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CROSS-REFERENCE TO RELATED APPLICATIONS 
       [0001]    This is a continuation of U.S. patent application Ser. No. 11/831,475, filed Jul. 31, 2007 (issuing as U.S. Pat. No. 7,500,518 on Mar. 10, 2009), which was a continuation of co-pending U.S. patent application Ser. No. 11/371,168, filed Mar. 7, 2006 (now U.S. Pat. No. 7,249,632), which was a continuation of U.S. patent application Ser. No. 10/658,092, filed Sep. 9, 2003 (now U.S. Pat. No. 7,007,753), which claimed priority of Provisional Patent Application Ser. No. 60/409,177, filed Sep. 9, 2002. Each of these applications are incorporated herein by reference. Priority of each of these applications is hereby claimed. 
     
    
     STATEMENT REGARDING FEDERALLY SPONSORED RESEARCH OR DEVELOPMENT 
       [0002]    Not applicable 
       REFERENCE TO A “MICROFICHE APPENDIX” 
       [0003]    Not applicable 
       BACKGROUND 
       [0004]    In top drive rigs, the use of a top drive unit, or top drive power unit is employed to rotate drill pipe, or well string in a well bore. Top drive rigs can include spaced guide rails and a drive frame movable along the guide rails and guiding the top drive power unit. The travelling block supports the drive frame through a hook and swivel, and the driving block is used to lower or raise the drive frame along the guide rails. For rotating the drill or well string, the top drive power unit includes a motor connected by gear means with a rotatable member both of which are supported by the drive frame. 
         [0005]    During drilling operations, when it is desired to “trip” the drill pipe or well string into or out of the well bore, the drive frame can be lowered or raised. Additionally, during servicing operations, the drill string can be moved longitudinally into or out of the well bore. 
         [0006]    The stem of the swivel communicates with the upper end of the rotatable member of the power unit in a manner well known to those skilled in the art for supplying fluid, such as a drilling fluid or mud, through the top drive unit and into the drill or work string. The swivel allows drilling fluid to pass through and be supplied to the drill or well string connected to the lower end of the rotatable member of the top drive power unit as the drill string is rotated and/or moved up and down. 
         [0007]    Top drive rigs also can include elevators are secured to and suspended from the frame, the elevators being employed when it is desired to lower joints of drill string into the well bore, or remove such joints from the well bore. 
         [0008]    At various times top drive operations, beyond drilling fluid, require various substances to be pumped downhole, such as cement, chemicals, epoxy resins, or the like. In many cases it is desirable to supply such substances at the same time as the top drive unit is rotating and/or moving the drill or well string up and/or down, but bypassing the top drive&#39;s power unit so that the substances do not damage/impair the unit. Additionally, it is desirable to supply such substances without interfering with and/or intermittently stopping longitudinal and/or rotational movement by the top drive unit of the drill or well string. 
         [0009]    A need exists for a device facilitating insertion of various substances downhole through the drill or well string, bypassing the top drive unit, while at the same time allowing the top drive unit to rotate and/or move the drill or well string. 
         [0010]    One example includes cementing a string of well bore casing. In some casing operations it is considered good practice to rotate the string of casing when it is being cemented in the wellbore. Such rotation is believed to facilitate better cement distribution and spread inside the annular space between the casing&#39;s exterior and interior of the well bore. In such operations the top drive unit can be used to both support and continuouslyrotate/intermittently reciprocate the string of casing while cement is pumped down the string&#39;s interior. During this time it is desirable to by-pass the top drive unit to avoid possible damage to any of its portions or components. 
         [0011]    The following U.S. patents are incorporated herein by reference: U.S. Pat. No. 4,722,389. 
         [0012]    While certain novel features of this invention shown and described below are pointed out in the annexed claims, the invention is not intended to be limited to the details specified, since a person of ordinary skill in the relevant art will understand that various omissions, modifications, substitutions and changes in the forms and details of the device illustrated and in its operation may be made without departing in anyway from the spirit of the present invention. No feature of the invention is critical or essential unless it is expressly stated as being “critical” or “essential.” 
       BRIEF SUMMARY 
       [0013]    The apparatus of the present invention solves the problems confronted in the art in a simple and straightforward manner. The invention herein broadly relates to an assembly having a top drive arrangement for rotating and longitudinally moving a drill or well string. In one embodiment the present invention includes a swivel apparatus, the swivel generally comprising a mandrel and a sleeve, the swivel being especially useful for top drive rigs. 
         [0014]    The sleeve can be rotatably and sealably connected to the mandrel. The swivel can be incorporated into a drill or well string and enabling string sections both above and below the sleeve to be rotated in relation to the sleeve. Additionally, the swivel provides a flow path between the exterior of the sleeve and interior of the mandrel while the drill string is being moved in a longitudinal direction (up or down) and/or being rotated/reciprocated. The interior of the mandrel can be fluidly connected to the longitudinal bore of casing or drill string thus providing a path from the sleeve to the interior of the casing/drill string. 
         [0015]    In one embodiment an object of the present invention is to provide a method and apparatus for servicing a well wherein a swivel is connected to and below a top drive unit for conveying pumpable substances from an external supply through the swivel for discharge into the well string, but bypassing the top drive unit. 
         [0016]    In another embodiment of the present invention is provided a method of conducting servicing operations in a well bore, such as cementing, comprising the steps of moving a top drive unit longitudinally and/or rotationally to provide longitudinal movement and/or rotation/reciprocation in the well bore of a well string suspended from the top drive unit, rotating the drill or well string and supplying a pumpable substance to the well bore in which the drill or well string is manipulated by introducing the pumpable substance at a point below the top drive power unit and into the well string. 
         [0017]    In other embodiments of the present invention a swivel placed below the top drive unit can be used to perform jobs such as spotting pills, squeeze work, open formation integrity work, kill jobs, fishing tool operations with high pressure pumps, sub-sea stack testing, rotation of casing during side tracking, and gravel pack or frack jobs. In still other embodiments a top drive swivel can be used in a method of pumping loss circulation material (LCM) into a well to plug/seal areas of downhole fluid loss to the formation and in high speed milling jobs using cutting tools to address down hole obstructions. In other embodiments the top drive swivel can be used with free point indicators and shot string or cord to free stuck pipe where pumpable substances are pumped downhole at the same time the downhole string/pipe/free point indicator is being rotated and/or reciprocated. In still other embodiments the top drive swivel can be used for setting hook wall packers and washing sand. 
         [0018]    In still other embodiments the top drive swivel can be used for pumping pumpable substances downhole when repairs/servicing is being done to the top drive unit and rotation of the downhole drill string is being accomplished by the rotary table. Such use for rotation and pumping can prevent sticking/seizing of the drill string downhole. In this application safety valves, such as TIW valves, can be placed above and below the top drive swivel to enable routing of fluid flow and to ensure well control. 
         [0019]    The drawings constitute a part of this specification and include exemplary embodiments to the invention, which may be embodied in various forms. 
     
