Tubing hanger with lateral feed-through connection

BACKGROUND OF THE INVENTION

Field of the Invention

The present invention relates to downhole packers. More particularly, the present invention relates to a downhole packer with feed-through connections for communication conduits and a method for pressure testing the connections.

BACKGROUND OF THE RELATED ART

Field of the Invention

Downhole packers are typically used to seal an annular area formed between two co-axially disposed tubulars within a wellbore. For example, downhole packers may seal an annulus formed between production tubing disposed within well bore casing. Alternatively, packers may seal an annulus between the outside of a tubular and an unlined borehole. Routine uses of packers include the protection of casing from pressure, both well and stimulation pressures, as well as the protection of the wellbore casing from corrosive fluids. Other common uses include the isolation of formations or leaks within a well bore casing or multiple producing zones, thereby preventing the migration of fluid between zones. Packers may also be used to hold kill fluids or treating fluids within the casing annulus.

Conventional packers typically comprise a resilient sealing element located between first and second retaining rings. The sealing element is typically a synthetic rubber composite which can be compressed by the retaining rings to expand radially outward into contact with an inner surface of a well casing there-around. The compression and expansion of the sealing element seals the annular area by preventing the flow or passage of fluid across the expanded sealing element.

Conventional packers are typically run into a wellbore within a string of tubulars and anchored in the wellbore using mechanical compression setting tools or fluid pressure devices. Conventional packers are also typically installed using cement or other materials pumped into an inflatable sealing element.

During the production of a well, downhole devices are often controlled or otherwise in communication with above-ground equipment. For example, a control panel above the earth's surface may direct a downhole valve to open or close, a sleeve to shift, or a motor to turn on or off. Data is also collected through the use of downhole devices and transmitted to the surface. For example, data may include pressure readings, temperature readings, flowing velocities, or flow rates. Data sent to and from the surface may be transmitted through a control line such as an electrical wire, fiber optic, or hydraulic conduit.

Control lines connecting the surface equipment and the downhole devices are typically placed in the annulus between the well casing and the production tubing. For devices above a packer this is easily accomplished since the annulus is unobstructed. However, devices below a packer present a challenge since the annulus is sealed off. Packers of the prior art have provided for control lines to pass through the sealing element. One disadvantage associated with running the control lines through element is that the mechanical integrity of the sealing element is compromised. Another disadvantage is that an effective seal between the sealing element and the control lines traversing there-through is difficult to establish and even more difficult to maintain.

Therefore, packers have recently provided for the control lines to pass longitudinally there-through. However, one disadvantage associated with packers of this type is pressure testing each and every connection disposed within the packer. Pressure testing each and every connection consumes valuable time prior to running the packer down the hole. Another disadvantage arises in these packers upon the retrieval of the packer from the well bore. Upon retrieval of the packer from the well bore, the control lines are simply stretched until they break. There is no way to determine how much force is required to break the control lines, and there is no way to determine where the control line will physically break.

Furthermore, retrievable packers typically have a release mechanism disposed within a larger bore of a multi-bore packer because of the weight of the attached tubing string. The cross sectional area of a small bore is simply too small to handle the weight of an attached tubing string. One problem associated with having the release mechanism disposed within the large bore is that the larger bore is often in communication with the production tubing. Often times, the release mechanism becomes jammed or stuck due to an accumulation around the release mechanism of waxy paraffins from within the production fluid, making the packer difficult or near impossible to release.

Therefore, there is a need for a downhole packer having a release mechanism disposed within a small bore that can withstand the weight of the attached tubing string. There is also a need for a packer with internal communication conduits having a cutting mechanism for controllably severing the control lines disposed there-through. There is further a need for a packer having one or more internal communication conduits having one test port to pressure test each connection of the packer thereby saving time and resources prior to running the packer down the hole.

