Wellhead rotating breech lock and method

A rotating breech lock rotates tubing to distribute wear caused by a rotating or reciprocating rod of an artificial lift system. The rotating breech lock has a spool that disposes on a wellhead. A bowl element disposes in the spool's bore, and a hanger fits into the spool and lands on the bowl element with a thrust bearing. Above the hanger, a load ring fits against the hanger with a bearing, and a hold-down sleeve and locking pins hold the load ring against the hanger. The spool has a worm that mates with a wheel defined about the hanger so turning the worm by a ratchet or other mechanism rotates the hanger. Internally, the hanger has a bore with opposing shoulders separated by gaps. A mandrel couples to the tubing and disposes up into the hanger. Protrusions or keys on the hanger can selectively align with the gaps and the shoulders depending on how the mandrel is rotated in the hanger bore.

BACKGROUND

Tubing hangers support tubing for wellheads in a number of applications. In general, most tubing hangers land in a tubing spool of the wellhead and support the weight of tubing that extends down the wellbore from the wellhead. One particular example of a tubing hanger is Weatherford's breech-lock tubing hanger system. This system has a false bowl and a hanger mandrel that land together in a tubing spool. Anchor screws retain the false bowl, while the hanger mandrel can be disengaged from the false bowl by lifting the mandrel in the false bowl with a landing joint and rotating the mandrel a quarter turn. In this orientation, the mandrel can be passed through the false bowl and can be run downhole. The mandrel can be reengaged in the false bowl with a reverse of these steps for placing tubing in tension.

Tubing hangers are also used for artificial lift systems. For example, a jack pump, a progressive cavity pump unit, or other device for an artificial lift system rotates or reciprocates a rod at a producing well. The rod operates downhole components of the artificial lift system to produce fluids from the wellbore. Because the moving rod passes through the wellhead and through tubing, the movement of the rod can cause excessive wear on internal portions of the tubing during operation. Additionally, the wellbore's deviation and the constituents of the produced fluids can increase the wear of the tubing. Eventually, the unevenly worn tubing can cause equipment failures so that it must be removed and replaced.

Tubing rotators are a type of tubing hanger that install on wellheads to deal with wear on the tubing by moving rods. Tubing swivels and tubing anchor catcher swivels have also been used in conjunction with tubing rotators. In general, the tubing rotator rotates the tubing within the wellbore so wear from the reciprocating or rotating rod can be more evenly distributed around the inside of the tubing. The rotation can also inhibit or reduce the buildup of paraffin or wax in the tubing.

Commercial examples of tubing rotators include the Rodec Tubing Rotator Systems available from R&M Energy Systems of Willis, Tex. Commercial examples of prior art tubing swivels include the Rodec Slimeline Tubing Swivel and Rodec AC Anchor Catcher Swivel available from R&M Energy Systems of Willis, Tex. Examples of some prior art tubing rotators and swivels are disclosed in U.S. Pat. Nos. 2,599,039; 2,471,198; 2,595,434; 2,630,181; 5,139,090; 5,327,975; and 5,427,178; and 6,834,717.

Attempts in the prior art to put tubing to be rotated under tension while using a tubing rotator have focused on aspects of the tubing anchor or swivel as disclosed in U.S. Pat. Nos. 5,139,090; 5,327,975; and 6,834,717, for example. Yet, there are limitations to current methods of setting tubing to be rotated by a “rotating tubing hanger” in tension while a blowout preventer (BOP) is installed on the well for complete well control. For example, when a rotating tubing hanger is to be used, operators run a tubing anchor in-the-hole on the bottom of the tubing string. The tubing is then spaced out to accommodate the rotating tubing hanger assembly, and operators set the anchor. With the anchor set, the tubing is stretched above the BOP (when applicable), which allows the rotating tubing hanger assembly to be installed on the tubing string. Once installed, the entire string is lowered through the BOP and landed in the wellhead. Performing these steps can be limited by the amount of stretch that can be applied to the tubing string so that this procedure may not work with some implementations.

Although existing tubing rotators and systems may be effective, what is needed is a way to rotate tubing that allows operators to pull tension on the tubing to be rotated during operation in a straightforward manner, especially when a blowout preventer (BOP) is installed on the well.