    
     
       BRIEF DESCRIPTION OF THE SEVERAL VIEWS OF THE DRAWINGS 
         [0020]    For a further understanding of the nature, objects, and advantages of the present invention, reference should be had to the following detailed description, read in conjunction with the following drawings, wherein like reference numerals denote like elements and wherein: 
           [0021]      FIG. 1  is a schematic view showing a top drive rig with one embodiment of a top drive swivel incorporated in the drill string; 
           [0022]      FIG. 2  is a schematic view of one embodiment of a top drive swivel; 
           [0023]      FIG. 3  is a sectional view of a mandrel which can be incorporated in the top drive swivel of  FIG. 2 ; 
           [0024]      FIG. 4  is a sectional view of a sleeve which can be incorporated into the top drive swivel of  FIG. 2 ; 
           [0025]      FIG. 5  is a right hand side view of the sleeve of  FIG. 4 ; 
           [0026]      FIG. 6  is a sectional view of the top drive swivel of  FIG. 2 ; 
           [0027]      FIG. 6A  is a sectional view of the packing unit shown in  FIG. 6 ; 
           [0028]      FIG. 6B  is a top view of the packing injection ring shown in  FIGS. 6 and 6A ; 
           [0029]      FIG. 6C  is a side view section of the packing injection ring shown in  FIG. 6B ; 
           [0030]      FIG. 7  is a top view of a clamp which can be incorporated into the top drive swivel of  FIG. 2 ; 
           [0031]      FIG. 8  is a side view of the clamp of  FIG. 7 ; 
           [0032]      FIG. 9  is a perspective view and partial sectional view of the top drive swivel shown in  FIG. 2 . 
       
    
    
