Abstract:
An improved method and apparatus for dropping a ball, plug or dart during oil and gas well operations (e.g., cementing operations) employs a specially configured valving member with curved and flat portions that alternatively direct fluid flow through a bore or opening in the valving member via an inner channel or around the periphery of the valving member in an outer channel. In one embodiment, the ball(s), dart(s) or plug(s) are contained in a sliding sleeve that shifts position responsive to valve rotation. An optional indicator indicates to a user or operator that a ball or plug has passed a selected one of the valving members.

Description:
CROSS-REFERENCE TO RELATED APPLICATIONS 
     Priority of U.S. Provisional Patent Application Ser. No. 61/180,296, filed 21 May 2009, incorporated herein by reference, is hereby claimed. 
     U.S. patent application Ser. No. 11/749,591, filed 16 May 2007 (now U.S. Pat. No. 7,607,481), and U.S. patent application Ser. No. 11/951,802, filed 6 Dec. 2007, are each hereby incorporated herein by reference. 
    
    
     STATEMENT REGARDING FEDERALLY SPONSORED RESEARCH OR DEVELOPMENT 
     Not applicable 
     REFERENCE TO A “MICROFICHE APPENDIX” 
     Not applicable 
     BACKGROUND OF THE INVENTION 
     1. Field of the Invention 
     The present invention relates to a method and apparatus that is of particular utility in cementing operations associated with oil and gas well exploration and production. More specifically the present invention provides an improvement to cementing operations when running a casing string. 
     2. General Background of the Invention 
     Patents have issued that relate generally to the concept of using a plug, dart or a ball that is dispensed or dropped into the well or “down hole” during oil and gas well drilling and production operations, especially when conducting cementing operations. The following possibly relevant patents are incorporated herein by reference. The patents are listed numerically. The order of such listing does not have any significance. 
     
       
         
               
               
               
             
           
               
                 TABLE 
               
               
                   
               
               
                 U.S. 
                   
                 ISSUE DATE 
               
               
                 Pat. No. 
                 TITLE 
                 MM-DD-YYYY 
               
               
                   
               
             
             
               
                 3,828,852 
                 Apparatus for Cementing Well Bore Casing 
                 Aug. 13, 1974 
               
               
                 4,427,065 
                 Cementing Plug Container and Method of  
                 Jan. 24, 1984 
               
               
                   
                 Use Thereof 
                   
               
               
                 4,624,312 
                 Remote Cementing Plug Launching System 
                 Nov. 25, 1986 
               
               
                 4,671,353 
                 Apparatus for Releasing a Cementing Plug 
                 Jun. 09, 1987 
               
               
                 4,722,389 
                 Well Bore Servicing Arrangement 
                 Feb. 02, 1988 
               
               
                 4,782,894 
                 Cementing Plug Container with Remote 
                 Nov. 08, 1988 
               
               
                   
                 Control System 
                   
               
               
                 4,854,383 
                 Manifold Arrangement for use with a Top 
                 Aug. 08, 1989 
               
               
                   
                 Drive Power Unit 
                   
               
               
                 4,995,457 
                 Lift-Through Head and Swivel 
                 Feb. 26, 1991 
               
               
                 5,095,988 
                 Plug Injection Method and Apparatus 
                 Mar. 17, 1992 
               
               
                 5,236,035 
                 Swivel Cementing Head with Manifold 
                 Aug. 17, 1993 
               
               
                   
                 Assembly 
                   
               
               
                 5,293,933 
                 Swivel Cementing Head with Manifold 
                 Mar. 15, 1994 
               
               
                   
                 Assembly Having Remove Control Valves 
                   
               
               
                   
                 and Plug Release Plungers 
                   
               
               
                 5,435,390 
                 Remote Control for a Plug-Dropping Head 
                 Jul. 25, 1995 
               
               
                 5,758,726 
                 Ball Drop Head With Rotating Rings 
                 Jun. 02, 1998 
               
               
                 5,833,002 
                 Remote Control Plug-Dropping Head 
                 Nov. 10, 1998 
               
               
                 5,856,790 
                 Remote Control for a Plug-Dropping Head 
                 Jan. 05, 1999 
               