SUMMARY

A wellhead rotating breech lock rotates tubing to distribute wear evenly around the inside of the tubing caused by a rotating or reciprocating rod of an artificial lift system, for example. The rotating breech lock has a tubing spool that disposes on the wellhead. A hanger assembly has a bowl element that disposes in the spool's bore on a spool landing, and the bowl element supports a breech lock hanger in the spool with a thrust bearing. Above the hanger, a load ring fits against the hanger with a thrust bearing, and an adapter held in the spool with locking pins holds the load ring against the hanger.

The spool has a rotatable drive exposed in the spool's bore. The drive includes a worm that mates with a wheel defined around the outside of the breech lock hanger. Turning of the worm by a ratchet or other mechanism rotates the hanger. Internally, the hanger has a bore with opposing shoulders separated by gaps for selectively landing a mandrel.

The mandrel couples to tubing that disposes down the borehole from the wellhead. To engage the mandrel in the breech lock hanger, the mandrel disposes up into the hanger's bore, and landings on the mandrel can selectively land on the opposing shoulders in the hanger's bore. Therefore, to hold the mandrel in the hanger so it can turn with the hanger, the mandrel's landings can selectively align with the bore's shoulders when the mandrel is rotated in one orientation in the hanger bore. To insert or remove the mandrel from the hanger, the landings can selectively align with the gaps between shoulders when the mandrel is rotated in an offset orientation in the hanger bore.

The ability to engage and disengage the mandrel from the hanger with the landings and shoulders allows the mandrel and attached tubing to be keyed out of the hanger and run downhole to set downhole components, such as an anchor/packer assembly. With a downhole component set, the mandrel can be pulled back up into the hanger and keyed into a locked condition in the hanger so the mandrel and attached tubing can then rotate with the hanger during operation. In this way, tension can remain drawn on the tubing while the rotating breech lock subsequently rotates it during operation.

DETAILED DESCRIPTION

As shown inFIG. 1A, a pump jack20reciprocates a sucker rod14though a wellhead assembly30of a borehole. Although shown with the pump jack20, any suitable pumping unit can be used, such as a StrapJack® pumping unit, Rotaflex® pumping unit, or other type of pumping unit. (STRAP JACK and ROTAFLEX are registered trademarks of Weatherford/Lamb, Inc.) The wellhead assembly30has a wellhead or casing head32supporting casing10in the borehole. Typically, the wellhead32has a casing hanger (not shown) disposed therein that supports the casing10, which is cemented in the borehole. Below the wellhead assembly30, tubing12disposed in the casing10has the sucker rod14disposed therein. Above the wellhead32, the assembly30has a stuffing box34and piping36for collecting production fluid.

The sucker rod14extending downhole can have several sections of rod (not shown) interconnected by rod couplings (not shown). At its downhole end, the sucker rod14connects to a downhole plunger and barrel arrangement (not shown) in a producing zone of the borehole. At the surface, however, the sucker rod14couples to a polished rod16that passes through the wellhead assembly30and seals through the stuffing box34. The upper end of the rod16then couples to the pump jack20.

As the pump jack20operates, the sucker rod14and polished rod16reciprocate through the wellhead assembly30and tubing12to operate the downhole pump and bring production fluid to the surface. As noted previously, the reciprocating rod14can cause excessive and uneven wear inside the tubing12. By rotating the tubing12while the pump jack20is operating, the inside surface of the tubing12can be worn evenly, which extends the tubing's life.

To achieve this rotation, the wellhead assembly30includes a rotating breech lock100according to the present disclosure. The rotating breech lock100installs above the wellhead32and supports the tubing12in the borehole. As the pump jack20operates, an interconnecting chain22pulls a lever102of a ratchet or similar mechanism coupled to the rotating breech lock100. With the cyclical motion of the pump jack20, the rotating breech lock100can then rotate the tubing12by some defined amount (e.g., several degrees). In this way, wear inside the tubing12caused by the reciprocating rod14can be more evenly distributed around the tubing's internal circumference. In addition to rotating the tubing12, the rotating breech lock100of the present disclosure allows the tubing12to be pulled in tension as described in more detail later.

InFIG. 1B, another implementation has the disclosed rotating breech lock100for rotating tubing12extending from a wellhead assembly40. In this arrangement, the wellhead assembly40has a wellhead42disposed above casing10. The rotating breech lock100disposes on the wellhead42and supports the tubing12in the borehole. Above the rotating breech lock100, the wellhead assembly40has a stuffing box45, a motor46, and other components of a progressive cavity pump drive44.