SUMMARY OF THE INVENTION

In one aspect, a packer is provided having a release mechanism disposed within a small bore that can withstand the weight of the attached tubing string. In one aspect, the packer comprises a body having one or more conduits formed there-through; a lock body disposed on a first end of the body; a collapsible member threadably engaged to the body at a first end and shouldered against the lock body at a second end; and a slideable member disposed within the collapsible member. In another aspect, the packer comprises a lock body disposed on a first end of the body, wherein the lock body comprises a recessed groove formed in an inner surface thereof; an expandable ring disposed within the recessed groove, wherein the expandable ring comprises concentric grooves disposed on an inner surface thereof which matably engage concentric grooves disposed about an outer surface of the body; a releasable collar at least partially disposed about the expandable ring; and a slideable sleeve at least partially disposed about the releasable collar.

A packer is also provided with internal communication conduits having a cutting mechanism for controllably severing the control lines disposed therethrough. In one aspect, the packer comprises a body having one or more conduits formed there-through, wherein the one or more conduits comprises an enlarged first end; and a cutting member disposed with the enlarged first end. Movement of the body compresses the cutting member into a control line disposed within the conduit thereby controllably severing the control line.

A packer is further provided with one or more internal communication conduits having one test port to pressure test each connection of the packer thereby saving time and manpower. In one aspect, the packer comprises a body having one or more conduits formed there-through; a chamber disposed within the body, wherein the chamber is in fluid communication with each of the one or more conduits; and an aperture for pressurizing the chamber. Pressurized fluid flows in a first direction through a first conduit to the chamber and flows in a second direction from the fluid chamber through each conduit.

In addition, a method for retrieving a packer from a well bore is provided. In one aspect, the method comprises attaching a retrieval tool to a body, the body comprising one or more conduits formed there-through; a lock body disposed on a first end of the body, wherein the lock body comprises a recessed groove formed in an inner surface thereof; a ring disposed within the recessed groove, wherein the ring comprises concentric grooves disposed on an inner surface thereof which matably engage concentric grooves disposed about an outer surface of the body; a collar at least partially disposed about the ring; and a sleeve at least partially disposed about the collar; moving the sleeve from a first position to a second position using the retrieval tool; releasing the collar; and then expanding the ring. In another aspect, the method comprises attaching a retrieval tool to a body, wherein the body has one or more conduits formed there-through; a lock body disposed on a first end of the body; a collapsible member threadably engaged to the body at a first end and shouldered against the lock body at a second end; and a slideable member disposed within the collapsible member. The retrival tool is used to move the slideable member from a first position to a second position thereby disengaging the collapsible member from the lock body. Movement of the slideable member allows the collapsible member to collapse inwardly and release the packer.

Further, a method of severing a control line in a well bore is provided. The method comprises releasing a body, the body comprising: one or more conduits formed there-through, wherein the one or more conduits comprises an enlarged first end; one or more control lines disposed within the one or more conduits; and a cutting member disposed with the enlarged first end; and compressing the cutting member. The cutting member has a sharp edge disposed thereto that controllably severs the control lines disposed through the conduits.

Still further, a method of pressure testing conduits of a packer is provided. In one aspect, the packer comprises flowing a fluid into a body, wherein the body has one or more conduits formed there-through, wherein the one or more conduits comprises a seal mandrel disposed therein and an annular cavity formed between an outer surface of the seal mandrel and an inner surface of the body; and a chamber disposed within the body, wherein the chamber is in fluid communication with the annular cavities. The chamber acts as a manifold for pressure testing the one or more conduits. The pressurized fluid flows in a first direction through a first annular cavity to the chamber and flows in a second direction from the fluid chamber through each annular cavity.

BRIEF DESCRIPTION OF THE DRAWINGS

So that the manner in which the above recited features, advantages and objects of the present invention are attained and can be understood in detail, a more particular description of the invention, briefly summarized above, may be had by reference to the embodiments thereof which are illustrated in the appended drawings.

It is to be noted, however, that the appended drawings illustrate only typical embodiments of this invention and are therefore not to be considered limiting of its scope, for the invention may admit to other equally effective embodiments.

FIGS. 1A-1D

are a section view of a packer of the present invention shown in a run position.

FIG. 2

is section view along line

2

—

2

of FIG.

1

C.

FIG. 3

is section view along angled lines

3

—

3

of FIG.

2

.

FIGS. 4A-4D

are a section view of the packer of

FIGS. 1A-1D

shown in a set position.