     DETAILED DESCRIPTION 
       [0033]    Detailed descriptions of one or more preferred embodiments are provided herein. It is to be understood, however, that the present invention may be embodied in various forms. Therefore, specific details disclosed herein are not to be interpreted as limiting, but rather as a basis for the claims and as a representative basis for teaching one skilled in the art to employ the present invention in any appropriate system, structure or manner. 
         [0034]      FIG. 1  is a schematic view showing a top drive rig  1  with one embodiment of a top drive swivel  30  incorporated into drill string  20 .  FIG. 1  is shows a rig  1  having a top drive unit  10 . Rig  5  comprises supports  16 , 17 ; crown block  2 ; traveling block  4 ; and hook  5 . Draw works  11  uses cable  12  to move up and down traveling block  4 , top drive unit  10 , and drill string  20 . Traveling block  4  supports top drive unit  10 . Top drive unit  10  supports drill string  20 . 
         [0035]    During drilling operations, top drive unit  10  can be used to rotate drill string  20  which enters wellbore  14 . Top drive unit  10  can ride along guide rails  15  as unit  10  is moved up and down. Guide rails  15  prevent top drive unit  10  itself from rotating as top drive unit  10  rotates drill string  20 . During drilling operations drilling fluid can be supplied downhole through drilling fluid line  8  and gooseneck  6 . 
         [0036]    At various times top drive operations, beyond drilling fluid, require substances to be pumped downhole, such as cement, chemicals, epoxy resins, or the like. In many cases it is desirable to supply such substances at the same time as top drive unit  10  is rotating and/or moving drill or well string  20  up and/or down and bypassing top drive unit  10  so that the substances do not damage/impair top drive unit  10 . Additionally, it is desirable to supply such substances without interfering with and/or intermittently stopping longitudinal and/or rotational movements of drill or well string  20  being moved/rotated by top drive unit  10 . This can be accomplished by using top drive swivel  30 . 
         [0037]    Top drive swivel  30  can be installed between top drive unit  10  and drill string  20 . One or more joints of drill pipe  18  can be placed between top drive unit  10  and swivel  30 . Additionally, a valve can be placed between top drive swivel  30  and top drive unit  10 . Pumpable substances can be pumped through hose  31 , swivel  30 , and into the interior of drill string  20  thereby bypassing top drive unit  10 . Top drive swivel  30  is preferably sized to be connected to drill string  20  such as 4½ inch IF API drill pipe or the size of the drill pipe to which swivel  30  is connected to. However, cross-over subs can also be used between top drive swivel  30  and connections to drill string  20 . 
         [0038]      FIG. 2  is a schematic view of one embodiment of a top drive swivel  30 . Top drive swivel  30  can be comprised of mandrel  40  and sleeve  150 . Sleeve  150  is rotatably and sealably connected to mandrel  30 . Accordingly, when mandrel  40  is rotated, sleeve  150  can remain stationary to an observer insofar as rotation is concerned. As will be discussed later inlet  200  of sleeve  150  is and remains fluidly connected to a the central longitudinal passage  90  of mandrel  40 . Accordingly, while mandrel  40  is being rotated and/or moved up and down pumpable substances can enter inlet  20  and exit central longitudinal passage  90  at lower end  60  of mandrel  40 . 
         [0039]      FIG. 3  is a sectional view of mandrel  40  which can be incorporated in the top drive swivel  30 . Mandrel  40  is comprised of upper end  50  and lower end  60 . Central longitudinal passage  90  extends from upper end  50  through lower end  60 . Lower end  60  can include a pin connection or any other conventional connection. Upper end  50  can include box connection  70  or any other conventional connection. Mandrel  40  can in effect become a part of drill string  20 . Sleeve  150  fits over mandrel  40  and becomes rotatably and sealably connected to mandrel  40 . Mandrel  40  can include shoulder  100  to supper sleeve  150 . Mandrel  40  can include one or more radial inlet ports  140  fluidly connecting central longitudinal passage  90  to recessed area  130 . Recessed area  130  preferably forms a circumferential recess along the perimeter of mandrel  40  and between packing support areas  131 , 132 . In such manner recessed area will remain fluidly connected with radial passage  190  and inlet  200  of sleeve  150  (see  FIGS. 4 ,  6 ). 
