|Publication number||US3766991 A|
|Publication date||23 Oct 1973|
|Filing date||2 Apr 1971|
|Priority date||2 Apr 1971|
|Publication number||US 3766991 A, US 3766991A, US-A-3766991, US3766991 A, US3766991A|
|Original Assignee||Brown Oil Tools|
|Export Citation||BiBTeX, EndNote, RefMan|
|Patent Citations (9), Referenced by (118), Classifications (12), Legal Events (1)|
|External Links: USPTO, USPTO Assignment, Espacenet|
United States Patent 1 Brown Oct. 23, 1973 ELECTRIC POWER SWIVEL AND SYSTEM FOR USE IN ROTARY WELL DRILLING  Inventor: Cicero C. Brown, c/o Brown Oil Tool, Inc., PO. Box 19236, Houston, Tex. 77024  Filed: Apr. 2, 1971  Appl. No.: 130,597
Hanson 173/57 X 1,949,908 3/1934 Hawk 173/20 X 2,016,785 10/1935 Lawlor 173/79 X 3,426,855 2/1969 Crooke et al. 173/57 3,266,582 8/1966 l-lomanick 175/85 X 3,404,741 10/1968 Gheorghe et al. |66/77.5 X Thornburg 173/57- Primary ExaminerErnest R. Purser Attorney'Carlos A. Torres and Bill B. Berryhill  ABSTRACT An electric power swivel for rotating and handling drill pipe during well drilling, adapted for use with either conventional drill pipe or larger diameter casing strings and having fluid pressure cushioned suspension means to accommodate vertical movements required in making up and breaking out threaded connections between pipe sections.
26 Claims, 15 Drawing Figures rAnzmwumaa ms 3.766391 SHEET 10E 6 PATENTED URI 2 3 I913 sum 2 or s AT TOENE) PAIENIEnum 23 ms 3.766591 sum 8 or 6 ATTORNEY ELECTRIC POWER SWIVEL AND SYSTEM FOR USE IN ROTARY WELL DRILLING BACKGROUND OF THE INVENTION Conventional rotary drilling requires the use of a heavy rotary table and its large and heavy drive connections and appurtenances and large drilling engines, all of which are relatively expensive and cumbersome, and have other undesirable features particularly in connection with drilling operations conducted in water bodies.
The present invention is directed to an electric power drive swivel with several appurtenances by which a relatively simple drilling system is provided which obviates most of the objectional features of more conventional systems, which is highly flexible for application to a wide variety of drilling conditions, and which is readily portable and easily assembled and disassembled as may be required.
The system in accordance with this invention includes a swivel stem suitably supported for rotation in a casing on which is mounted a reversible electric motor connected to the swivel stem by an efficient gear train. The swivel structure is supported from the travelling block of the drilling rig by a fluid-pressure cushioned suspension and is pivotally mounted in a guide frame slidable longitudinally in the derrick. A fluid pressure actuated tilting jack is arranged between the travelling block and the swivel housing to enable angular tilting of the swivel for alignment with pipe sections to be transferred to and from the drill string during the drilling operation. The system also includes a novel form of connector for connecting the swivel to the drill pipe sections and a strain gauge arrangement for continuously monitoring loads on the swivel and its supporting system.
Other and more specific objects and advantages of this invention will become more readily apparent from the following detailed description when read in conjunction with the accompanying drawing.
In the drawing:
FIGS. 1A and 18, together, comprise a vertical view, partly in elevation and partly in section of the power swivel in accordance with one embodiment of this invention;
FIG. 2 is a cross-sectional view taken on line 22 of FIG. 1A;
FIG. 3 is a vertical partly sectional view of one form of a connector device fordrivingly connecting the power swivel to a pipe string, the parts being shown in the unactuated position;
FIG. 4 is a view similar to FIG. 3 showing the parts in the actuated pipe-gripping position;
FIGS. 5 and 7 are cross-sectional views taken on lines 55 and 77, respectively of FIG. 4;
FIG. 6 is a cross-sectional view taken on line 66 of FIG. 3;
FIG. 8 is a view partly in elevation and partly in section showing one position of the power swivel suspension;
FIG. 9 is a view similar to FIG. 8 showing another position of the power swivel suspension;
FIGS. 10, ll, 12 and 13 are generally diagrammatic views showing several positions of the power swivel in the drilling derrick at different stages of operation; and
FIG. 14 is a cross-sectional view taken on line 14l4 of FIG. 12.
Referring to the drawing, the power swivel comprises a hollow casing 10 of inverted generally frusto-conical shape defining an enclosure 11 closed at its upper end by a cap plate 12 removably secured to the upper end of'the casing by bolts 13 (FIG. 2) and communicating with an axial bore 14 opening through throat portion 10a defining the lower end of the casing. An electric motor, designated generally by the letter M, is vertically mounted centrally on cap plate 12 and removably secured thereto by cap screws 15. Motor M may be of any well known construction having sufficient power and adapted for reversible operation. The details of the motor do not form a part of this invention, except that it is provided with a hollow drive shaft 16, suitably supported for rotation in the vertical position .and having an axial bore 16a.