               
                 5,960,881 
                 Downhole Surge Pressure Reduction  
                 Oct. 05, 1999 
               
               
                   
                 System and Method of Use 
                   
               
               
                 6,142,226 
                 Hydraulic Setting Tool 
                 Nov. 07, 2000 
               
               
                 6,182,752 
                 Multi-Port Cementing Head 
                 Feb. 06, 2001 
               
               
                 6,390,200 
                 Drop Ball Sub and System of Use 
                 May 21, 2002 
               
               
                 6,575,238 
                 Ball and Plug Dropping Head 
                 Jun. 10, 2003 
               
               
                 6,672,384 
                 Plug-Dropping Container for Releasing a  
                 Jan. 06, 2004 
               
               
                   
                 Plug Into a Wellbore 
                   
               
               
                 6,904,970 
                 Cementing Manifold Assembly 
                 Jun. 14, 2005 
               
               
                 7,066,249 
                 Plug-Dropping Container for Releasing a  
                 Jun. 27, 2006 
               
               
                   
                 Plug into a Wellbore 
               
               
                   
               
             
          
         
       
     
     BRIEF SUMMARY OF THE INVENTION 
     The present invention provides an improved method and apparatus for use in cementing and like operations when running casing. 
     In one embodiment, the present invention is directed to a method of transmitting cement into an oil and gas well having an open hole well bore at least partially occupied by a casing string, comprising the steps of: 
     a) providing a top drive casing installation apparatus that is able to lift a joint of casing, rotate that joint of casing to a generally inclined or vertical position and then rotate that joint of casing while connecting that joint of casing to a casing string that extends into the well bore; 
     b) rotating the casing string with the apparatus of claim  1  after step “a” while circulating a well fluid into the well bore via the casing string annulus; 
     c) preparing a module that is about the size of the joint of casing of step “a”, wherein the module includes a plug dropping tool having one or more valves that enables fluid flow in the casing string below the module to be valved and one or more plugs that can be lowered into the well bore by opening one of the valves; 
     d) using the top drive casing installation apparatus of step “a” to join the module of step “c” to the casing string; 
     e) circulating fluid into the well via the module after step “d”; 
     f) releasing a plug from the module of step “c”; and 
     g) transmitting cement into the well bore after step “f”. 
     Preferably, the module includes an extension member below the plug dropping tool. The module can include an extension member above the plug dropping tool. 
     The method can further comprise dropping a plug from the plug dropping tool after step “g”. 
     The method can provide a mechanism that makes up joints of casing to form the casing string, and in steps “c” through “g” the module is positioned above said mechanism. 
     The module preferably includes an intake port that enables intake of cement. 
     The method can include positioning the valves of the module of step “c” below the intake port. 
     Preferably, there are three of said valves in the module of step “c”. 
     Preferably, there are at least three connectable sections that define the module of step “c”. 
     The present invention provides in one embodiment a method of transmitting cement into an oil and gas well having an open hole well bore with a well annulus that is at least partially occupied by a casing string having a casing annulus, comprising the steps of: 
     a) providing a top drive casing installation apparatus that is able to lift a joint of casing, rotate that joint of casing to a generally inclined or vertical position and then rotate that joint of casing while connecting that joint of casing to a casing string that extends into a the well bore; 
     b) rotating the casing string with the apparatus of claim  1  after step “a” while circulating a well fluid into the well bore via the casing string annulus; 
     c) preparing a module that is about the size of the joint of casing of step “a”, wherein the module includes a plug dropping tool having one or more valves that enables fluid flow in the casing string below the module to be valved and one or more plugs that can be lowered into the well bore by opening one of the valves; 
     d) using the top drive casing installation apparatus of step “a” to join the module of step “c” to the casing string; 
     e) circulating fluid into the well via the module after step “d”; 
     f) releasing a plug from the module of step “c”; and 
     g) transmitting cement into the well bore after step “f” of sufficient volume to fill at least a portion of the well annulus in between a formation and the casing. 
     The present invention provides in one embodiment a method of cementing an annular space in between a casing string having a casing string bore and an oil well having a well bore, comprising the steps of: 