Here, the rod14rotates by the drive44at the wellhead assembly40and rotates a rotor in a stator of a downhole progressive cavity pump48deployed downhole. To rotate the rod14, a polished rod16at the surface passes through the stuffing box45. The motor46attached by a gear assembly47rotates the rods14/16to operate the downhole pump48.

As the motor46operates, the rod14rotates in the tubing12, which can cause excessive and uneven wear inside the tubing12. By rotating the tubing12with the rotating breech lock100while the motor46is operating, the inside surface of the tubing12can be worn evenly, which extends its life. To achieve this rotation, a flexible drive cable105extends from an upper gear box107to another gear box104. As the polished rod16turns, the flexible drive cable105transfers the rotation of the rod16from the one gear box107to the other gear box104, which is coupled to the rotating breech lock100. With the rotation of the rod16, the rotating breech lock100can then rotate the tubing12so that the sucker rod14extending through the tubing12causes more even wear inside.

As opposed to the above mechanisms for mechanically activating the rotating breech lock100, another implementation shown inFIG. 1Ccan use an electrically controlled drive106coupled to the rotating breech lock100on a plunger lift system50. During operation, the controlled drive106activates the rotating breech lock100to rotate the tubing12to distribute wear. This drive106can be electrical, hydraulic, or pneumatic and can have control circuitry and other necessary components.

As also shown inFIG. 1C, the disclosed rotating breech lock100can be used in applications other than those involving a rotating or reciprocating rod. As shown here, the disclosed rotating breech lock100is used with a plunger lift system50in which a plunger56travels uphole and downhole through tubing12in a borehole casing10. At the surface, a lubricator54has a bumper, catcher, piping and other components for the plunger56. A sensor108, such as a proximity sensor or the like, can detect or count the plunger56when it arrives at the lubricator54, and the drive106can use the sensed detection to operate the rotating breech lock100to rotate the supported tubing12. Again, the ability to rotate the tubing12with the rotating breech lock100in this type of system can also reduce wear caused by the repeated passage of the plunger56.

For even distribution of wear, the tubing12inFIGS. 1A-1Cis preferably turned automatically on a continuous basis. As indicated above, the rotating breech lock100can be activated in a number of ways including movement by a pump jack, a flexible drive cable, an electronically controlled drive, hydraulic pressure, etc. As will be appreciated with the benefit of this disclosure, these and other mechanisms can be used to actuate the rotating breech lock100. Moreover, the rotating breech lock100can be used with systems having reciprocating rod, rotating rod, a plunger lift, and other systems in applications where rotating tubing can be advantageous.

With an understanding of how the disclosed rotating breech lock100is used, discussion now turns to a more detailed description of the rotating breech lock's components and operation.FIG. 2Ashows portions of the rotating breech lock100in a cutaway perspective, andFIG. 2Bshows portions of the rotating breech lock100in cross-section. The rotating breech lock100includes a tubing spool110and a hanger assembly120. The tubing spool110has a drive150, and the hanger assembly120has an intermediate bowl130, a rotating breech hanger140, a load ring160, a load ring adapter170, and a mandrel180.

As shown, the intermediate bowl130lands in the spool's bore112against a lower landing114, and the bowl130has a number of external seals to seal in the bore112. The rotating breech hanger140has a bearing shoulder148athat lands on the bowl's bearing shoulder135with a thrust bearing137disposed therebetween. Portion of the rotating breech hanger140seals inside the bore132of the intermediate bowl130. The thrust bearing137can use roller bearings or other types of bearings, and lubrication ports115acan be provided in the spool110for lubricating the bearing137. The intermediate bowl130affixes to the rotating breech hanger140with a snap ring, spiral lock, or the type of retainer179, and the bowl130has ports for delivering lubrication to the bearing137.

Shown in isolated detail inFIGS. 3A-3C, for example, the tubing spool110defines a lubrication port115aand an annular groove arrangement to bring lubricant into the spool's bore112. Another lubrication port115bcommunicates with the side hole118for the worm drive (150). Shown in detail inFIGS. 4A-4B, the intermediate bowl130has inner slots133and outer slots134for O-rings and defines side ports139for communicating lubrication.

Returning toFIGS. 2A-2B, the load ring160lands on an upper shoulder148bof the rotating breech hanger140with a thrust bearing167and seals against the spool's bore112and the breech hanger140with O-ring seals. Again, the thrust bearing167can use roller bearings or other types of bearings, and lubrication can be provided to the bearing167via the lubricator port (115b) of the spool (110) for the drive (150) or some other pathway.