FIGS. 5A-5D

are a section view of the packer of

FIGS. 1A-1D

shown in a released position.

FIG. 6

is a section view of a control line assembly along lines

6

—

6

of FIG.

2

.

FIG. 7

is a section view of a packer of the present invention in a run-in position having a release mechanism disposed within a small diameter bore.

FIG. 8

is a section view along lines

8

—

8

of FIG.

7

.

FIG. 9

is a section view of the packer of

FIG. 7

shown in a released position.

FIG. 10

is a section view along lines

10

—

10

of FIG.

9

.

DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENT

FIGS. 1A-1D

are a section view of a packer

100

of the present invention shown in a run position. The packer

100

includes a body

102

having an engagement assembly, a body lock ring assembly, a retrieval assembly, and one or more control line assemblies disposed thereon. For ease and clarity of description, the packer

100

will be described in more detail below as if disposed within a tubular in a vertical position as oriented in the

FIGS. 1-10

. It is to be understood, however, that the packer

100

may be disposed in any orientation, whether vertical or horizontal. It is also to be understood that the packer

100

may be disposed in a bore hole without a tubular there-around.

Referring to

FIGS. 1A-1D

, the body

102

is a cylindrical member having one or more longitudinal bores formed there-through. As shown, the body includes two longitudinal bores

120

,

130

, for communication with tubing string. The first bore

120

typically has a smaller inner diameter and is known as the “small” bore. The second bore

130

typically has a larger inner diameter and is known as the “large” bore. During operation, the small bore

120

is often used to flow inhibitors, diluents, or other chemicals to a selected zone of a well bore that has been chemically treated, for example. Conversely, the large bore

130

is often connected to, or otherwise in fluid communication, with a production string carrying production fluids from within the well bore.

The body

102

also includes one or more communication conduits

140

formed longitudinally there-through as shown in FIG.

2

. Hydraulic, fiber optic, and/or electrical control lines

160

are often disposed through the conduits

140

to communicate surface equipment with sub-surface equipment. The control lines

160

are sealed within the packer

100

using a control line assembly which is disposed within a lock body

150

. The lock body

150

is disposed on the second end of the body

102

, and is essentially an extension of the body

102

, as shown in FIG.

1

C. Like the body

102

, the lock body

150

includes the bores

120

,

130

, and the one or more communication conduits

140

disposed longitudinally there-through.

Considering the engagement assembly in more detail, the engagement assembly includes a sealing element

210

, first and second gauge rings

212

,

215

, first and second cones

220

,

250

, cylinder

230

, first and second pistons

235

,

240

, and slip

255

, each disposed about the body

102

. The engagement assembly further includes one or more snap rings

263

,

265

,

267

, a first variable volume chamber

270

, and a second variable volume chamber

280

. A first port

275

formed in an outer surface of the body

102

allows for fluid communication between the large bore

130

and the first variable volume chamber

270

, which is adjacent a first end of the first piston

235

and a second end of the second gauge ring

215

. A second port

285

formed in the outer surface of the body

102

allows for fluid communication between the large bore

130

and the second variable volume chamber

280

(shown in FIG.

4

C).

The engagement assembly further includes one or more “dogs”

260

to fix the cylinder

230

to the body

102

. The “dogs” therefore prevent any pre-mature activation or movement of the packer

100

caused by an unavoidable contact against the borehole as the packer

100

is run down into the hole. The “dogs”

260

are housed within apertures formed in the second section of the cylinder

230

, and a recessed groove formed in the outer surface of the body

102

. The first section of the second piston

240

is disposed about the “dogs”

260

to keep the “dogs”

260

within the groove formed about the body

102

. The operation of the dogs

260

, the snap rings

263

,

265

, and

267

and the second chamber

280

, will be discussed below with the operation of the packer

100

.

The slip

255

is disposed about the body

102

between the first cone

220

and the second cone

250

. An outer surface of the slip

255

, preferably includes at least one outwardly extending serration or edged tooth

256

, to engage an inner surface of a tubular

700

disposed there-around (shown in FIGS.