         [0040]    To reduce friction between mandrel  40  and packing units  305 , 415  ( FIG. 6 ) and increase the life expectancy of packing units  305 ,  415 , packing support areas  131 ,  132  can be coated and/or sprayed welded with a materials of various compositions, such as hard chrome, nickel/chrome or nickel/aluminum (95 percent nickel and 5 percent aluminum) A material which can be used for coating by spray welding is the chrome alloy TAFA 95 MX Ultrahard Wire (Armacor M) manufactured by TAFA Technologies, Inc., 146 Pembroke Road, Concord N.H. TAFA 95 MX is an alloy of the following composition: Chromium 30 percent; Boron 6 percent; Manganese 3 percent; Silicon 3 percent; and Iron balance. The TAFA 95 MX can be combined with a chrome steel. Another material which can be used for coating by spray welding is TAFA BONDARC WIRE-75B manufactured byTAFA Technologies, Inc. TAFA BONDARC WIRE-75B is an alloy containing the following elements: Nickel 94 percent; Aluminum 4.6 percent; Titanium 0.6 percent; Iron 0.4 percent; Manganese 0.3 percent; Cobalt 0.2 percent; Molybdenum 0.1 percent; Copper 0.1 percent; and Chromium 0.1 percent. Another material which can be used for coating by spray welding is the nickel chrome alloy TAFALOY NICKEL-CHROME-MOLY WIRE-71T manufactured by TAFA Technologies, Inc. TAFALOY NICKEL-CHROME-MOLY WIRE-71T is an alloy containing the following elements: Nickel 61.2 percent; Chromium 22 percent; Iron 3 percent; Molybdenum 9 percent; Tantalum 3 percent; and Cobalt 1 percent. Various combinations of the above alloys can also be used for the coating/spray welding. Packing support areas  131 ,  132  can also be coated by a plating method, such as electroplating. The surface of support areas  131 ,  132  can be ground/polished/finished to a desired finish to reduce friction and wear between support areas  131 ,  132  and packing units  305 ,  415 . 
         [0041]      FIG. 4  is a sectional view of sleeve  150  which can be incorporated into top drive swivel  30 .  FIG. 5  is a right hand sectional view of sleeve  150  taken along the lines  4 - 4 . Sleeve  150  can include central longitudinal passage  180  extending from upper end  160  through lower end  170 . Sleeve  150  can also include radial passage  190  and inlet  200 . Inlet  200  can be attached by welding or any other conventional type method of fastening such as a threaded connection. If welded the connection is preferably heat treated to remove residual stresses created by the welding procedure. Also shown is protruding section  155  along with upper and lower shoulders  156 , 157 . Lubrication port  210  can be included to provide lubrication for interior bearings. Packing ports  220 ,  230  can also be included to provide the option of injecting packing material into the packing units  305 , 415  (see  FIG. 6 ). A protective cover  240  can be placed around packing port  230  to protect packing injector  235  (see  FIG. 6 ). Optionally, a second protective cover can be placed around packing port  220 , however, it is anticipated that protection will be provided by clamp  600  and inlet  200 . Sleeve  150  can include peripheral groove  205  for attachment of clamp  600 . Additionally, key way  206  can be provided for insertion of a key  700 .  FIG. 5  illustrates how central longitudinal passage  180  is fluidly connected to inlet  200  through radial passage  190 . It is preferred that welding be performed using Preferred Industries Welding Procedure number T3, 155OREV-A 4140HT (285/311 bhn) RMT to 4140 HT (285/311 bhn(RMT) It is also preferred that welds be X-ray tested, magnetic particle tested, and stress relieved. 
         [0042]      FIG. 6  is a sectional view of the assembled top drive swivel  30  of  FIG. 2 . As can be seen sleeve  150  slides over mandrel  40 . Bearings  145 ,  146  rotatably connect sleeve  150  to mandrel  40 . Bearings  145 ,  146  are preferably thrust bearings although many conventionally available bearing will adequately function, including conical and ball bearings. Packing units  305 ,  415  sealingly connect sleeve  150  to mandrel  40 . Inlet  200  of sleeve  150  is and remains fluidly connected to central longitudinal passage  90  of mandrel  40 . Accordingly, while mandrel  40  is being rotated and/ormoved up and down pumpable substances can enter inlet  200  and exit central longitudinal passage  90  at lower end  60  of mandrel  40 . Recessed area  130  and protruding section  155  form a peripheral recess between mandrel  40  and sleeve  150 . The fluid pathway from inlet  200  to outlet at lower end  60  of central longitudinal passage  90  is as follows: entering inlet  200  (arrow  201 ); passing through radial passage  190  (arrow  202 ); passing through recessed area  130  (arrow  202 ); passing through one of the plurality of radial inlet ports  140  (arrow  202 ), passing through central longitudinal passage  90  (arrow  203 ); and exiting mandrel  40  via lower end  60  at pin connection  80  (arrows  204 ,  205 ). 
         [0043]      FIG. 6A  shows a blown up schematic view of packing unit  305 . Packing unit  305  can comprise packing end  320 ; packing ring  330 , packing ring  340 , packing lubrication ring  350 , packing end  360 , packing ring  370 , packing ring  380 , packing ring  390 , packing ring  400 , and packing end  410 . Packing unit  305  sealing connects mandrel  40  and sleeve  150 . Packing unit  305  can be encased by packing retainer nut  310  and shoulder  156  of protruding section  155 . Packing retainer nut  310  can be a ring which threadably engages sleeve  150  at threaded area  316 . Packing retainer nut  310  and shoulder  156  squeeze packing unit  305  to obtain a good seal between mandrel  40  and sleeve  150 . Set screw  315  can be used to lock packing retainer nut  310  in place and prevent retainer nut  310  from loosening during operation. Set screw  315  can be threaded into bore  314  and lock into receiving area  317  on sleeve  150 . Packing unit  415  can be constructed substantially similar to packing unit  305 . The materials for packing unit  305  and packing unit  415  can be similar. 