Shown in detail inFIGS. 8A-8B, for example, the load ring160has a load bearing shoulder165for fitting against the thrust bearing (167). In addition, the load ring160has a slot163in the bore162for an O-ring seal (not shown). At its upper end, the ring160has thread holes166to receive ends of bolts (not shown) for attaching the load ring160to the load ring adapter (170) as discussed below.

As shown inFIG. 2B, the load ring adapter170fits above the load ring160and can be held by lock pins119installing in pin holes117in the spool's upper flange. A snap ring177fits between the adapter170and the load ring160, and the snap ring177engages a top groove on the rotating breech hanger140to couple these components together. In this way, the adapter170, the load ring160, the rotating breech hanger140, and the intermediate bowl130can all be lowered into the spool110as a unit and landed on the spool's shoulder114. Shown in detail inFIGS. 9A-9B, the adapter170has holes176for passage of the bolts (not shown) used to attach the adapter170to the load ring (160).

Finally, as shown inFIGS. 2A-2B, the mandrel180is shown installed in the rotating breech hanger140, where it can be selectively landed. The upper end of the mandrel180can seal inside the breech's bore142. The mandrel180as discussed below installs into the breech's bore142from the lower end, and the bore142of the breech hanger140prevents upward passage of the mandrel180.

With an understanding of the arrangement of components for the disclosed rotating breech lock100and how they install together, discussion now turns to more details related to the rotating breech hanger140, the drive150, and the mandrel180.

As shown inFIGS. 5A-5D, the bore142of the rotating breech hanger140has a widened area144, and the bore142has lands146separated by slot gaps147defined in the lower end thereof. The bore's widened area144accommodates portions of the mandrel (180) when disposed therein, and the lands146and gaps147enable the mandrel (180) to selectively land in (or pass out of) the hanger's bore142depending on how the mandrel (180) is oriented.

As best shown inFIG. 5C, grooves143at the upper end hold O-ring seals (not shown) for engaging the mandrel (180) when disposed in the bore142. Holes149bdefined through the breech hanger140communicate with the bore142at the lands146. These holes149breceive pins149afor engaging the mandrel (180) as described below. As best shown inFIGS. 5A-5B, an increased outer diameter of the breech hanger140defines a worm wheel145thereabout, which is used for turning the hanger140as discussed below.

As noted previously with reference toFIGS. 2A-2B, the rotating breech hanger140lands inside the spool110equipped with the drive150, and the mandrel180coupled to the downhole tubing fits up into the bore142of the breech hanger140. As the rod cycles up and down or rotates, for example, the motion cycles the rotation of the breech hanger140via the drive150. The rotation of the breech hanger140in turn rotates the tubing attached to the mandrel180and reduces wear inside the tubing to increase the tubing's life.

Various types of drive mechanisms can be used for the drive150that rotates the hanger140in the spool's bore112. For example, the drive150can use any of a number of gear arrangements known in the art. As shown more particularly inFIG. 6, the drive150has a shaft152with thread of a worm158disposed thereabout. The shaft's distal end154fits into the inner pocket of the spool's side hole (118;FIG. 3C), while the shaft's proximal end156protrudes therefrom for threading to other components, such as handle, motor, lever, ratchet, or the like, used to rotate the worm158. A rim155between the worm158and the proximal end156holds a seal for sealing in the spool's side hole (118).

The worm158of the drive150meshes with the wheel145defined about the breech hanger140ofFIGS. 5A-5B. The worm158and wheel145allow the breech hanger140to drift into place in the tubing spool (110) with sufficient clearance while the worm158and wheel145mesh during assembly. The meshing preferably avoids any attempt of the components' teeth to chew against one another. To accomplish this, the profile on the wheel145as shown inFIGS. 5A-5Bpreferably has a curved side profile and has inlet fillets to ease the gear around the elements of the worm158as the wheel145drifts into place.

As noted previously with reference toFIGS. 2A-2B, the mandrel180fits up into the bore142of the hanger140. In particular, the mandrel180shown in detail inFIGS. 7A-7Dhas landings190on opposing sides of the mandrel's outside surface. Each of these landings190defines a key slot192. Inside, the mandrel's bore182has threads184a-bfor coupling to tubing (not shown) as described below.