     a) providing a plurality of casing joints that enable the casing string to be lengthened; 
     b) connecting a casing joint to the string with a machine that both lifts the casing joint and rotates the casing joint and casing string relative to one another during connecting; 
     c) circulating a fluid into the well bore via the casing bore after step “c”; 
     d) providing a casing joint module having a module wall, module bore and a plug dropping tool, said tool including one or more valves and one or more plugs; 
     e) after step “b”, adding the module of step “d” to the casing string with the machine of step “b”; and 
     f) pumping a volume of cement containing material into the well bore via the plug dropping tool and casing bore, wherein a plug travels from the plug dropping tool to the casing bore with the cement containing material. 
     Preferably, the module has multiple valves and multiple plugs and further comprising placing plugs upstream and downstream of the volume of cement containing material while the machine of step “b” and “e” is at least partially supporting the module. 
     Preferably, the machine lifts the module from a non-vertical to a generally vertical position in step “e”. 
     Preferably, in step “e” part of the module extends above the machine. 
     Preferably, in step “d” the module has a fitting that enables fluid to be pumped into the module bore via the module wall. 
     Preferably, the casing string is rotated between steps “b” and “f”. 
     Preferably, the casing string is rotated and moved vertically in between steps “b” and “f”. 
     Preferably, the pumping of step “f” occurs less than one hour after step “e”. 
     In one embodiment, the present invention provides a method of cementing an annular space in between a casing string having a casing string bore and an oil well having a well bore, comprising the steps of: 
     a) providing a plurality of casing joints that enable the casing string to be lengthened; 
     b) connecting a casing joint to the string with a machine that both lifts the casing joint and rotates the casing joint and casing string relative to one another during connecting; 
     c) circulating a fluid into the well bore via the casing bore after step “c”; 
     d) providing a casing joint module having a module wall, module bore and a plug dropping tool, said tool including one or more valves and one or more plugs; 
     e) after step “b”, adding the module of step “d” to the casing string with the machine of step “b”; 
     f) pumping a volume of cement containing material into the well bore via the plug dropping tool and casing bore, wherein a plug travels from the plug dropping tool to the casing bore with the cement containing material; 
     g) wherein the machine remains in substantially the same position in steps “b” through “e”. 
     The module can have multiple valves and multiple plugs and the method can further comprise placing plugs upstream and downstream of the volume of cement containing material while the machine of step “b” and “e” is at least partially supporting the module. 
     Preferably, the machine lifts the module from a non-vertical to a generally vertical position in step “e”. 
     Preferably, in step “e” part of the module extends above the machine. 
     Preferably, in step “d” the module has a fitting that enables fluid to be pumped into the module bore via the module wall. 
     Preferably, the casing string is rotated between steps “b” and “f”. 
     Preferably, the casing string is rotated and moved vertically in between steps “b” and “f”. 
     Preferably, the pumping of step “f” occurs less than one hour after step “e”. 
     In one embodiment, the present invention provides a method of transmitting cement into an oil and gas well having an open hole well bore at least partially occupied by a casing string, comprising the steps of: 
     a) providing a top drive casing installation apparatus that is able to lift a joint of casing, rotate that joint of casing to a generally inclined or vertical position and then rotate that joint of casing while connecting that joint of casing to a casing string that extends into a the well bore; 
     b) attaching a valving apparatus to the casing string after step “a” that enables fluid circulation through a valving member or around a valving member that controls dispensing of a plug so that circulation is enabled before or after dropping a plug, the valving apparatus including one or more ball valving members that valve a central passageway and one or more fins attached to the ball valving member for valving flow outside and around the central passageway; 
     c) rotating the casing string after step “b” while circulating a well fluid into the well bore via the casing string annulus; 
     d) circulating fluid into the well after step “b”; 
     e) releasing a plug into the well after step “c”; and 
     f) transmitting cement into the well bore after step “e”. 
     Preferably, at least one valving member has a valve opening that enables passage of a plug of a diameter of 6.5 inches. 
     Preferably, the tool body has a working tension of two million pounds. 
     Preferably, the tool body has an internal working pressure of 15,000 psi. 
     Preferably, the tool body has a working torque of 50,000 foot pounds. 
     Preferably, the tool body has a working torque of 50,000 foot pounds in either of two rotational directions. 
    
