US3766991A - Electric power swivel and system for use in rotary well drilling - Google Patents

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.

Description

United States Patent 1 Brown Oct. 23, 1973 ELECTRIC POWER SWIVEL AND SYSTEM FOR USE IN ROTARY WELL DRILLING [76] Inventor: Cicero C. Brown, c/o Brown Oil Tool, Inc., PO. Box 19236, Houston, Tex. 77024 [22] Filed: Apr. 2, 1971 [21] 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 [57] 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 3.766391SHEET 10E 6 PATENTED URI 2 3 I913 sum 2 or s AT TOENE) PAIENIEnum 23 ms 3.766591sum 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 online 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 ahollow casing 10 of inverted generally frusto-conical shape defining an enclosure 11 closed at its upper end by acap plate 12 removably secured to the upper end of'the casing by bolts 13 (FIG. 2) and communicating with anaxial bore 14 opening throughthroat portion 10a defining the lower end of the casing. An electric motor, designated generally by the letter M, is vertically mounted centrally oncap plate 12 and removably secured thereto bycap 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 ahollow drive shaft 16, suitably supported for rotation in the vertical position .and having an axial bore 16a.

Atubular swivel stem 17 extends throughbore 14 and carries a horizontally extendingannular head 18 at its upper end. The lower end ofstem 17 projects from thelower end ofcasing 10 and is provided with a threadedpin 17a for connection to other tools, as will appear subsequently.Head 18 is rotatably supported onroller 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 facingshoulder 21 incasing 10.Roller bearings 22 are mounted betweenswivel stem 17 and the wall ofthroat portion 10a at a point belowshoulder 21 and are held in place by atubular bushing 23 which also defines a packing space containing seal packing 24 for sealing off betweenswivel stem 17 and bushing 23. Atubular cap 25 surrounds the portion of the swivel stem extending below the lower end ofthroat portion 10a and is secured to the latter by means ofcap screws 26 which extend through the flange 2311 onbushing 23 and thereby serve to also securebushing 23,bearings 22 and seal packing 24 in place about the swivel stem.

Swivelstem 17 is rotatably driven bymotor shaft 16 through a train of gears which includes anannular pinion 26 mounted on ahub sleeve 27 which is suitably secured coaxially to the lower end ofshaft 16; a set of threeplanetary gears 28 in mesh withpinion 26 and rotatably mounted about enlargedhubs 29 which are secured to head 18 by means ofcap screws 30. The planetary gears are in mesh with asun gear 31 seated against the inner wall ofcasing 10 near its upper end and secured tocap plate 12 by means ofcap screws 32.

Casing 10 is formed with a pair of laterally extendingears 33,33 spaced apart and having vertically extendingbores 34,34 therethrough. Capplate 12 hassimilar ears 35,35 overlyingears 33, 33 and provided withbores 36,36 registering withbores 34, 34.Tubular sleeve 37,37 having axial through-bores 38,38- are screwed into the lower ends ofbores 34,34. Each of thebores 38 defines apressurecylinder 38a adpated to receive apiston 39 formed with alower head 40 fitted with seal rings -41 and 42 for'slidable sealing engagement with the wall ofbore 38. Piston 39 extends upwardly throughbores 34 and 36 which are provided withrespective packings 43 and 44 sealing with the piston to close the upper ends of the cylinders. The upper end portions ofpistons 39 which project abovecap plate 12 are provided with externally threadedpins 45 which are screwed intohanger caps 46. The latter have upwardly extendinglugs 47 which are received inclevises 48 and pivotally secured thereto by means of transversely extendingpivot pins 49. The clevises are .se-

cured to the opposite ends of a bail 50 (FIG. 1A) by.

ized by a body of an inertpneumatic fluid 54a such as' nitrogen gas.

