a force that urges the seal from under the sleeve that is at the substantially fixed position.

4. The method of claim 2 , further comprising:
substantially preventing movement of the mandrel in an uphole direction when in the landed position with a slip positioned against the mandrel, the slip comprising a gripping edge directed downhole.

5. The method of claim 4 , further comprising:
receiving a force applied to the mandrel in an uphole direction;
in response to the force, decoupling the sleeve from the mandrel; and
moving the well tool in the uphole direction subsequent to decoupling the sleeve from the mandrel.

6. The method of claim 5 , where decoupling the sleeve from the mandrel comprises receiving a force that shears the pin that couples the sleeve to the slip, the method further comprising:
raising the mandrel in the uphole direction while the sleeve remains abutting the shoulder;
aligning the dog with a profile on the mandrel, the dog retracted from the undercut when aligned with the profile on the mandrel; and
based on the dog retracted from the undercut, receiving a force to raise the seal so that the sleeve covers the exterior surface of the seal.

7. The method of claim 1 , further comprising:
receiving a force to move an expander sleeve that is positioned in an inner bore of the mandrel further downhole;
moving a ramp of the expander sleeve under a portion of a key to urge the key radially toward the inner surface of the tubular; and
locking the key into one or more undercuts on the inner surface of the tubular.

8. The method of claim 1 , further comprising coupling the well tool to one of a tubing or wireline.

9. The method of claim 1 , further comprising receiving a running tool force that prevents a plugging dart disposed within the mandrel from moving in the uphole direction.

10. The method of claim 1 , further comprising moving a plugging dart in the uphole direction.

11. The method of claim 1 , wherein when substantially covered by the sleeve, the seal is adapted to withstand a temperature of about 450° F.

12. A well tool, comprising:
a mandrel that extends through at least a portion of the well tool;
a seal carried on the mandrel that comprises an interior surface that faces the mandrel and an exterior surface opposite the interior surface; and
a sleeve fixed to the mandrel when the tool is in a run-in position and positioned adjacent an outer surface of the mandrel between the exterior surface of the seal and a wellbore and covering the seal, the tool changeable between a first position with the seal covered by the sleeve and a second position with at least a portion of the seal exposed from beneath the sleeve so that the exterior surface of the seal creates a seal in an annulus between the exterior surface of the well tool and an inner surface of a tubular that receives a lower end of the tool when the tool is in the second position wherein the sleeve includes:
an opening configured to allow a pin there-through, the pin extendable into a pin bore of the mandrel to thereby couple the sleeve to the mandrel, and
a through-channel configured to surround lateral edges of a dog carried on the mandrel, the dog engageable with an undercut of the tubular to thereby to make the well tool fixable to the tubular.

13. The well tool of claim 12 , wherein:
when the tool is in the run-in position, the pin is forcibly shearable to permit movement of the tool from the first position to the second position; and
the dog is adjustable to move into the undercut on the inner surface of the tubular in response to forcible shearing of the pin and a force directed on the mandrel in a downhole direction, the dog abutting a shoulder of the undercut to retain the sleeve in a substantially fixed position seated on a shoulder of the inner surface of the tubular in response to the force directed on the mandrel.

14. The well tool of claim 13 , where the tool is configured to move from the first position to the second position in response to the force directed on the mandrel in the downhole direction.

15. The well tool of claim 13 , further comprising:
a slip carried on the mandrel and pinned to the sleeve, the slip comprising a gripping edge directed in a downhole direction that substantially prevents movement of the mandrel in an uphole direction.

16. The well tool of claim 15 , further comprising:
the pin that couples the sleeve to the slip, the pin breakable to release the sleeve from the mandrel in response to a force in an uphole direction, the well tool moveable in the uphole direction subsequent to decoupling the sleeve from the mandrel.

17. The well tool of claim 12 , further comprising:
an expander sleeve positioned in an inner bore of the mandrel, the expander sleeve comprising a ramped outer surface; and
a key carried on the expander sleeve and moveable into a locked position into one or more undercuts of the inner surface of the tubular in response to a downhole force acting on the expander sleeve to move the ramped outer surface under the key.

18. The well tool of claim 12 , wherein when substantially covered by the sleeve, the seal is adapted to withstand a temperature of about 450° F.

19. The well tool of claim 12 , wherein the seal comprises a plurality of V-rings, a male adaptor, a female adapter, and a backup ring.

20. A wellbore flow control system, comprising:
a tubular comprising a nipple and a no-go shoulder; and
a flow control device comprising:
a mandrel;
a seal carried on the mandrel, the seal comprising an inner surface that faces the mandrel and an outer surface opposite the inner surface; and
a sleeve carried on the mandrel, the sleeve disposed between the seal and an inner surface of the tubular with the sleeve adjacent the no-go shoulder, the seal moveable in response to a force acting on the mandrel t

Assignees

• Halliburton Energy Services Inc

Inventors

• Pickle Brad Richard

Classifications

• E21B33/12 Primary

  Packers; Plugs (used for cementing E21B33/134, E21B33/16) · CPC title

• E21B23/06

  for setting packers · CPC title

• E21B33/04 Primary

  Casing heads; Suspending casings or tubings in well heads · CPC title

• E21B33/1208

  characterised by the construction of the sealing or packing means (E21B33/1277 takes precedence) · CPC title

• E21B33/129

  with mechanical slips for hooking into the casing (E21B33/122, E21B33/124 take precedence) · CPC title