         [0044]    Packing end  320  is preferably a bronze female packing end. Packing ring  330  is preferably a “Vee” packing ring—Teflon such as that supplied by CDI part number 0500700-VS-720 Carbon Reflon (having 2 percent carbon). Packing ring  340  is preferably a “Vee” packing ring—Rubber such as that supplied by CDI part number 0500700-VS-850NBR Aramid. Packing lubrication ring  350  is described below in the discussion regarding  FIGS. 6B and 6C . Packing end  360  preferably a bronze female packing end. Packing ring  370  is preferably a “Vee” packing ring—Teflon such as that supplied by CDI part number 0500700-VS-720 Carbon Reflon (having 2 percent carbon). Packing ring  380  is preferably a “Vee” packing ring—Rubber such as that supplied by CDI part number 0500700-VS-850NBR Aramid. Packing ring  390  is preferably a “Vee” packing ring—Teflon such as that supplied by CDI part number 0500700-VS-720 Carbon Reflon (having 2 percent carbon). Packing ring  400  is preferably a “Vee” packing ring—Rubber such as that supplied by CDI part number 0500700-VS-850NBR Aramid. Packing end  410  is preferably a bronze male packing ring. Various alternative materials for packing rings can be used such as standard chevron packing rings of standard packing materials. Bronze rings preferably meet or exceed an SAE 660 standard. 
         [0045]    A packing injection option can be provided for top drive swivel  30 . Injection fitting  225  can be used to inject additional packing material such as teflon into packing unit  305 . Head  226  for injection fitting  225  can be removed and packing material can then be inserting into fitting  225 . Head  226  can then be screwed back into injection fitting  225  which would push packing material through fitting  225  and into packing port  220 . The material would then be pushed into packing ring  350 . Packing ring  350  can comprise radial port  352  and transverse port  351 . The material would proceed through radial port  352  and exit through transverse port  351 . The material would tend to push out and squeeze packing rings  340 ,  330 ,  320  and packing rings  360 ,  370 ,  380 ,  390 ,  400  tending to create a better seal between packing unit  305  with mandrel  40  and sleeve  150 . The interaction between injection fitting  235  and packing unit  415  can be substantially similar to the interaction between injection fitting  225  and packing unit  305 . A conventionally available material which can be used for packing injection fittings  225 ,  235  is DESCO™ 625 Pak part number 6242-12 in the form of a 1 inch by ⅜ inch stick and distributed by Chemola Division of South Coast Products, Inc., Houston, Tex. In  FIG. 6 , injection fitting  235  is shown ninety degrees out of phase and, is preferably located as shown in  FIG. 9 . 
         [0046]    Injection fittings  225 ,  235  have a dual purpose: (a) provide an operator a visual indication whether there has been any leakage past either packing units  305 ,  415  and (b) allow the operator to easily inject additional packing material and stop seal leakage without removing top drive swivel  30  from drill string  20 . 
         [0047]      FIGS. 6B and 6C  shows top and side views of packing injection ring  350 . Packing injection ring  350  includes a male end  355  at its top and a flat end  356  at its rear. Ring  350  includes peripheral groove  353  around its perimeter. Optionally, ring  350  can include interior groove along its interior. A plurality of transverse ports  351 , 351 ′,  351 ″,  351 ″′, etc. extending from male end  355  to flat end  356  can be included and can be evenly spaced along the circumference of ring  350 . A plurality of radial ports  352 ,  352 ′,  352 ″,  352 ′″, etc. can be included extending from peripheral groove  353  and respectively intersecting transverse ports  351 , 351 ′,  351 ″,  351 ″′, etc. Preferably, the radial ports can extend from peripheral groove  353  through interior groove  354 . 
         [0048]    Retainer nut  800  can be used to maintain sleeve  150  on mandrel  40 . Retainer nut  800  can threadably engage mandrel  40  at threaded area  801 . Set screw  890  can be used to lock in place retainer nut  800  and prevent nut  800  from loosening during operation. Set screw  890  threadably engages retainer nut  800  through bore  900  and sets in one of a plurality of receiving portions  910  formed in mandrel  40 . Retaining nut  800  can also include grease injection fitting  880  for lubricating bearing  145 . Wiper ring  271  set in area  270  protects against dirt and other items from entering between the sleeve  150  and mandrel  40 . Grease ring  291  set in area  290  holds in lubricant for bearing  145 . 
         [0049]    Bearing  146  can be lubricated through grease injection fitting  211  and lubrication port  210 . Bearing  145  can be lubricated through grease injection fitting  881  and lubrication port  880 . 
