The field of the invention is a lockable swivel that can be used in a drill string for rotation thereof when the swivel is locked and in wireline applications to let the drill string rotate freely when the wireline is operated.
Previously, if the operator desired to rotate the drill string during wireline operations, the wireline was pulled from the well bore and the entry devices were disengaged from the drill string. The removal of the wireline could be avoided if an inline swivel was placed in the drill string between the wireline device and the rotary table. This arrangement would permit rotation to be accomplished with a wireline in place, but effectively disengaged the top-drive unit from its preferred role of providing both lifting power and rotation to the drill string.
Using prior conventional technology, the drill pipe was separated and raised high above the rig floor on each run in order to change out tools. Although the pipe can be rotated, the operator could not circulate or reciprocate the pipe during these periods. Circulation was achieved by adding a pump-in sub and another T.I.W. safety valve immediately above the existing T.I.W. valve; which, however, put the disconnect or break point between the upper T.I.W. valve and the swivel several feet above the rig floor creating a safety hazard while operating the rig tongs.
Further, since the tool strings must be stripped in and out beneath the upper assembly, a lubricator or tool protection device could not be used and all tools and explosives were brought onto the rig floor unshielded and unconfined. In the event of an inadvertent detonation of the explosive string shot or perforators, all personnel on the rig floor were totally exposed to this unnecessary life-threatening hazard.
Once rigged-up and going in the hole using conventional technology such as the Boyd side-entry sub, the wireline passed through the acute angle in the side entry sub. This caused excessive wearing of the wireline and creates sever grooving in the sub. The single rubber pack-off, which is commonly used with this system, is very susceptible to leaking and/or line gripping and stoppage during pump-down operations. The system cannot be used when working under surface pressure and with the need to utilize a grease injector and wireline blow out preventers (BOPs).
During pipe recovery operations, both right and left-hand torque must be worked down-hole using the rig tongs. This is a procedure has long been recognized to be one of the greatest safety hazards to be encountered during pipe recovery operations. When using this prior technology, pipe tongs were attached to the drill string and secured to the rig to hold torque that had been put into the drill string from the rotary table or top drive unit.
With the present invention, this torque can be maintained while continuing circulation and wireline operation.
USP RE41,759
Referring to
This design permitted the wireline entry devices 106 to be left in the drill string 100 during all operations involving the wireline operation avoiding the time consuming makeup and disengagement of the entry tools 106 required to safely permit entry of the wireline into the well bore. If rotation and longitudinal movement is desired, the wireline alone was removed from the wellbore, but the entry tool 106 remained in place and the swivel 110 is locked to provide transmission of all rotation through the swivel 110 into the pipe string 112.
At other times, the operator using a top-drive unit 102 could pick up the drill string 100 and yet maintain torque which has been put into the pipe string 112 in pipe recovery operations. This was done by engaging the swivel 110 in locked position and picking up with the top drive unit 102. As the torque is worked through the drill string 100, additional wireline operations and the operator would set the drill string 100 down, disengage the swivel 110, continue to rotate with the rotary table 114 and continue the wireline operations.
The swivel provided to accomplish the above operations is shown in
Also relevant in the lockable swivel field is U.S. Pat. No. 6,378,630
A lockable swivel features a unitary upper housing connected to a unitary lower housing with a connector to hold the housing components together for relative or tandem rotation. A hydraulically actuated piston shifts spaced apart splines axially to selectively engage splines on both housings for the locked position and to release the splines in both housing for the unlocked position. A thrust bearing in the lower housing is disposed between two pairs of tapered surfaces with the upper pair disposed on the housings and the lower pair between the connector and the lower housing. The thrust bearing is disposed between a pair of spherical bearings with the upper radial bearing retained by the upper housing and the lower radial bearing retained by the connector. An internal ring retains the piston to the upper housing.
Referring to
Piston 19 has an upper spline 48 engaged with a spline 50 on the upper body 12 in the
Thrust bearing 8 is externally retained by adjacent perpendicular surfaces 74 and 76 on the connector 15 and 70 and 72 on the lower body 13. Thrust bearing 8 is straddled by mating sloping surfaces on opposed sides. Above the bearing 8 surface 80 on the lower end 56 of the upper body 12 sits in opposition to surface 82 on the lower body. Below the bearing 8 surface 84 on the lower body 13 is opposed to mating surface 86 on the connector 15. Surfaces 84 and 86 are not intended to contact. In one option the pair of mating sloping surfaces 80 and 82 above bearing 8 can contact and in that variation the upper radial bearing 9 can be replaced with a floating roller bearing to transmit the axial component of a thrust load while the radial component is absorbed by the upper body 12.
In preferred alternative to dealing with tensile thrust, as it is very unusual to have compressive thrust loads in such devices, the surfaces 84 and 86 or 80 and 82 do not contact and the thrust load is taken by the upper spherical bearing 9. The mating pairs of sloping surfaces allow the use of a larger thrust bearing 8 than the radial bearings 9 that straddle it above and below.
The piston 19 can be pinned at 5 to allow external indication of the position of the piston 19. Piston 19 can also be shear pinned to the upper body 12 for run in to prevent accidental movement of the piston 19 until a predetermined force is applied in chamber 42.
Those skilled in the art can now appreciate several features and variations thereof as depicted in
While the piston is illustrated as hydraulically externally driven in opposed directions those skilled in the art will appreciate that the piston can be alternatively actuated with flow cycles therethrough that in combination with a j-slot mechanism can put the piston 19 in the splines locked and unlocked positions in situations where hydraulic power systems are not available. In this case the piston is acted on by a spring return to work against the force generated with fluid flow. On the other hand the piston can have unequal piston areas and can be moved against a spring bias with simply applied pressure and removal of the applied pressure.
The driving force can also be locally available rig air. The spacing of the bearing assembly that comprises bearings 8 and 9 axially spaced from the retainer 14 allow the use of larger bearings without adding unduly to the diameter of the housings while at the same time providing additional supporting wall for the bearings.
The above description is illustrative of the preferred embodiment and many modifications may be made by those skilled in the art without departing from the invention whose scope is to be determined from the literal and equivalent scope of the claims appended hereto.
Filing Document | Filing Date | Country | Kind |
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PCT/GB2012/053004 | 12/4/2012 | WO | 00 |