As will be evident later, the rotating breech hanger (140;FIGS. 5A-5D) can rotate the mandrel180and tubing when the mandrel180is installed in a seated orientation inside the rotating breech hanger (140). When installed in this seated orientation within the breech hanger (140;FIG. 5C), for example, the landings190on the mandrel180can land on the landing shoulders (146) inside the hanger's bore (142). In this position, the key slots192can align with the side holes (149b) in the breech hanger140. The pins (149a) in the side holes (149b) can then engage in the mandrel's key slots192to lock rotation of the mandrel180and breech hanger (140) together. These pins (149a) can be held with an interference fit in the holes (149b) or by other means.

When the mandrel180is lifted and rotated to an offset orientation situated 90-degrees from its seated orientation, the mandrel's landings190can pass along the slots (147) on the inside of the bore (142) of the breech hanger (140;FIG. 5C). With this orientation, the mandrel180can pass out of and draw into the breech hanger (140). Being able to move the mandrel180in and out of the rotating breech hanger (140) allows tubing attached to the mandrel180to be drawn up into the breech hanger (140) in tension.

FIG. 10is a cross-sectional view showing components of another arrangement for the rotating breech lock100of the present disclosure. Components of this rotating breech lock100are similar to those described previously so that like reference numerals are used between similar components. InFIG. 10, however, the intermediate bowl130has a more compact shape, and the tubing spool110has a shoulder114disposed lower in the spool's bore112. As before, the intermediate bowl130affixes to the breech hanger140on the lower end with a snap ring, a spiral lock, or the type of retainer179. This bowl130can have lubrication ports (not shown) communicating with ports (not shown) on the spool110so the bearings137can be lubricated in a manner similar to that described previously. As also shown, the internal bore112of the spool110can define a recess113to accommodate the worm wheel145and reduce the chances that friction between the bore112and wheel145may occur.

The use of the more compact intermediate bowl130can reduce problems with wear, friction, and stresses and can allow the rotating breech hanger140to have increased width along its length, which can be beneficial. Overall, the rest of the rotating breech lock100can be the same as described previously and can function in the same way.

Assembly and operation of the rotating breech lock100will now be discussed with reference toFIGS. 11A-11E. As shown inFIG. 11A, the tubing spool110equipped with the drive150installs on wellhead components60according to standard procedures. A BOP stack70then installs above the tubing spool110using standard procedures to provide wellbore isolation during assembly. Operators can then attach any ratchet lever or other assembly (not shown) to the drive150.

At this point, operators measure the distance from the rig floor to the gear boss surrounding the tubing spool110for the drive150. This distance is used later when setting up additional components of the rotating breech lock100. Operators run a tubing string200having tubing (e.g.,220/230) and having an anchor/packer assembly205downhole according to standard procedures. Which components of the anchor/packer assembly205used on the tubing string200depends on the implementation (e.g., whether a reciprocating, rotating, or plunger type of system is used). As shown, the anchor/packer assembly205can have an anchor210and a swivel212between tubing220/230and can have a packer240as well as other elements.

Downhole, for example, the distal end of upper tubing220can have an anchor210with a tubing swivel212. For its part, the tubing swivel212can use a known design having bearings and seals that can operate in both compression and tension to allow the tubing220above the swivel212to rotate while tubing230and other components downhole from the swivel212do not rotate. The anchor210can also have components of an anchor catch swivel, such as slips and the like, known in the art.

At the rig, operators run the tubing string200downhole and then set it in place with slips so that the top of the upper tubing220is at a suitable level above the rig floor (not shown) for installing the hanger assembly120. As shown inFIG. 11B, operators then assemble components of the hanger assembly120together by making up the intermediate bowl130, the breech hanger140, the load ring160, and the adapter170to one another as described previously. To do this, the bowl130affixes on the hanger140with the ring179and has the thrust bearing137against the hanger140. The load ring160fits on the other end of the hanger140with the thrust bearing167, and the ring177affixes the load ring160to the hanger140. The adapter170then fits onto the hanger140and secures to the load ring160with screws (not shown).

With the hanger assembly120made up, operators make up the mandrel180on the tubing string200and thread it to required torque as shown inFIG. 11B. Operators then orient the made-up hanger assembly120with the adapter170upwards and slide the assembly120over the top of the mandrel180. To do this, the mandrel180fits through the lower end of the rotating breech hanger140with the mandrel's landings190passing through the hanger's slots (147;FIG. 5C). Once the landing shoulder190of the mandrel180is located in the relief area (144;FIG. 5C) in the rotating breech hanger140, operators rotate the hanger assembly120clockwise 90° (¼ turn) and allow the assembly120to rest on the mandrel180.