4

A-

4

D). The slip

255

typically includes at least one recessed groove (not shown) milled therein to fracture under stress allowing the slip

255

to expand radially outward to engage the inner surface of the tubular

700

. For example, the slip

255

may include four evenly sloped segments separated by equally spaced recessed grooves to contact the tubular

700

and become evenly distributed about the outer surface of the body

102

.

An inner surface of the slip

255

has a first tapered end and a second tapered end corresponding to tapered surfaces of the first and second cones

220

,

250

. The tapered end of the first cone

220

rests underneath the first tapered end of the slip

255

, and the tapered end of the second cone

250

rests underneath the second tapered surface of the slip

255

. As will be explained in more detail below, the second cone

250

travels toward the first cone

220

which is securely held to the body

102

. As a result, the slip

255

is forced radially outward and over the opposing tapered surfaces of the cones

220

,

250

until the slip

255

engages the inner surface of the tubular

700

.

The element

210

may have any number of configurations to effectively seal the annulus between the body

102

and the inner surface of the tubular

700

. For example, the element

210

may include grooves, ridges, indentations, or extrusions designed to allow the element

210

to conform to variations in the shape of the interior of the tubular

700

. The element

210

can be constructed of any expandable or otherwise malleable material which creates a permanent set position and stabilizes the body

102

relative to the tubular

700

. For example, the element

210

may be a metal, plastic, elastomer, or any combination thereof.

The element

210

is disposed about the body

102

between the first gauge ring

212

and the second gauge ring

215

. The first gauge ring

212

is threadably engaged to an outer surface of the second cone

220

. As a result, the two members move together during the activation and release of the packer

100

which will be described below. The second gauge ring

215

consists of a first section and a second section having different outer diameters. The outer diameter of the first section is greater than the outer diameter of the second section thereby forming an interface or shoulder between the two sections.

The cylinder

230

has a first section and a second section whereby the first section of the cylinder

230

has a greater inner diameter and a greater outer surface than the second section. The first section is disposed about the second section of the second gauge ring

215

and abuts the shoulder formed by the two sections of the second gauge ring

215

. The inner diameter of the second section abuts the outer diameter of the body

102

. Annular grooves are disposed about an outer surface and an inner surface of the second section to house an elastomeric seal or the like to form a fluid barrier within the first chamber

270

formed between the body

102

and the ring housing

410

.

More particularly, the first chamber

270

is formed within the inner diameter of the first section of the cylinder

230

and the outer surface of the body

102

, between the second end of the second gauge ring

215

and a first end of the first piston

235

. The first port

275

is formed through the body

102

to place the bore

130

in fluid communication with the first chamber

270

. The first piston

235

and snap ring

263

are disposed about the body

102

within the chamber

270

. The snap ring

263

prevents axial movement of the first piston

235

in a direction opposite the second gauge ring

215

. Annular grooves are disposed about an outer surface and an inner surface of the first piston

235

to house an elastomeric seal or the like to form a fluid barrier between the cylinder

230

and the body

102

. As will be explained below in more detail, fluid from the bore

130

travels through the port

275

into the chamber

270

and asserts a force against the second gauge ring

215

in a first direction and against the piston

235

in a second direction.

Considering the body lock ring assembly in more detail, the assembly includes a lock ring

410

and a ring housing

420

. The body lock ring

410

is a cylindrical member radially disposed between the ring housing

420

and the lock body

150

. The lock ring

410

includes an inner surface having profiles disposed thereon to mate with profiles formed on the outer surface of the lock body

150

. A longitudinal cut within the lock ring

410

allows the lock ring

410

to expand radially and contract as it movably slides or ratchets in relation to the outer surface of the lock body

150

.

The ring housing

420

is radially disposed about the cylinder

230

at a first end and the body lock ring

410

at a second end. At the first end, the ring housing

420

abuts the shoulder formed in the outer surface of the cylinder

230

and is threadably engaged to the second section of the cylinder

230

. At the second end, the ring housing

420

has a jagged inner surface to engage a mating jagged outer surface of the lock ring

410

. The relationship between the jagged surfaces creates a gap there-between allowing the lock ring

410

to expand radially as the profiles formed thereon move across mating profiles formed on the lock body

150

. The profiles formed on the lock ring

410

have a tapered leading edge allowing the lock ring

410

to move across the mating profiles formed on the lock body

150

in one axial direction while preventing movement in the other direction.