A tubular swivel stem 17 extends through bore 14 and carries a horizontally extending annular head 18 at its upper end. The lower end of stem 17 projects from thelower end of casing 10 and is provided with a threaded pin 17a for connection to other tools, as will appear subsequently. Head 18 is rotatably supported on roller bearings 19 which are, in turn, seated on the upper flanges of a horizontally disposed H-beam collar 20, which encircles the swivel stem and is seated on an upwardly facing shoulder 21 in casing 10. Roller bearings 22 are mounted between swivel stem 17 and the wall of throat portion 10a at a point below shoulder 21 and are held in place by a tubular bushing 23 which also defines a packing space containing seal packing 24 for sealing off between swivel stem 17 and bushing 23. A tubular cap 25 surrounds the portion of the swivel stem extending below the lower end of throat portion 10a and is secured to the latter by means of cap screws 26 which extend through the flange 2311 on bushing 23 and thereby serve to also secure bushing 23, bearings 22 and seal packing 24 in place about the swivel stem.
Swivel stem 17 is rotatably driven by motor shaft 16 through a train of gears which includes an annular pinion 26 mounted on a hub sleeve 27 which is suitably secured coaxially to the lower end of shaft 16; a set of three planetary gears 28 in mesh with pinion 26 and rotatably mounted about enlarged hubs 29 which are secured to head 18 by means of cap screws 30. The planetary gears are in mesh with a sun gear 31 seated against the inner wall of casing 10 near its upper end and secured to cap plate 12 by means of cap screws 32.
Casing 10 is formed with a pair of laterally extending ears 33,33 spaced apart and having vertically extending bores 34,34 therethrough. Cap plate 12 has similar ears 35,35 overlying ears 33, 33 and provided with bores 36,36 registering with bores 34, 34. Tubular sleeve 37,37 having axial through-bores 38,38- are screwed into the lower ends of bores 34,34. Each of the bores 38 defines a pressurecylinder 38a adpated to receive a piston 39 formed with a lower head 40 fitted with seal rings -41 and 42 for'slidable sealing engagement with the wall of bore 38. Piston 39 extends upwardly through bores 34 and 36 which are provided with respective packings 43 and 44 sealing with the piston to close the upper ends of the cylinders. The upper end portions of pistons 39 which project above cap plate 12 are provided with externally threaded pins 45 which are screwed into hanger caps 46. The latter have upwardly extending lugs 47 which are received in clevises 48 and pivotally secured thereto by means of transversely extending pivot pins 49. The clevises are .se-
cured to the opposite ends of a bail 50 (FIG. 1A) by.
ized by a body of an inert pneumatic fluid 54a such as' nitrogen gas.
A tubular mandrel extends upwardly through the bore of swivel stem 17, being threadedly connected to the stem at a point opposite head l8 by a threaded connection 71. The mandrel extends upwardly through the bore of hub sleeve 27 and bore 160 of motor shaft 16 and thence through a'swivel housing 62. A swivel bushing 63 (FIG. 1A) is threadedly secured to the upper end of mandrel 60 and is provided with a suitable rotary connection 64 to the upper end of swivel housing 62. The upper end of bushing 63 is connected to the goose-neck fittings 65 of conventional design adapted for conducting drilling mud or other fluid to the drilling string through the bore of mandrel 60.
For continuously measuring the load on the swivel, a plurality (only one shown) of a generally conventional type of strain gauge are mounted on the inner face of web 20a of I-I-beam 20, the leads 71 of the gauges being brought outside casing 10 to a suitable electrical instrument panel (not shown) at the drillers station, where the forces to which the strain gauges are subject may be suitably measured and indicated and recorded. The outer ends of cars 33 are fitted with trunions 72 journalled in the ends of guide arms 73 (FIGS. 1B, 2, and 11) which connect guide sleeves 74 disposed for sliding movement on vertically disposed guide bars 75 suitably mounted in drilling derrick D in which the power swivel is suspended.
The trunions thus provide a pivoting connection bewith a collar K. This embodiment comprises a tubular housing having a bore 85a and threadedly connected to a threaded pin formed on a head 86 having an axial bore 86a, the upper end of which is provided with a threaded socket 87 adapted to receive pin 17a of the swivel stem. The latter is provided with longitudinal passages 88 and 88a in its wall communicating at their upper. ends with spaced ports 89 and 90 respectively'in cap 25 which are connected respectively to conduits 91 and 92 for circulation of pressure fluid between a suitable source (not shown) and the connector device. At a point above pin 17a passages 88a and communicate respectively with spaced ports 93 and 94 which communicate, respectively, with conduits 95 and 96 extending through head'86 and a reduced diameter I extension 97 thereof into communication with spaced points in a cylinder 98 defined between the wall of bore 85a and extension 97. I v
A set of angularly spaced lugs 99 are mounted for limited radial movement through correspondingly shaped radial slots 100 in the lower end of extension 97. Lugs 99 are resiliently biased outwardly by means of springs 101 arranged between extensions 102 on the upper and lower ends of the lugs and opposed portions of the lower end of extension 97. A sleeve piston 103 is slidably mounted in cylinder 98 and is secured to the upper end ofa skirt 104 which extends downwardly between the wall of bore 85a and the exterior of extension 97, the skirt-being movable downwardly behind lugs 99 to urge the latter inwardly against the opposition of springs 101. The arrangement is such that when pressure fluid is introduced through conduit 96 above piston. 103 forcing the latter downwardly, skirt 104 will force lugs 99 inwardly against pipe P and define shoulders 105 (FIGS. 4 and 7) beneath the lower end of collar K and thereby prevent the connector device from tween the power swivel andthe guide sleeves so as to permit the power swivel to be tilted at an angle to the vertical when required in operations to be described subsequently (FIGS. 10 and 12).