    
     
       BRIEF DESCRIPTION OF THE SEVERAL VIEWS OF THE DRAWINGS 
       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: 
         FIGS. 1A ,  1 B,  1 C are partial sectional elevation views of the preferred embodiment of the apparatus of the present invention wherein line A-A of  FIG. 1A  matches line A-A of  FIG. 1B , and line B-B of  FIG. 1B  matches line B-B of  FIG. 1C ; 
         FIG. 2  is a partial elevation view of the preferred embodiment of the apparatus of the present invention; 
         FIG. 3  is an elevation view of a section of casing; 
         FIG. 4  is a partial elevation view of the preferred embodiment of the apparatus of the present invention; 
         FIG. 5  is a partial elevation view of the preferred embodiment of the apparatus of the present invention and showing part of the method of the present invention; 
         FIG. 6  is a partial elevation view of the preferred embodiment of the apparatus of the present invention and showing part of the method of the present invention; 
         FIG. 7  is a partial elevation view of the preferred embodiment of the apparatus of the present invention and showing part of the method of the present invention; 
         FIG. 8  is a partial elevation view of the preferred embodiment of the apparatus of the present invention and showing part of the method of the present invention; 
         FIG. 9  is a partial elevation view of the preferred embodiment of the apparatus of the present invention and showing part of the method of the present invention; 
         FIG. 10  is a partial elevation view illustrating part of the method of the present invention; 
         FIG. 11  is a partial elevation view illustrating part of the method of the present invention; 
         FIG. 12  is a partial sectional elevation view of the preferred embodiment of the apparatus of the present invention; 
         FIG. 13  is a partial sectional elevation view of the preferred embodiment of the apparatus of the present invention; 
         FIG. 14  is a partial sectional elevation view of the preferred embodiment of the apparatus of the present invention; and 
         FIG. 15  is a partial sectional elevation view of the preferred embodiment of the apparatus of the present invention. 
     
    
    