         [0050]      FIG. 7  is a top view of clamp  600  which can be incorporated into top drive swivel  30 .  FIG. 8  is a side view of clamp  600 . Clamp  600  comprises first portion  610  and second portion  620 . First and second portions  610 ,  620  can be removably attached by fasteners  670 ,  680 . Clamp  600  fits in groove  605  of sleeve  150  ( FIG. 6 ). Key  700  can be included in keyway  690 . A corresponding keyway  691  is included in sleeve  150  of top drive swivel  30 . Keyways  690 ,  691  and key  700  prevent clamp  600  from rotating relative to sleeve  150 . A second key  720  can be installed in keyways  710 ,  711 . Shackles  650 ,  660  can be attached to clamp  600  to facilitate handing top drive swivel  30  when clamp  600  is attached. Torque arms  630 ,  640  can be included to allow attachment of clamp  600  (and sleeve  150 ) to a stationary part of top drive rig  1  and prevent sleeve  150  from rotating while drill string  20  is being rotated by top drive  10  (and top drive swivel  30  is installed in drill string  20 ). Torque arms  630 ,  640  are provided with holes for attaching restraining shackles. Restrained torque arms  630 ,  640  prevent sleeve  150  from rotating while mandrel  40  is being spun. Otherwise, frictional forces between packing units  305 ,  415  and packing support areas  131 ,  135  of rotating mandrel  40  would tend to also rotate sleeve  150 . Clamp  600  is preferably fabricated from  4140  heat treated steel being machined to fit around sleeve  150 . 
         [0051]      FIG. 9  is an overall perspective view (and partial sectional view) of top drive swivel  30 . Sleeve  150  is shown rotatably connected to mandrel  40 . Bearings  145 ,  146  allow sleeve  150  to rotate in relation to mandrel  40 . Packing units  305 ,  415  sealingly connect sleeve  150  to mandrel  40 . Retaining nut  800  retains sleeve  150  on mandrel  40 . Inlet  200  of sleeve  150  is fluidly connected to central longitudinal passage  90  of mandrel  40 . Accordingly, while mandrel  40  is being rotated and/or moved up and down pumpable substances can enter inlet  200  and exit central longitudinal passage  90  at lower end  60  of mandrel  40 . Recessed area  130  and protruding section  155  form a peripheral recess between mandrel  40  and sleeve  150 . The fluid pathway from inlet  200  to outlet at lower end  60  of central longitudinal passage  90  is as follows: entering inlet  200 ; passing through radial passage  190 ; passing through recessed area  130 ; passing through one of the plurality of radial inlet ports  40 ; passing through central longitudinal passage  90 ; and exiting mandrel  40  through central longitudinal passage  90  at lower end  60  and pin connection  80 . In  FIG. 9 , injection fitting  225  is shown ninety degrees out of phase and, for protection, is preferably located between inlet  200  and clamp  600 . 
         [0052]    Mandrel  40  takes substantially all of the structural load from drill string  20 . The overall length of mandrel  40  is preferably 52 and 5/16 inches. Mandrel  40  can be machined from a single continuous piece of heat treated steel bar stock. NC50 is preferably the API Tool Joint Designation for the box connection  70  and pin connection  80 . Such tool joint designation is equivalent to and interchangeable with 4½ inch IF (Internally Flush), 5 inch XH (Extra Hole) and 5½ inch DSL (Double Stream Line) connections. Additionally, it is preferred that the box connection  70  and pin connection  80  meet the requirements of API specifications 7 and 7G for new rotary shouldered tool joint connections having 6⅝ inch outer diameter and a 2¾ inch inner diameter. The Strength and Design Formulas of API 7G-Appendix A provides the following load carrying specification for mandrel  40  of top drive swivel  30 : (a) 1,477 pounds tensile load at the minimum yield stress; (b) 62,000 foot-pounds torsion load at the minimum torsional yield stress; and (c) 37,200 foot-pounds recommended minimum make up torque. Mandrel  40  can be machined from  4340  heat treated bar stock. 
         [0053]    Sleeve  150  is preferably fabricated from  4140  heat treated round mechanical tubing having the following properties: (120,000 psi minimum tensile strength, 100,000 psi minimum yield strength, and 285/311 Brinell Hardness Range). The external diameter of sleeve  150  is preferably about 11 inches. Sleeve  150  preferably resists high internal pressures of fluid passing through inlet  200 . Preferably top drive swivel  30  with sleeve  150  will withstand a hydrostatic pressure test of 12,500 psi. At this pressure the stress induced in sleeve  150  is preferably only about 24.8 percent of its material&#39;s yield strength. At a preferable working pressure of 7,500 psi, there is preferably a 6.7:1 structural safety factor for sleeve  150 . 
         [0054]    To minimize flow restrictions through top drive swivel  30 , large open areas are preferred. Preferably each area of interest throughout top drive swivel  30  is larger than the inlet service port area  200 . Inlet  200  is preferably 3 inches having a flow area of 4.19 square inches. The flow area of the annular space between sleeve  150  and mandrel  40  is preferably 20.81 square inches. The flow area through the plurality of radial inlet ports  140  is preferably 7.36 square inches. The flow area through central longitudinal bore  90  is preferably 5.94 square inches. 
         [0055]    The following is a list of reference numerals: 
         [0000]    
       