In particular, the profiles formed on both the outer surface of the lock body

150

and the inner surface of the lock ring

410

consist of formations having one side which is sloped and one side which is perpendicular to the outer surface of the lock body

150

. The sloped surfaces of the mating profiles allows the lock ring

410

to move across the body

102

in a single axial direction, whereas the perpendicular sides of the mating profiles prevent movement in the opposite axial direction. Therefore, the lock ring

410

may move or “ratchet” in one axial direction, but not the opposite axial direction.

The second chamber

280

is formed within the inner diameter of the ring housing

420

and the outer surface of the body

102

, between the second end of the cylinder

230

and a first end of the lock body

150

. The second port

285

formed in an outer surface of the body

102

provides for fluid communication between the bore

130

and the chamber

280

.

The second piston

240

and snap rings

265

and

267

are disposed about the body

102

within the chamber

280

. The second piston

240

is an annular member disposed about the body

102

adjacent the second end of the second gauge ring

215

and the lock body

150

. The second piston

240

has a first section and a second section, whereby the first section has a greater inner diameter than the second section. The first section is disposed about an annular channel formed in the outer surface of the second section cylinder

230

. The second section is disposed directly about the body

102

. Annular grooves are disposed about an outer surface and an inner surface of the second section to house an elastomeric seal or the like to form a fluid barrier between the ratchet housing

420

and the body

102

. As will be explained below in more detail, fluid from the bore

130

travels through the port

285

into the chamber

280

and asserts a force against the cylinder

230

in a first direction and against the piston

240

in a second direction. Within the chamber

280

, the snap ring

265

prevents the axial movement of the piston

240

in a direction opposite the lock body

150

, while the snap ring

267

prevents axial movement of the piston

240

in a direction opposite the cylinder

230

.

Considering the retrieval assembly in more detail, the retrieval assembly includes a collet

510

and a support sleeve

520

. The collet

510

is an annular, cylindrical member having a first section and a second section. The first section is a solid member which is threadably engaged to the body

102

. The second section includes a plurality of collapsible members or fingers which are shouldered out against an inner surface of the lock body

150

. The lock body

150

, therefore, is held to the body

102

through the fingers of the collet

510

.

The support sleeve

520

is an annular member disposed about the inner surface of second section of the collect release

510

. The support sleeve

520

is affixed to the collet

510

through one or more shearable members

530

, such as shear pins, for example. The removal of the support sleeve

520

allows the fingers of the collet

510

to collapse and thereby release the lock body

150

. As will be described below, upon the collapse of the fingers, the fingers will disengage from the inner surface of the lock body

150

and allow the lock body

150

to travel away from the body

102

, which thereby activates a cutting mechanism that severs the control line disposed there-through.

Referring to

FIGS. 2 and 3

, each conduit

140

of the lock body

150

contains a control line assembly to sever the control lines

160

running through the respective conduit

140

. Each control line assembly includes a seal sleeve

302

, a wedge housing

305

, one or more cutting wedges

310

, and a ferrule fitting

320

. The seal sleeve

302

is an annular, cylindrical member having a first end that is threadably engaged to the body

102

. A first end of the wedge housing

305

is threadably engaged to a second end of the seal sleeve

302

. A second end of the wedge housing

305

is a hexagonal head

307

or a comparable configuration, which is connectable to a tool, not shown, for operating the ferrule

320

. The wedge housing

305

also has a plurality of apertures formed axially therein to be used in conjunction with the cutting wedges

310

.

The cutting wedges

310

are disposed about the wedge housing

305

and housed within a flared second end of each conduit

140

. The cutting wedges

310

are aligned with the apertures formed in the wedge housing

305

, and when activated, the flared second end of the conduit

140

travels over the cutting wedges

310

, forcing the cutting wedges

310

radially inward toward the control line

160

. Accordingly, the cutting wedges

310

are forced into the apertures, thereby severing the control line

160

.