     DETAILED DESCRIPTION OF THE INVENTION 
       FIGS. 5-9  show generally an oil well drilling system  10  that can provide a platform  11 . Such platforms  11  are well known. Platform  11  supports a derrick  12  that can be equipped with a lifting device or draw works  13 . Platform  11  can employ a top drive unit. A top drive unit can be seen for example in U.S. Pat. Nos. 4,854,383 and 4,722,389 which are incorporated herein by reference. 
     In  FIG. 9 , a flow line  30  can be used for providing a selected fluid such as a fluidized cement or fluidized setable material to be pumped into the well during operations which are known in the industry and are sometimes referred to as cementing operations. Such cementing operations are discussed for example in prior U.S. Pat. Nos. 3,828,852; 4,427,065; 4,671,353; 4,782,894; 4,995,457; 5,236,035; 5,293,933; and 6,182,752, each of which is incorporated herein by reference. 
     A casing running tool or “CRT”  18  can be used to add joints of casing  16  (see  FIG. 3 ) to a casing string  17  that extends into a well bore. The casing string  17  is comprised of many joints of casing  16  connected end to end, typically with threaded connections. Casing running tool  18  is capable of supporting one joint of casing  16  at a time using arm or arms  31 . String  17  is supported with slips  32  when a new joint  16  must be added to string  17  (see  FIG. 6 ,  8 ). 
     Platform  11  provides a platform deck  33  that affords space for well personnel to operate and for the storage of equipment and supplies that are needed for the well drilling operation. The installation (or removal) of casing running tool  18  requires about three to four (3-4) hours of labor for platform operators. 
     Typically, the casing running tool  18  must be removed before a cementing operation can be conducted. Because the removal of the casing running tool  18  occupies about three to four hours of crew time, it is not possible to circulate fluid through the casing string  17  while the casing running tool  18  is being removed. This can lead to an immobilization or sticking of the casing string  17  in the well bore. 
     When a cementing operation is conducted, it is desirable or necessary to not only rotate the string  17  but to also reciprocate the string  17  up and down relative to the surrounding formation. Failure to do so can result in void spaces and an incomplete or failed cementing operation. 
     The present invention provides an improved method of installing a casing string and cementing the casing string in position wherein the three to four hours of rig time that are normally lost to the removal of a casing running tool have been eliminated. Thus, the casing string can be continuously rotated as shown by arrow  29 , reciprocated and fluid circulated to prevent a sticking of the casing string. This is accomplished by employing a module  15  that is about the same size and length as a normal joint of casing  16 . The module  15  is shown in FIGS.  4  and  6 - 9 . 
     The module  15  includes upper  21  and lower  22  end portions. The module is similar in size to a typical joint of casing  16  (see  FIG. 3 ) which has an upper end portion  19  that can be in the form of a box connection and a lower end portion  20  that can be in the form of a pin connection. In this fashion, the lower or pin connection  20  of one joint of casing  16  connects to the box connection or upper end portion  19  of the joint of casing  16  below it. Similarly, the module  15  provides an upper end portion  21  with a box connection and a lower end portion  22  with a pin connection that enables connection of the module  15  to a joint of casing  16  at its box connection  19 . 
     In  FIG. 4 , the module  15  includes a tool body  14  that is connected with a short joint of pipe or sub  34  to fitting  25 . The fitting  25  is a t-fitting that employs an inlet flow line  26  for adding cement or fluid containing cement to the bore of the module  15 . Valve  23  is placed above fitting  25  and provides a valve handle  24  for operating the valve  23 . Similarly, the flow line  26  can be provided with a valve  27  having a handle  28  for opening or closing the valve  27 . 
     Above valve  23  is provided another short joint or sub  63  which provides the box connection  21 . Below tool body  14  is provided a long joint of pipe or sub  64  having a lower end portion that provides pin connection  22 . In comparing  FIGS. 3 and 4 , the module  15  ( FIG. 4 ) is about the same length (for example, about 40-42 feet) as a standard joint of casing  16  ( FIG. 3 ) and provides the same connections at its end portions  21 ,  22 . 
     A casing running tool  18  simply handles the module  15  in the same fashion that it handles a joint of casing  16 . With the present invention, the casing running tool  18  does not have to be removed for cementing operations. Rather, it simply loads the module  15  into position at the top of string  17  as shown in  FIGS. 6 ,  7 ,  8  and  9  in the same manner that it loads and installs a joint of casing  16 . The casing running tool  18  can then remain in position during cementing operations, its removal not being required. Instead, cementing operations are conducted through the module  15  with its valve and fittings  23 - 28  and tool body  14 . 
     The present invention provides a tool body  14  configured for dropping balls, plugs, darts or the like as a part of a cementing operation. In the drawings ( FIGS. 1A ,  1 B,  1 C,  12 - 15 ), arrows  75  indicate generally the flow path of fluid (e.g. cement, fluidized material or the like) through the tool body  14 . In that regard, the present invention provides an improved ball or plug or dart dropping tool body  14 . 