         
               
             
               
               
             
               
               
             
           
               
                   
               
               
                 LIST FOR REFERENCE NUMERALS 
               
             
          
           
               
                 (Part No.) 
                 (Description) 
               
               
                 Reference Numeral 
                 Description 
               
               
                   
               
             
          
           
               
                 1 
                 rig 
               
               
                 2 
                 crown block 
               
               
                 3 
                 cable means 
               
               
                 4 
                 travelling block 
               
               
                 5 
                 hook 
               
               
                 6 
                 gooseneck 
               
               
                 7 
                 swivel 
               
               
                 8 
                 drilling fluid line 
               
               
                 10 
                 top drive unit 
               
               
                 11 
                 draw works 
               
               
                 12 
                 cable 
               
               
                 13 
                 rotary table 
               
               
                 14 
                 well bore 
               
               
                 15 
                 guide rail 
               
               
                 16 
                 support 
               
               
                 17 
                 support 
               
               
                 18 
                 drill pipe 
               
               
                 19 
                 drill string 
               
               
                 20 
                 drill string or work string 
               
               
                 30 
                 swivel 
               
               
                 31 
                 hose 
               
               
                 40 
                 swivel mandrel 
               
               
                 50 
                 upper end 
               
               
                 60 
                 lower end 
               
               
                 70 
                 box connection 
               
               
                 80 
                 pin connection 
               
               
                 90 
                 central longitudinal passage 
               
               
                 100 
                 shoulder 
               
               
                 101 
                 outer surface of shoulder 
               
               
                 102 
                 upper surface of shoulder 
               
               
                 110 
                 interior surface 
               
               
                 120 
                 external surface (mandrel) 
               
               
                 130 
                 recessed area 
               
               
                 131 
                 packing support area 
               
               
                 132 
                 packing support area 
               
               
                 140 
                 radial inlet ports (a plurality) 
               
               
                 145 
                 bearing (preferably combination 6.875 
               
               
                   
                 inch bearing cone, Timken Part number 
               
               
                   
                 67786, and 9.75 inch bearing cup bearing 
               
               
                   
                 cup, Timken part number 67720) 
               
               
                 146 
                 bearing (preferably combination 7 inch 
               
               
                   
                 bearing cone, Timken Part number 67791, 
               
               
                   
                 and 9.75 inch bearing cup bearing cup, 
               
               
                   
                 Timken part number 67720) 
               
               
                 150 
                 swivel sleeve 
               
               
                 155 
                 protruding section 
               
               
                 156 
                 shoulder 
               
               
                 157 
                 shoulder 
               
               
                 158 
                 packing support area 
               
               
                 159 
                 packing support area 
               
               
                 160 
                 upper end 
               
               
                 170 
                 lower end 
               
               
                 180 
                 central longitudinal passage 
               
               
                 190 
                 radial passage 
               
               
                 200 
                 inlet 
               
               
                 201 
                 arrow 
               
               
                 202 
                 arrow 
               
               
                 203 
                 arrow 
               
               
                 204 
                 arrow 
               
               
                 205 
                 peripheral groove 
               
               
                 206 
                 key way 
               
               
                 210 
                 lubrication port 
               
               
                 211 
                 grease injection fitting (preferably grease 
               
               
                   
                 zerk (¼ - 28 td. in. streight, mat.-monel 
               
               
                   
                 Alemite part number 1966-B) 
               
               
                 220 
                 packing port 
               
               
                 225 
                 injection fitting(preferably packing 
               
               
                   
                 injection fitting (10,000 psi) Vesta - PGI 
               
               
                   
                 Manufacturing part number PF10N4- 
               
               
                   
                 10)(alternatively Pressure Relief Tool for 
               
               
                   
                 packing injection fitting Vesta - PGI 
               
               
                   
                 Manufacturing part number PRT -PIF 12-20) 
               
               
                 226 
                 head 
               
               
                 230 
                 packing port 
               
               
                 235 
                 injection fitting (preferably packing 
               
               
                   
                 injection fitting (10,000 psi) Vesta - PGI 
               
               
                   
                 Manufacturing part number PF10N4- 
               
               
                   
                 10)(alternatively Pressure Relief Tool for 
               
               
                   
                 packing injection fitting Vesta - PGI 
               
               
                   
                 Manufacturing part number PRT -PIF 12-20) 
               
               
                 240 
                 cover 
               
               
                 250 
                 upper shoulder 
               
               
                 260 
                 lower shoulder 
               
               
                 270 
                 area for wiper ring 
               
               
                 271 
                 wiper ring (preferably Parker part number 
               
               
                   
                 959-65) 
               
               
                 280 
                 area for wiper ring 
               
               
                 281 
                 wiper ring (preferably Parker part number 
               
               
                   