As shown inFIG. 11B, a landing joint250then makes up to the top of the mandrel180using standard procedures. Marks are made on the landing joint250aligned with the landing shoulders190of the mandrel180to indicate their orientation. Additionally, marks are made on the rig floor aligned with the mandrel's landing shoulders190to indicate their orientation.

At this point, operators lower the hanger assembly120in the tubing spool110. As shown inFIG. 11C, the intermediate bowl130, the breech hanger140, the load components160/170, the mandrel180, and attached tubing220are run though the spool's bore112until the intermediate bowl130lands on the spool's landing shoulder114. When properly landed, a horizontal mark made previously on the landing joint250should be level with the rig floor. Once landed, operators install and tighten all of the anchor screws119to retain the hanger assembly120in the spool110. With the hanger assembly120landed inside the tubing spool110, operators then make a mark on the landing joint250above the rig floor at a specified distance for the tubing string200to be lowered to set the packer/anchor assembly downhole as described below.

At this point, operators disengage the mandrel180from the breech hanger140as shown inFIG. 11D. To do this, operators lift the landing joint250and the mandrel180until all of the tubing weight is taken off the hanger140. This moves the landings190free of the pins149a. Using the previous vertical markings, operators then rotate the mandrel180a quarter turn (i.e., 90-degrees) so the landings190align with the landing gaps (147;FIG. 5C) in the hanger's bore142.

Once the mandrel180has been keyed free, operators then run the mandrel180downward through the breech hanger140, intermediate bowl130, and beyond as shown inFIG. 11D. The tubing string200is run until reaching the mark on the landing joint250specifying the required distance to set the anchor/packer assembly205downhole. Operators then actuate the anchor/packer assembly205using known procedures. For example, the tubing swivel210can have J-slot locking mechanisms, slips, and other components related to tubing swivels and tubing anchors known and used in the art to make the necessary connection. For its part, the packer240can be set mechanically and/or hydraulically.

At this point with the tubing string200properly set, operators align the vertical marks on the landing joint250with the marks on the rig floor to align the mandrel's landings190with the hanger's gaps (147;FIG. 5C). The tubing swivel212can allow the upper tubing220to rotate relative to the tubing230set with the packer240. With a straight vertical lift, operators then pull the mandrel180attached to the tubing220back upward into the rotating breech hanger140as shown inFIG. 11E. This puts tension on the tubing220. The mandrel180can pilot itself back into the breech hanger140if aligned within an acceptable accuracy. If the weight indicator shows a sudden increase, however, operators can slack off and realign the mandrel's shoulders190.

Once the mandrel180reaches the upper recess (144;FIG. 5C) inside the hanger's bore (142), operators rotate the mandrel180a quarter turn. The swivel210can allow the mandrel180and attached tubing220to turn relative to the fixed tubing230and other components downhole. Once turned, operators lower the mandrel180and key it back into the breech hanger140as shown inFIG. 11E. At this point, the hanger assembly120has the tubing's tension on it.

Operators can remove the landing joint250by rotating it counter-clockwise from the mandrel180. With the well safe and under control, the BOP stack70is removed from the tubing spool110. Now the rotating breech lock100is set up for operation, and operators can install any other components, such as ratchet mechanism, production piping, gas lift equipment, rod, etc. The tubing220is now ready to be rotated via the drive150of the rotating breech lock100with tension pulled on the tubing220.

All the while, the hanger assembly120maintains pressure containment between the mandrel180and the breech hanger140while rotating the tubing220in conjunction with a pump jack or other actuating device. As the device cycles and the action rotates the breech hanger140, internal wear on the tubing's internal diameter can be evenly distributed to increase the life of the tubing220and decrease the need for maintenance. Downhole, the swivel212allows the tubing220to rotate relative to production tubing230and other components fixed in the wellbore's casing10. Whenever a work over is needed, a landing joint220can stab into the mandrel180so previous procedures can be used to disengage the mandrel180from the breech hanger140.

The foregoing description of preferred and other embodiments is not intended to limit or restrict the scope or applicability of the inventive concepts conceived of by the Applicants. In exchange for disclosing the inventive concepts contained herein, the Applicants desire all patent rights afforded by the appended claims. Therefore, it is intended that the appended claims include all modifications and alterations to the full extent that they come within the scope of the following claims or the equivalents thereof.