In order to effect tilting of the power swivel when desired, a fluid pressure actuated tilting jack, designated generally by the letter J, (FIGS. 10 to 13) is connected between travelling block B and casing 10 of the power swivel. Such a tilting jack is disclosed in my copending application, Ser. No. 125,740, filed Mar. 18, 1971. Jack J comprises a cylinder 76 hingedly connected at 77 to the side of travelling block B and enclosing a piston 78 having its free end hingedly connected to casing 10.
A connection for the end of piston 78 'to casing 10 is shown in FIGS. 2 and 10 to 14, and comprises a hinge lug 79 projecting radially outwardly from casing 10 at the mid point between ears 33,33. Lug 79 is adapted to be received in a clevis 80 carried by the outer end of piston 78 and is hingedly secured thereto by a transverse hinge pin 81.
FIGS. 3 to 7, inclusive, illustrate an overshot form of a connector device, designated generally by the letter 0, for drivingly connecting swivel stem 17 tothe upper end of a string of drill pipe P or a section thereof fitted being pulled off the end of the pipe, thus performing the functions of more conventional elevators.
. A pair of arcuate recesses 106 are provided in opposite portions of the innerwall of extension 97. A pair of arcuate cam shoes 107 having toothed inner faces 108 are rockably mounted on shafts 109 vertically disposedin recesses 106. The shapes of the cams and recesses are .made so that an initial rotational movement of the connector in either. direction will rock the cams into tight gripping engagement with collar K and thereby transmit corresponding rotary movement from the power swivel through the connector device to the pipe.
Where the drill string is the relatively small diameter conventional drill pipe, or has flush diameter boxes, pin 17a on the swivel stem may be screwed directly into the usual threaded box K of the pipe (FIGS.'8 and 9). Still another suitable form of connector device which is adapted to be insertible in the bore of the drill string and non-threadedly connected thereto is disclosed in my U. S.'Pat. No. 3,552,507 and U. S. application, Ser.
No. 52,517, filed July 6, 1970; An additional form of connector device for use in combination with a power swivel is illustrated in my copending U. S. application, Ser. No. 70,425, filed Sept. 8, I970.
OPERATION In operation, the power swivel will be hung from the travelling block, as best seen in'FIGS. 10 to 14, and
the derrick from a supply located outside the derrick and presented by a conveyor R or the like, as shown in FIG. 10, at an angle to the vertical, jack J will be actuated to tilt the power swivel at an angle appropriate to' align connector 0 with the pipe section which will then be pushed into the bore of the connector by any suitable manual or mechanical means, not shown. The end of the pipe section will be secured in the connector by actuation of lugs 99 by means of pressure fluid supplied through passages 88 and 96 to cylinder 98 to move pisshoes 107 to grip pipe section P and rotate the same to make it up into the box on the upper end of the drill string in the well. After the connection is thus made,
continued rotation of the drill string by the power swivel will drill off the added section of drill pipe.
Thereafter with the well string including the added pipe section held in slips in the well head, lugs 99 will be retracted by directing flow of pressure fluid through conduits 88a and 95 to raise piston 103 and skirt 104. Subsequently, raising of the power swivel will pull connector 0 off the upper end of the pipe and. enable repetition of operation of adding pipe sections to the well string and drilling them off as required. When drilling off a section of added pipe, drilling fluid will be introduced through goose neck 65, mandrel 60 and swivel stem 17 to the bore of the drill pipe string and circulated in the usual manner down the pipe string through the drill bit passages (not shown) and thence upward to the surface outside the drill pipe string.
When necessary to withdraw the drill string, the pipe sections are broken out successively by reverse rotation of the power swivel, while the remainder of the string is held conventionally in slips supported in wellhead W. Each section is removed from the derrick after release from connector 0 (FIG. 13), the latter being tilted by means of jack J to an appropriate angle for laying the pipe section onto the transfer conveyor R,'one suitable form of which is disclosed in my aforesaid U. S. application, Ser. No. 125,740, filed Mar. 18, 1971. FIG. 12 shows the power swivel returned to the vertical position after releasing the discharged pipe section as shown in FIG. 13, and is thus in position to be lowered to again engage the upper end of the pipe string for removing the next pipe section.
In making-up and breaking-out the pipe sections, the hangers formed by cylinders 38a and pistons 39 perform useful functions as shock absorbers and in enabling smooth handling of the pipe. When a section of pipe P is picked up by the power swivel, the pressure maintained in cylinders 38a by the pressurized fluid in reservoir 53 will be sufficient to hold pistons 39 in their lowered position (FIGS. 18 and 9). When the threaded pin on the lower end of the pipe section is stabbed into the box on the upper end of the pipe string and the added pipe section is rotated to make up the threads, the entire swivel will be pulled down as the threads are made up and this downward pull will be resiliently opposed by the pneumatically pressurized fluid in reservoir 53 and cylinders 39 which act as shock absorbers to protect against thread damage as the pipe section is made up.
When breaking-out operations are being conducted, the load of the entire pipe string must be taken on the power swivel when the well head slips are released to enable the entire pipe string to be lifted to an appropriate height before the slips are again re-set. As this load is taken, the power swivel will be pulled down relative to bail 50 and pistons 39 secured thereto, the pistons moving up in cylinders 38a as the pressurizing fluid in reservoir 53 is compressed (FIG. 8), usually for the full length of the piston stroke. When the slips in the well head are re-set and the power swivel operated to unscrew the pipe section being removed, the upward movement of the power swivel occasioned by the unscrewing of the threads will be compensated for by relative downward movements of pistons 39 under the cushioningpressure of the pressurizing fluid in reservoir 53 which thereby assures smooth release of the threads without sudden upward jumping of the power swivel when the last thread is released. When this occurs pistons 39 will be returned to the positionsshown in FIGS. 1B and 9.