As shown in

FIG. 3

, an annulus

399

is formed between an outer surface of each seal sleeve

302

and an inner surface of each communication conduit

140

. A fluid chamber

350

is also formed between the interface of the body

102

and the lock body

150

such that each annulus

399

is in fluid communication with the fluid chamber

350

. The fluid chamber

350

, therefore, acts a manifold providing fluid communication between each annulus

399

for transferring fluid from one annulus

399

to another.

A test port

360

is disposed on the lock body

150

and is used to simultaneously pressure test each control line assembly disposed in the packer

100

. The test port

360

is in fluid communication with a first annulus

399

formed about a first seal sleeve

302

. A test fluid, preferably a liquid, is introduced through the test port

360

to the first annulus

399

. The test fluid travels within the first annulus

399

to the fluid chamber

350

. From the fluid chamber

350

, the fluid travels via each annulus

399

to the test holes

330

disposed on the ferrule fittings

320

. Accordingly, each ferrule fitting

320

can be pressure tested simultaneously to ensure a proper fluid seal within each conduit.

FIGS. 4A-4D

are a section view of the packer

100

shown in a set position within a tubular

700

. To set or actuate the packer

100

, the packer

100

is first attached within a string of tubulars (not shown) and control lines (not shown), and run down a wellbore to a desired location. Fluid pressure within the bore

130

is supplied to the first and second chambers

270

,

280

, through their respective ports

275

,

285

. The fluid pressure within the chambers

270

,

280

, is substantially equal to the pressure within the bore

130

.

Within the second chamber

280

, the fluid pressure forces the second piston

240

in a second direction toward the snap ring

267

. The second piston

240

transfers force through the snap ring

267

to the body

102

which transfers the force into the lock body

150

. Since the ratchet housing

420

is threadably engaged to the cylinder

230

, the lock body

150

moves relative to the body lock ring assembly which causes the lock ring

410

to ratchet across the lock body

150

in the first direction. Movement of the second piston

240

also uncovers the “dogs”

260

which disconnects the cylinder

230

from the body

102

. Consequently, the fluid pressure moves the cylinder

230

in a first direction toward the engagement assembly.

Within the first chamber

270

, the fluid pressure moves the first piston

235

in the second direction against the snap ring

263

. The snap ring

263

transfers the force to the body

102

. In the first direction, the fluid pressure exerts a force against the second gauge ring

215

, moving the ring

215

toward the engagement assembly. Since the second gauge ring

215

and the cylinder

230

are threadably engaged as well as shouldered out, the two members

215

,

230

move in the first direction together. Moreover, since the two members

215

,

230

are tied together, the sum of the forces within the volumes of the first chamber

270

and the second chamber

280

is asserted against the members

215

,

230

in the first direction. Accordingly, the volumes of the respective chambers

270

,

280

can be smaller than if they were to operate individually.

Continuing in the first direction, the cylinder

230

and second gauge ring

215

transfer the force through the sealing element

210

to the first gauge ring

212

, which is threaded to the second cone

250

. The first cone

220

is held securely to the body

102

, thereby exerting an equal and opposite force against the members moving in the first direction. Accordingly, the second cone

250

moves underneath the slip

255

, driving the slip

255

up an over the tapered surfaces of the first cone

220

and the second cone

250

, and radially outward toward the tubular

700

, as shown in

FIGS. 4A and 4B

. At the same time, the first and second gauge rings

212

,

215

, longitudinally compress and radially expand the element

210

toward the tubular

700

, as shown in FIG.

4

B.

To retrieve the packer

100

and controllably sever the control lines

160

, a retrieval tool, not shown, is attached to the support sleeve

520

. The tool applies a force in the first direction to the support sleeve

520

to shear the shearable members

530

holding the support sleeve

520

to the collet

510

. Referring to

FIGS. 5A-5D

, once the shearable members

530

release, the support sleeve

520

travels axially in the first direction along the collet

510

from a first position to a second position. The release of the support sleeve

520

allows the fingers of the collet

510

to collapse radially inward, thereby disengaging the lock body

150

from the collet

510

. Consequently, the lock body

150

is free to move independently of the body

102

in the second direction by the weight of the tubing string attached thereto.