                 959-65) 
               
               
                 290 
                 area for grease ring 
               
               
                 291 
                 grease ring (preferably Parker part number 
               
               
                   
                 2501000 Standard Polypak) 
               
               
                 300 
                 area for grease ring 
               
               
                 301 
                 grease ring (preferably Parker part number 
               
               
                   
                 2501000 Standard Polypak) 
               
               
                 305 
                 packing unit 
               
               
                 310 
                 packing retainer nut 
               
               
                 314 
                 bore for set screw 
               
               
                 315 
                 set screw for packing retainer nut 
               
               
                 316 
                 threaded area 
               
               
                 317 
                 set screw for receiving area 
               
               
                 320 
                 packing end 
               
               
                 330 
                 packing ring 
               
               
                 340 
                 packing ring 
               
               
                 350 
                 packing injection ring 
               
               
                 351 
                 transverse port 
               
               
                 352 
                 radial port 
               
               
                 353 
                 peripheral groove 
               
               
                 354 
                 interior groove 
               
               
                 355 
                 male end 
               
               
                 356 
                 flat end 
               
               
                 360 
                 packing end 
               
               
                 370 
                 packing ring 
               
               
                 380 
                 packing ring 
               
               
                 390 
                 packing ring 
               
               
                 400 
                 packing ring 
               
               
                 410 
                 packing end 
               
               
                 415 
                 packing unit 
               
               
                 420 
                 packing retainer nut 
               
               
                 425 
                 set screw for packing retainer nut 
               
               
                 430 
                 packing end 
               
               
                 440 
                 packing ring 
               
               
                 450 
                 packing ring 
               
               
                 460 
                 packing lubrication ring 
               
               
                 470 
                 packing end 
               
               
                 480 
                 packing ring 
               
               
                 490 
                 packing ring 
               
               
                 500 
                 packing ring 
               
               
                 510 
                 packing ring 
               
               
                 520 
                 packing end 
               
               
                 600 
                 clamp 
               
               
                 605 
                 groove 
               
               
                 610 
                 first portion 
               
               
                 620 
                 second portion 
               
               
                 630 
                 torque arm 
               
               
                 640 
                 torque arm 
               
               
                 650 
                 shackle 
               
               
                 660 
                 shackle 
               
               
                 670 
                 fastener 
               
               
                 680 
                 fastener 
               
               
                 690 
                 keyway 
               
               
                 691 
                 keyway 
               
               
                 700 
                 key 
               
               
                 710 
                 keyway 
               
               
                 711 
                 keyway 
               
               
                 720 
                 key 
               
               
                 730 
                 peripheral groove 
               
               
                 800 
                 retaining nut 
               
               
                 801 
                 threaded area 
               
               
                 810 
                 outer surface 
               
               
                 820 
                 inclined portion 
               
               
                 830 
                 bore 
               
               
                 840 
                 inner surface 
               
               
                 850 
                 threaded portion 
               
               
                 860 
                 upper surface 
               
               
                 870 
                 bottom surface 
               
               
                 880 
                 lubrication port 
               
               
                 881 
                 grease injection fitting (preferably grease 
               
               
                   
                 zerk (¼ - 28 td. in. streight, mat.-monel 
               
               
                   
                 Alemite part number 1966-B) 
               
               
                 890 
                 set screw 
               
               
                 900 
                 bore for set screw 
               
               
                 910 
                 receiving portion for set screw 
               
               
                   
               
             
          
         
       
     
         [0056]    All measurements disclosed herein are at standard temperature and pressure, at sea level on Earth, unless indicated otherwise. All materials used or intended to be used in a human being are biocompatible, unless indicated otherwise. 
         [0057]    It will be understood that each of the elements described above, or two or more together may also find a useful application in other types of methods differing from the type described above. Without further analysis, the foregoing will so fullyrevealthe gist of the present invention that others can, by applying current knowledge, readily adapt it for various applications without omitting features that, from the standpoint of prior art, fairly constitute essential characteristics of the generic or specific aspects of this invention set forth in the appended claims. The foregoing embodiments are presented by way of example only; the scope of the present invention is to be limited only by the following claims.

Summary:
For use with a top drive power unit supported for connection with a well string in a well bore to selectively impart longitudinal and/or rotational movement to the well string, a feeder for supplying a pumpable substance such as cement and the like from an external supply source to the interior of the well string in the well bore without first discharging it through the top drive power unit including a mandrel extending through a sleeve which is sealably and rotatably supported thereon for relative rotation between the sleeve and mandrel. The mandrel and sleeve have flow passages for communicating the pumpable substance from an external source to discharge through the sleeve and mandrel and into the interior of the well string below the top drive power unit. The unit can include a packing injection system, clamp, and novel packing configuration.