Strain gauges likewise perform useful functions in operation of the described assemblage. H-beam collar 20 functions as a compression member between head 18 and casing shoulder 21 and thereby is subject to the varying loads carried by the swivel stem during various stages of operation of the power swivel in handling pipe and during drilling. By mounting the strain gauges 70 on web 20a of the H-beam, they will continuously sense and be directly responsive to the varying loads imposed on the swivel stem. Thus, the gauges may be continuously employed with suitable known instrumentation to continuously deliver information to the driller with respect to the total loads on the hoist equipment, the weight-on-bit and other information of like nature which is useful to the driller in the drilling and pipe handling operations.
It will be understood that various changes and modifications may be made in the details of the abovedescribed embodiments within the scope of the appended claims but without departing from the spirit of their invention.
What I claim and desire to secure by Letters Patent 1. A power swivel for use in rotary well drilling, comprising:
a. a housing;
b. a tubular swivel stem rotatably mounted in the housing;
0. a reversible electric power motor mounted on the housing and having a tubular drive shaft coaxial with said swivel stem;
(1. transmission means in the housing operably connecting said drive shaft to said swivel stem;
e. releasable connector means associated with said swivel stem for drivingly connecting said stem to a pipe section; and
f. fluid pressure-loaded hanger means on said housing for resiliently supporting the swivel from the hoist system of a drilling derrick.
2. A power swivel according to claim 1 including pressure-responsive means mounted in said housing in axial compression between said swivel stem and a relatively fixed supporting element in said housing for directly sensing the compression forces therebetween.
3. A power swivel according to claim 1 wherein said connector means includes:
a. a tubular housing adapted to coaxially receive the upper end of said pipe section;
b. a set of angularly spaced pipe-gripping shoes mounted in the housing for rocking movement into and out of gripping engagement with said pipe end in response to angular movement of the housing relative to the pipe section;
c. a plurality of angularly spaced abutment members mounted in said housing beneath said shoes for radial movement to and from supporting position beneath an external shoulder on the pipe section; and
d. fluid pressure-responsive means in said housing for actuating said abutment members.
4. Ina power swivel according to claim 3, conduit means housed in said swivel stem for communicating pressure fluid to said fluid pressure-responsive means.
5. A power swivel according to claim 1 wherein said hanger means comprises:
a. a pair of vertically disposed cylinders mounted at diametrically spaced points in said housing;
b. pistons reciprocable in said cylinders;
c. a bail member connected to the upper ends of said pistons and supported from said hoist system; and
d. a pneumatic pressure fluid reservoir in continuous communication with said cylinders.
6. An assembly for manipulating tubular members comprising:
a. support means;
b. rotary drive means carried by said support means;
c. stem means rotatably powered by said rotary drive means for rotating said tubular members;
d. rotary drive shaft means coaxial with said steam means and extending longitudinally through motor means included in said drive means, said motor means including a reversible electric motor means;
e. first gear means connected with said drive shaft means for rotation therewith;
f. second gear means for meshing engagement with said first gear means and movable by rotation of said first gear means; and I g. drive linkage means operatively connected between said stem'means and said second gear means for imparting rotary motion from said second gear means to said stem means, said second gear means including-at least three planatary gear means rotatable about gear axes fixed relative to said drive linkage means and said planatary gear means operatively meshing with a surrounding third gear means whereby rotation of said first gear means acts through said planatary gear means against said surrounding third gear means to rotate said drive linkage means.
7. An assembly as defined in claim 6 further including:
a. orienting means for positioning the axis of said stem means at different axial alignments; and
b. communicating fluid flow passage means extending longitudinally through said stem means and said drive shaft means.
8. An assembly as defined in claim 6 further including:
a. connector means carried by said stem means for engagement and release of said tubular members; and
b. load sensing and indicating means for sensing and indicating the load supported by said assembly.
9. An assembly as defined in claim 6 further including:
a. vertical drive means for moving said rotary drive means vertically through said support means; and
b. automatic, resilient shock absorbing means independent of said vertical drive means for accommodating relative vertical movement between said stem means and said support means.
10. An assembly for manipulating tubular members comprising:
a. rotary drive means;
b. tubular stem means rotatively powered by said rotary drive means for rotating said tubular members,
c. connector means carried by said stem means and remotely operable for non-threaded engagement with said tubular members for rotation of said members in any direction;
d. remotely operable means included in said connector means for nonrotative release from said tubular members; and
e. sealing means included with said connector means for forming a sealed engagement between said tubular stem means and said tubular members.
11. An assembly as defined in claim 10 further including vertical drive means for moving said stem means to different vertical positions.
12. An assembly as defined in claim 11 further including orienting means for varying the angle of inclination of said stern means.
13. An assembly as defined in claim 11 further including:
a. support means for supporting said rotary drive means; and
b. automatic shock absorbing means independent of said vertical drive means for accommodating relative vertical movement between said stem means and said support means.
14. An assembly as defined in claim 10 wherein:
a. said rotary drive means includes a reversible electric motor; I
b. a drive shaft extends longitudinally through said motor; and
c. a fluid flow passage means extends longitudinally through said drive shaft.