A tubular mandrel extends upwardly through the bore ofswivel 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 ofhub sleeve 27 and bore 160 ofmotor shaft 16 and thence through a'swivelhousing 62. A swivel bushing 63 (FIG. 1A) is threadedly secured to the upper end ofmandrel 60 and is provided with a suitablerotary connection 64 to the upper end ofswivel 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 ofmandrel 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 ofweb 20a of I-I-beam 20, the leads 71 of the gauges being brought outsidecasing 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 ofcars 33 are fitted withtrunions 72 journalled in the ends of guide arms 73 (FIGS. 1B, 2, and 11) which connectguide sleeves 74 disposed for sliding movement on vertically disposedguide 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 abore 85a and threadedly connected to a threaded pin formed on ahead 86 having anaxial bore 86a, the upper end of which is provided with a threadedsocket 87 adapted to receivepin 17a of the swivel stem. The latter is provided withlongitudinal passages 88 and 88a in its wall communicating at their upper. ends withspaced ports 89 and 90 respectively'incap 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 abovepin 17a passages 88a and communicate respectively withspaced ports 93 and 94 which communicate, respectively, withconduits 95 and 96 extending through head'86 and a reduceddiameter I extension 97 thereof into communication with spaced points in acylinder 98 defined between the wall ofbore 85a andextension 97. I v

A set of angularly spacedlugs 99 are mounted for limited radial movement through correspondingly shapedradial slots 100 in the lower end ofextension 97.Lugs 99 are resiliently biased outwardly by means ofsprings 101 arranged betweenextensions 102 on the upper and lower ends of the lugs and opposed portions of the lower end ofextension 97. Asleeve piston 103 is slidably mounted incylinder 98 and is secured to the upper end ofaskirt 104 which extends downwardly between the wall ofbore 85a and the exterior ofextension 97, the skirt-being movable downwardly behindlugs 99 to urge the latter inwardly against the opposition ofsprings 101. The arrangement is such that when pressure fluid is introduced throughconduit 96 above piston. 103 forcing the latter downwardly,skirt 104 will forcelugs 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 andcasing 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 acylinder 76 hingedly connected at 77 to the side of travelling block B and enclosing apiston 78 having its free end hingedly connected tocasing 10.

A connection for the end of piston 78 'tocasing 10 is shown in FIGS. 2 and 10 to 14, and comprises ahinge lug 79 projecting radially outwardly from casing 10 at the mid point betweenears 33,33.Lug 79 is adapted to be received in aclevis 80 carried by the outer end ofpiston 78 and is hingedly secured thereto by atransverse hinge pin 81.

FIGS. 3 to 7, inclusive, illustrate an overshot form of a connector device, designated generally by theletter 0, for drivingly connectingswivel 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 ofarcuate recesses 106 are provided in opposite portions of the innerwall ofextension 97. A pair of arcuate cam shoes 107 having toothedinner faces 108 are rockably mounted onshafts 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' alignconnector 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 oflugs 99 by means of pressure fluid supplied throughpassages 88 and 96 tocylinder 98 to movepisshoes 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 throughconduits 88a and 95 to raisepiston 103 andskirt 104. Subsequently, raising of the power swivel will pullconnector 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 throughgoose 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 bycylinders 38a andpistons 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 incylinders 38a by the pressurized fluid inreservoir 53 will be sufficient to holdpistons 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 inreservoir 53 andcylinders 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 andpistons 39 secured thereto, the pistons moving up incylinders 38a as the pressurizing fluid inreservoir 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 ofpistons 39 under the cushioningpressure of the pressurizing fluid inreservoir 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 occurspistons 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 betweenhead 18 andcasing 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 onweb 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 toclaim 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 inclaim 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 inclaim 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 inclaim 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 inclaim 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 inclaim 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 inclaim 17 wherein said rotary drive means includes a reversible electric motor means.

19. An assembly as defined inclaim 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

Claims (26)

1. A power swivel for use in rotary well drilling, comprising: a. a housing; b. a tubular swivel stem rotatably mounted in the housing; c. a reversible electric power motor mounted on the housing and having a tubular drive shaft coaxial with said swivel stem; d. 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. In a 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 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 stem 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; 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 15 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 said well pipe for transmitting torque thereto; e. a tubular housing included in said connector to coaxially 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; c. 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 for forming a sealing engagement between said tubular stem means and said tubular members; f. vertical drive means for moving said rotary drive means vertically through said support means; and g. orienting means for varying the angle of inclination of said stem means.

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