As the lock body

150

moves in the second direction away from the body

102

, the body lock ring assembly ratchets in the first direction across the lock body

150

until the lock ring

410

contacts the shoulder formed in the outer surface of the first end of the lock body

150

. At this point, the body lock ring assembly now moves with the lock body

150

. Since the lock ring housing

420

is threadably engaged to the cylinder

230

which is threadably engaged to the second gauge ring

215

, the slip

255

and the element

210

are allowed to relax and move radially inward away from the tubular

700

, thereby disengaging the packer

100

from the wellbore.

In addition, movement of the lock body

150

away from the body

102

activates the control line assemblies which controllably sever the control lines

160

as shown in FIG.

6

. In particular, movement of the lock body

150

in the second direction, opposite the body

102

, causes the wedges

310

to travel up the slope of the tapered second end of the conduits

140

thereby forcing the wedges

310

into the apertures of the wedge housing

305

. Consequently, the sharp surfaces of the wedges contact the control lines

160

and sever the control lines

160

at the point of contact.

In addition to the packer

100

described above,

FIG. 7

is a section view of a packer

200

shown in a run position having a release mechanism disposed in the first bore

120

. Due to the physical properties of the production fluid, a release mechanism in the production tubing may become unreliable. For example, paraffins in the production fluid have a tendency to accumulate and collect on the release mechanism and thereby effectively prevent the operation of the mechanism. Therefore, it is desirable to have the release mechanism disposed within the non-production bore

120

, as shown in

FIGS. 7-10

.

The packer

200

includes an engagement assembly, one or more control line assemblies, a body lock ring assembly, and a retrieval assembly. The engagement assembly, body lock ring assembly, and control line assembly are similar to those described above for the packer

100

, and therefore, utilize the same numeric identification. The different retrieval assembly of the packer

200

includes a support sleeve

600

, a containment ring

610

, a stopper

620

, and a release sleeve

630

.

The support sleeve

600

is disposed within the second bore

130

, and connects the lock body

150

to the body

102

. The support sleeve

600

is a cylindrical member and is threadably engaged to the second bore

130

at a first end thereof. At a second end, the support sleeve

600

has a plurality of concentric grooves formed in an outer surface thereof to engage mating concentric grooves formed in an inner surface of the containment ring

610

.

The containment ring

610

is a split-ring disposed about the second end of the support sleeve

600

, and is disposed within a window formed in an inner surface of the lock body

150

. As stated above, the containment ring

610

has a plurality of concentric grooves formed in an inner surface thereof to matably engage the grooves of the support sleeve

600

. The containment ring

610

also has at least two axially recessed grooves

612

,

614

, formed in an outer surface thereof, as shown in FIG.

8

.

Referring to

FIGS. 7 and 8

, the stopper

620

is disposed about the containment ring

610

and has one or more legs

625

extending from an inner surface thereof that are disposed within the recessed grooves

612

,

614

, of the containment ring

610

. The legs

625

prevent the containment ring

610

from splitting open until retrieval of the packer

200

is desired.

The release sleeve

630

is disposed within the first bore

120

and covers an outer surface of the stopper

620

. The release sleeve

630

holds the stopper

620

against the containment ring

610

. A first end of the release sleeve

630

is attached to the body

102

through a shearable member

635

, such as a shear pins, for example. Upon the release of the release sleeve

630

, the stopper

620

is uncovered and allowed to disengage from the containment ring

610

as shown in

FIGS. 9 and 10

. Once the stopper

620

is released, the containment ring

610

expands open, disengaging its concentric grooves from the concentric grooves formed in the support sleeve

600

. The lock body

150

is therefore released from the body

102

. As described above, axial movement of the lock body

150

in the second direction, away from the body

102

, activates the cutting mechanisms disposed within the control line assemblies, and also disengages the slip

255

and element

210

from the tubular

700

there-around.

The aspects of the invention described herein are not limited to uses in a packer and could have similar uses in any wellbore component. Furthermore, while foregoing is directed to the preferred embodiment of the present invention, other and further embodiments of the invention may be devised without departing from the basic scope thereof, and the scope thereof is determined by the claims that follow.