15. An assembly for manipulating tubular members comprising:
a. support means;
b. rotary drive means carried in said support means,
said rotary drive means including a reversible electric motor;
c. drive shaft means extending longitudinally through said motor and including a fluid flow passage means extending longitudinally through said drive shaft;
d. stem means rotatably powered by said rotary drive means for rotating said tubular members;
e. connector means carried by said stem means for engagement or release of said tubular members;
f. vertical drive means for moving said rotary drive means vertically through said support means; and
g. automatic, resilient shock absorbing means independent of said vertical drive means for accommodating relative vertical movement between said stem means and said support means, said shock absorbing means including a pressurized gas acting against an incompressible fluid.
16. An assembly as defined in claim further including load sensing and indicating means for sensing and indicating the load supported by said assembly.
17. A system for handling threaded tubular well members adapted to be joined together to form a tubular string of such members comprising:
a. support means;
.b. rotary drive means carried by said support means;
c. stem means rotatably powered by said rotary drive means for rotating said tubular well members and for rotating a string of said members;
d. connector means carried by said stem means and remotely operable for non-threaded engagement with said tubular members and string for rotation of said members and string in any direction;
e. release means included in said connector means and remotely operable for non-rotative release from said tubular members and string;
f. vertical drive means for moving said rotary drive means vertically through said support means;
g. orienting means for changing the inclination of said stem means;
h. remotely operable holding means for preventing rotation of said string while said stem means and a connected tubular member are rotated for removing or adding said connected member to said string; and
i. gearing means included in said rotary drive means for providing sufficient force in said rotary drive means for independently making and breaking fully tightened joints between tubular members.
18. An assembly as defined in claim 17 wherein said rotary drive means includes a reversible electric motor means.
19. An assembly as defined in claim 18 wherein:
a. drive shaft means extend longitudinally through said electric motor means; and
b. fluid flow passage means extend longitudinally through said drive shaft means in fluid communication with said stem means.
20. In a rotary drilling system including a derrick and a vertically movable travelling block suspended in the derrick:
a. an electric powered rotary drive unit pivotally supported from the travelling block and movable vertically therewith;
b. reversibly rotatable hollow swivel means carried by said drive unit for connection to a well pipe;
c. fluid pressure-operated jack means pivotally connecting said drive unit to said travelling block operable to effect angular movement of the drive unit relative to the vertical;
d. a drive connector carried by the swivel means adapted for non-threaded engagement with the upper end of the said well pipe for transmitting torque thereto;
e. a tubular housing included in said connector to co axially receive the upper end of said pipe string; and
f. a set of pipe-gripping shoes rockably mounted in said housing for angular movement into and out of gripping engagement with the upper end of said well pipe in accordance with the direction of angular movement of said housing relative to said pipe string.
21. A rotary drilling system according to claim 20 including means mounted in said housing for releasably securing said housing against axial release from said well pipe.
22. A rotary drilling system according to claim 21 wherein said last-mentioned means comprises:
a. a plurality of angularly spaced abutment members mounted in said housing beneath said shoes for radial movement to and from supporting positions beneath an external shoulder on the well pipe; and
b. means in the housing for effecting said radial movements.
23. A rotary drilling system according to claim 22 wherein said last-mentioned means comprises:
a. resilient means normally biasing said abutment members outwardly away from said supporting position; and
b. fluid pressure-actuated means in the housing operable to move said abutment members inwardly to said supporting position in opposition to said resilient means.
24. A rotary drilling system according to claim 23 wherein said fluid pressure-actuated means comprises:
a. piston means axially movable to and from positions thrustingly engaging said abutment members; and
b. pressure fluid-supply conduits extending through said swivel means into communication with said piston means.
25. An assembly for manipulating tubular members comprising:
a. support means;
b. rotary drive means carried by said support means;
0. stem means rotatively powered by said rotary drive means for rotating said tubular members;
d. rotary drive shaft means coaxial with said stem means and extending longitudinally through motor means included in said drive means;
e. first gear means connected with said drive shaft means for rotation therewith;
f. second gear means for meshing engagement with said first gear means and movable by rotation of said first gear means;
g. drive linkage means operatively connected between said stem means and said second gear means for imparting rotary motion from said second gear means to said stem means;
h. connector means carried by said stem means and remotely operable for non-threaded engagement and release of said tubular members; and
i. sealing means included with said connector means for forming a sealed engagement between said stem means and said tubular members.
26. An assembly for manipulating tubular members comprising:
a. rotary drive means;
b. tubular stem means rotatively powered by said rotary drive means for rotating said tubular members;
c. drive shaft means extending longitudinally through an electric motor means included in said drive means;
d. a fluid flow passage means extending longitudinally through said drive shaft means in fluid communication with said tubular stem means;
e. connector means carried by said stem means for engagement or release of said tubular member, said connector means including remotely operable means for nonthreaded engagement in release of said tubular member and further including sealing means vertically through said support means; and means for forming a sealing engagement between g. orienting means for varying the angle of inclination said tubular stem means and said tubular members; of said stem means.
f. vertical drive means for moving said rotary drive
|Cited Patent||Filing date||Publication date||Applicant||Title|
|US1377575 *||22 Dec 1919||10 May 1921||Rotary well-drilling apparatus|
|US1395706 *||22 Dec 1919||1 Nov 1921||Greve Edgar E||Rotary well-drilling apparatus|
|US1398551 *||2 Aug 1920||29 Nov 1921||Hanson Gustaf W||Boring-drill|
|US1949908 *||19 Aug 1929||6 Mar 1934||Hawk Watson L||Weight indicating device for well drilling apparatus|
|US2016785 *||15 Aug 1934||8 Oct 1935||Lawior Joseph P||Means for drilling wells|
|US2863638 *||19 Apr 1955||9 Dec 1958||Bucyrus Erie Co||Rotary drill string apparatus|
|US3266582 *||24 Aug 1962||16 Aug 1966||Leyman Corp||Drilling system|
|US3404741 *||20 Dec 1963||8 Oct 1968||Ministerul Ind Petrolui Si Chi||Automated system and drilling rig for continuously and automatically pulling and running a drill-pipe string|
|US3426855 *||6 Feb 1967||11 Feb 1969||Global Marine Inc||Drilling apparatus|
|Citing Patent||Filing date||Publication date||Applicant||Title|
|US3857450 *||2 Aug 1973||31 Dec 1974||Guier W||Drilling apparatus|
|US3915243 *||22 Jan 1975||28 Oct 1975||Gardner Denver Co||Rotary drive and joint breakout mechanism|
|US3915244 *||6 Jun 1974||28 Oct 1975||Brown Cicero C||Break out elevators for rotary drive assemblies|
|US3949818 *||30 Sep 1974||13 Apr 1976||Western Gear Corporation||Hydraulic drilling rig and power swivel|
|US3964552 *||23 Jan 1975||22 Jun 1976||Brown Oil Tools, Inc.||Drive connector with load compensator|
|US4074774 *||19 May 1975||21 Feb 1978||Brown Cicero C||Drilling assembly|
|US4393944 *||11 Sep 1980||19 Jul 1983||Warman International Limited||Drill rig|
|US4416337 *||26 May 1981||22 Nov 1983||Albert Phillips||Drill head assembly|
|US4465144 *||22 Feb 1983||14 Aug 1984||Warman International Limited||Drill rig mast structure|
|US4489794 *||2 May 1983||25 Dec 1984||Varco International, Inc.||Link tilting mechanism for well rigs|
|US4593773 *||14 May 1984||10 Jun 1986||Maritime Hydraulics A.S.||Well drilling assembly|
|US4753300 *||26 Feb 1987||28 Jun 1988||Triten Corporation||Hydraulic top drive for wells|
|US4781359 *||23 Sep 1987||1 Nov 1988||National-Oilwell||Sub assembly for a swivel|
|US4813498 *||3 Mar 1988||21 Mar 1989||National-Oilwell||Active counterbalance for a power swivel during well drilling|
|US4867236 *||6 Oct 1988||19 Sep 1989||W-N Apache Corporation||Compact casing tongs for use on top head drive earth drilling machine|
|US4878546 *||12 Feb 1988||7 Nov 1989||Triten Corporation||Self-aligning top drive|
|US4890681 *||5 Apr 1989||2 Jan 1990||Michael Skelly||Method and apparatus for rotary power driven swivel drilling|
|US5036927 *||19 Sep 1990||6 Aug 1991||W-N Apache Corporation||Apparatus for gripping a down hole tubular for rotation|
|US5193626 *||17 Aug 1990||16 Mar 1993||Rudolf Hausherr & Sohne Gmbh & Co. Kg||Drilling device|
|US5195598 *||23 Dec 1991||23 Mar 1993||Devall Donald L||Drill head assembly|
|US5381867 *||24 Mar 1994||17 Jan 1995||Bowen Tools, Inc.||Top drive torque track and method of installing same|
|US5501286 *||30 Sep 1994||26 Mar 1996||Bowen Tools, Inc.||Method and apparatus for displacing a top drive torque track|
|US6527047||16 Aug 1999||4 Mar 2003||Weatherford/Lamb, Inc.||Method and apparatus for connecting tubulars using a top drive|
|US6527493||5 Dec 1997||4 Mar 2003||Varco I/P, Inc.||Handling of tube sections in a rig for subsoil drilling|
|US6679333 *||26 Oct 2001||20 Jan 2004||Canrig Drilling Technology, Ltd.||Top drive well casing system and method|
|US6688398||29 Jan 2003||10 Feb 2004||Weatherford/Lamb, Inc.||Method and apparatus for connecting tubulars using a top drive|
|US6705405||16 Aug 1999||16 Mar 2004||Weatherford/Lamb, Inc.||Apparatus and method for connecting tubulars using a top drive|
|US6722443||9 Aug 1999||20 Apr 2004||Weatherford/Lamb, Inc.||Connector for expandable well screen|
|US6896057||19 Apr 2004||24 May 2005||Weatherford/Lamb, Inc.||Connector for expandable well screen|
|US6938709||3 Jul 2002||6 Sep 2005||Varco International, Inc.||Pipe running tool|
|US6976298||16 Aug 1999||20 Dec 2005||Weatherford/Lamb, Inc.||Methods and apparatus for connecting tubulars using a top drive|
|US6981547||6 Dec 2002||3 Jan 2006||Weatherford/Lamb, Inc.||Wire lock expandable connection|
|US7017950||24 Sep 2003||28 Mar 2006||Weatherford/Lamb, Inc.||Expandable connection|
|US7021374||17 Dec 2003||4 Apr 2006||Weatherford/Lamb, Inc.||Method and apparatus for connecting tubulars using a top drive|
|US7025135||22 May 2003||11 Apr 2006||Weatherford/Lamb, Inc.||Thread integrity feature for expandable connections|
|US7096977||20 Jan 2005||29 Aug 2006||Varco I/P, Inc.||Pipe running tool|
|US7107663||12 Sep 2003||19 Sep 2006||Weatherford/Lamb, Inc.||Expandable coupling|
|US7140443||10 Nov 2003||28 Nov 2006||Tesco Corporation||Pipe handling device, method and system|
|US7140446||10 May 2005||28 Nov 2006||Weatherford/ Lamb, Inc.||Connector for expandable well screen|
|US7188686 *||7 Jun 2004||13 Mar 2007||Varco I/P, Inc.||Top drive systems|
|US7222683 *||16 Jun 2004||29 May 2007||Varco I/P, Inc.||Wellbore top drive systems|
|US7225523||30 Dec 2005||5 Jun 2007||Weatherford/Lamb, Inc.||Method for coupling and expanding tubing|
|US7228913 *||18 Jun 2004||12 Jun 2007||Varco I/P, Inc.||Tubular clamp apparatus for top drives and methods of use|
|US7231969 *||24 Jun 2004||19 Jun 2007||Varco I/P, Inc.||Wellbore top drive power systems and methods of use|
|US7240928||17 Sep 2003||10 Jul 2007||Weatherford/Lamb, Inc.||Tubing connection arrangement|
|US7281587||30 Mar 2006||16 Oct 2007||Weatherford/Lamb, Inc.||Apparatus and methods for tubular makeup interlock|
|US7320374 *||28 May 2005||22 Jan 2008||Varco I/P, Inc.||Wellbore top drive systems|
|US7353880||15 Nov 2006||8 Apr 2008||Weatherford/Lamb, Inc.||Method and apparatus for connecting tubulars using a top drive|
|US7377324||14 Aug 2006||27 May 2008||Tesco Corporation||Pipe handling device, method and system|
|US7448456||1 Feb 2006||11 Nov 2008||Weatherford/Lamb, Inc.||Adjustable rotating guides for spider or elevator|
|US7451826||15 Aug 2006||18 Nov 2008||Weatherford/Lamb, Inc.||Apparatus for connecting tubulars using a top drive|
|US7472762||6 Dec 2006||6 Jan 2009||Varco I/P, Inc.||Top drive oil flow path seals|
|US7510006||24 Jun 2005||31 Mar 2009||Varco I/P, Inc.||Pipe running tool having a cement path|
|US7513300||20 Mar 2007||7 Apr 2009||Weatherford/Lamb, Inc.||Casing running and drilling system|
|US7578043||8 Jun 2006||25 Aug 2009||Weatherford/Lamb, Inc.||Coupling tubulars|
|US7591304||24 Jun 2005||22 Sep 2009||Varco I/P, Inc.||Pipe running tool having wireless telemetry|
|US7654313||8 Feb 2007||2 Feb 2010||Tesco Corporation||Method and assembly for casing handling using a kelly rig|
|US7654325||31 Oct 2007||2 Feb 2010||Weatherford/Lamb, Inc.||Methods and apparatus for handling and drilling with tubulars or casing|
|US7665531||15 Nov 2006||23 Feb 2010||Weatherford/Lamb, Inc.||Apparatus for facilitating the connection of tubulars using a top drive|
|US7669662||20 Jul 2005||2 Mar 2010||Weatherford/Lamb, Inc.||Casing feeder|
|US7673675||9 May 2006||9 Mar 2010||Tesco Corporation||Pipe handling device and safety mechanism|
|US7694744||12 Jan 2006||13 Apr 2010||Weatherford/Lamb, Inc.||One-position fill-up and circulating tool and method|
|US7699121||24 Jun 2005||20 Apr 2010||Varco I/P, Inc.||Pipe running tool having a primary load path|
|US7712523||14 Mar 2003||11 May 2010||Weatherford/Lamb, Inc.||Top drive casing system|
|US7753138||24 Jun 2005||13 Jul 2010||Varco I/P, Inc.||Pipe running tool having internal gripper|
|US7757759||27 Apr 2007||20 Jul 2010||Weatherford/Lamb, Inc.||Torque sub for use with top drive|
|US7770654||23 May 2008||10 Aug 2010||Tesco Corporation||Pipe handling device, method and system|
|US7793719||31 Oct 2007||14 Sep 2010||Weatherford/Lamb, Inc.||Top drive casing system|
|US7845418||18 Jan 2006||7 Dec 2010||Weatherford/Lamb, Inc.||Top drive torque booster|
|US7874352||12 Dec 2006||25 Jan 2011||Weatherford/Lamb, Inc.||Apparatus for gripping a tubular on a drilling rig|
|US7882902||15 Nov 2007||8 Feb 2011||Weatherford/Lamb, Inc.||Top drive interlock|
|US7887103||7 Feb 2007||15 Feb 2011||Watherford/Lamb, Inc.||Energizing seal for expandable connections|
|US7895726||18 May 2004||1 Mar 2011||Weatherford/Lamb, Inc.||Tubing connector and method of sealing tubing sections|
|US7896084||15 Oct 2007||1 Mar 2011||Weatherford/Lamb, Inc.||Apparatus and methods for tubular makeup interlock|
|US7918273||23 Jan 2003||5 Apr 2011||Weatherford/Lamb, Inc.||Top drive casing system|
|US8002048 *||3 Sep 2008||23 Aug 2011||Bauer Maschinen Gmbh||Drilling implement and method for operating a drilling implement|
|US8037932||6 Jan 2010||18 Oct 2011||Tesco Corporation||Pipe handling device and safety mechanism|
|US8037949||16 Apr 2010||18 Oct 2011||Varco I/P, Inc.||Pipe running tool|
|US8136216||14 Jul 2009||20 Mar 2012||Weatherford/Lamb, Inc.||Method of coupling expandable tubing sections|
|US8210268||12 Dec 2008||3 Jul 2012||Weatherford/Lamb, Inc.||Top drive system|
|US8230933||1 Apr 2011||31 Jul 2012||Weatherford/Lamb, Inc.||Top drive casing system|
|US8251151||17 Feb 2011||28 Aug 2012||Weatherford/Lamb, Inc.||Apparatus and methods for tubular makeup interlock|
|US8365834||4 May 2009||5 Feb 2013||Weatherford/Lamb, Inc.||Tubular handling apparatus|
|US8517090||1 Aug 2012||27 Aug 2013||Weatherford/Lamb, Inc.||Apparatus and methods for tubular makeup interlock|
|US8567512||19 Jan 2011||29 Oct 2013||Weatherford/Lamb, Inc.||Apparatus for gripping a tubular on a drilling rig|
|US8708055||15 Feb 2013||29 Apr 2014||Weatherford/Lamb, Inc.||Apparatus and methods for wedge lock prevention|
|US8727021||26 Apr 2012||20 May 2014||Weatherford/Lamb, Inc.||Top drive system|
|US8752636||29 Jan 2013||17 Jun 2014||Weatherford/Lamb, Inc.||Tubular handling apparatus|
|US8807207 *||24 Apr 2014||19 Aug 2014||Larry G. Keast||Power swivel with tilt system|
|US8807208 *||24 Apr 2014||19 Aug 2014||Larry G. Keast||Method for using a power swivel with tilt|
|US9010410||8 May 2012||21 Apr 2015||Max Jerald Story||Top drive systems and methods|
|US20040017081 *||3 Jul 2003||29 Jan 2004||Simpson Neil Andrew Abercrombie||Coupling tubulars|
|US20040104575 *||12 Sep 2003||3 Jun 2004||Peter Ellington||Expandable coupling|
|US20040108119 *||6 Dec 2002||10 Jun 2004||Maguire Patrick G.||Wire lock expandable connection|
|US20040135370 *||17 Sep 2003||15 Jul 2004||Evans Jason David||Tubing connection arrangement|
|US20040149451 *||17 Dec 2003||5 Aug 2004||Weatherford/Lamb, Inc.||Method and apparatus for connecting tubulars using a top drive|
|US20040194968 *||19 Apr 2004||7 Oct 2004||Weatherford/Lamb, Inc.||Connector for expandable well screen|
|US20040231839 *||22 May 2003||25 Nov 2004||Peter Ellington||Thread integrity feature for expandable connections|
|US20050098352 *||10 Nov 2003||12 May 2005||Tesco Corporation.||Pipe handling device, method and system|
|US20050199385 *||10 May 2005||15 Sep 2005||Weatherford/Lamb, Inc.||Connector for expandable well screen|
|US20050269072 *||24 Jun 2004||8 Dec 2005||Folk Robert A||Wellbore top drive power systems & methods of use|
|US20050269104 *||7 Jun 2004||8 Dec 2005||Folk Robert A||Top drive systems|
|US20050274508 *||28 May 2005||15 Dec 2005||Folk Robert A||Wellbore top drive systems|
|US20050279492 *||16 Jun 2004||22 Dec 2005||Folk Robert A||Wellbore top drive systems|
|US20050279507 *||18 Jun 2004||22 Dec 2005||Folk Robert A||Tubular clamp apparatus for top drives & methods of use|
|US20060005962 *||20 Jan 2005||12 Jan 2006||Varco International, Inc.||Pipe running tool|
|US20060107514 *||30 Dec 2005||25 May 2006||Weatherford Lamb, Inc.||Expandable slotted tubing string and method for connecting such a tubing string|
|US20060118293 *||24 Jun 2005||8 Jun 2006||Daniel Juhasz||Pipe running tool having internal gripper|
|US20060124293 *||24 Jun 2005||15 Jun 2006||Daniel Juhasz||Pipe running tool having a primary load path|
|US20060124305 *||24 Jun 2005||15 Jun 2006||Daniel Juhasz||Pipe running tool having a cement path|
|US20060124353 *||24 Jun 2005||15 Jun 2006||Daniel Juhasz||Pipe running tool having wireless telemetry|
|USRE29541 *||16 Nov 1976||21 Feb 1978||Western Gear Corporation||Hydraulic drilling rig and power swivel|
|EP0311455A1 *||10 Oct 1988||12 Apr 1989||W-N Apache Corporation||Compact casing tongs for use on top head drive earth drilling machine|
|EP1103695A2 *||20 Nov 2000||30 May 2001||Compagnie Du Sol||Device for mounting a drilling tool on a mast|
|WO1996018799A1 *||18 Dec 1995||20 Jun 1996||Lucas Brian Ronald||Method and apparatus for connecting and disconnecting tubulars|
|WO1999030000A1 *||5 Dec 1997||17 Jun 1999||Boettger Dietrich||Handling of tube sections in a rig for subsoil drilling|
|WO2000011310A1 *||16 Aug 1999||2 Mar 2000||Harding Richard Patrick||An apparatus for connecting tubulars using a top drive|
|WO2003038229A2 *||23 Oct 2002||8 May 2003||Canrig Drilling Tech Ltd||Top drive well casing system and method|
|U.S. Classification||173/20, 175/85, 173/197, 173/164|
|International Classification||E21B19/00, E21B19/20, E21B3/02, E21B3/00|
|Cooperative Classification||E21B19/20, E21B3/02|
|European Classification||E21B3/02, E21B19/20|
|5 Apr 1982||AS||Assignment|
Owner name: HUGHES TOOL COMPANY A CORP. OF DE
Free format text: MERGER;ASSIGNOR:BROWN OIL TOOLS, INC. A TX CORP.;REEL/FRAME:003967/0348
Effective date: 19811214