     Ball/plug dropping head tool body  14  has an upper end portion  41  and a lower end portion  42 . Tool body  14  can be of multiple sections that are connected together, such as with threaded connections. In  FIGS. 1A-1C , the tool body  14  includes sections  35 ,  36 ,  37 ,  38 ,  39 . The section  35  is an upper section. The section  39  is a lower section. 
     Tool body  14  can be pre-loaded with a number of different items to be dropped as part of a cementing operation. For example, in  FIGS. 1A ,  1 B,  1 C and  12 - 15  there are a number of items that are contained in tool body  14 . These can include a larger diameter ball or dart or a smaller diameter ball or dart. 
     The tool body  14  supports a plurality of valving members  43 ,  44 . The valving members can include first valving member  43  which is an upper valving member and second valving member which is a lower valving member  44 . 
     Threaded connections  46 ,  47 ,  48 ,  49  can be used for connecting the various body sections  35 ,  36 ,  37 ,  38 ,  39  together end to end as shown in  FIGS. 1A ,  1 B,  1 C. Tool body  14  upper end  41  is provided with an internally threaded portion  50  for forming a connection with tubular member  34  that depends from fitting  25  as shown in  FIG. 4 . A flow bore  51  extends between upper end  41  and lower end  42  of tool body  14 . 
     Sleeve sections  52  are secured to tool body  34  within bore  51  as shown in  FIGS. 1A ,  1 B,  1 C. Sleeves or sleeve sections  52  can be generally centered within bore  51  as shown in  FIGS. 1A ,  1 B,  1 C using spacers  67  that extend along radial lines from the sections  35 - 39 . 
     Each valving member  43 ,  44  is movable between open and closed positions. In  FIGS. 1A ,  1 B,  1 C each of the valving members  43 ,  44  is in a closed position. In that closed position, each valving member  43 ,  44  prevents downward movement of a plug, ball or dart  40 . In  FIG. 1A , the closed position of valving member  43  prevents downward movement of larger diameter ball  40 . Similarly, in  FIG. 1B , a closed position of valving member  44  prevents a downward movement of dart  40 . In each instance, a ball, dart or plug  40  rests upon the outer curved surface  68  of valving member  43 , as shown in the drawings. 
     Each valving member  43 ,  44  provides a pair of opposed generally flat surfaces  69 ,  70  (see  FIG. 15 ). The tool body  14  provides opposed openings  90  that are receptive to the generally cylindrically shaped valve stems  54 ,  55  that are provided on the flat sections or flat surfaces  69 ,  70  of each valving member  43 ,  44 . The flat surface  69  provides valve stem  54 . Openings  90  are receptive of stems  54 ,  55 . 
     The flat surfaces  69 ,  70  enable fluid to flow in bore  51  in a position radially outwardly or externally of sleeve or sleeve section  52  by passing between the tool body sections  35 ,  36 ,  37 ,  38 ,  39  and sleeves  52 . Thus, bore  51  is divided into two flow channels. These two flow channels  71 ,  72  include a central flow channel  71  within sleeves  52  that is generally cylindrically shaped and that aligns generally with the channel  53  of each valving member  43 ,  44 . The second flow channel is an annular outer flow channel  72  that is positioned in between a sleeve  52  and the tool body sections  35 ,  36 ,  37 ,  38 ,  39 . The channels  71 ,  72  can be concentric. The outer channel  72  is open when the valving members  43 ,  44  are in the closed positions of  FIGS. 1A ,  1 B and  1 C, wherein central flow channel  71  is closed. 
     When the valving members  43 ,  44  are rotated to an open position, fins  73  become transversely positioned with respect to the flow path of fluid flowing in channel  72  thus closing outer flow channel  72 . This occurs when a valving member  43 ,  44  is opened for releasing a ball or dart  40 . 
     In  FIG. 13 , a tool  74  has been used to rotate valving member  44  in the direction of arrow  76  to an open position  66  that aligns its channel  53  with central flow channel  71  enabling a dart or ball  40  to fall downwardly via central flow channel  71 . In  FIG. 13 , outer flow channel  72  has been closed by fins  73  that have now rotated about 90 degrees from the open position of  FIGS. 1A ,  1 B to the closed position. Fins  73  close channel  72  in  FIG. 15 . It should be understood that tool  74  can also be used to rotate valving member  43  or  44  from a closed position to an open position  66  when it is desired that ball or dart  40  should drop. 
     With valves  43  open (see  FIG. 15 ), channel  72  enables fluid to circulate through behind the plug or dart  40  (see  FIG. 13 ). 
     In  FIG. 15 , second valving member  44  is opened releasing a dart  40 . This second dart can be inserted behind the first plug or dart  40  that was released by valve  43 . The second dart  40  can be used to push the cement  80  downwardly in the direction of arrow  82  in  FIG. 15 . A completion fluid or other fluid can be used to pump the second dart  40  downwardly, pushing cement ahead of it. 
     The ball  40  can be deformable, so that it can enter the smaller diameter section at the lower end portion  42  of tool body  14 . 
     Sleeve  52  is preferably a sliding sleeve that drops downwardly when a valving member  43  or  44  is rotated to an open position. 
     When valving member  44  is rotated to the open position, the gap between sleeve  52  and valving member  43  is now a larger gap. 
     A sleeve  52  above a valving member  43  or  44  thus moves up and down responsive to a rotation of that valving member  43  or  44 . 
     Indicator  56  can be attached to tool body  14  as shown in  FIG. 1B . Recesses  59  on the tool body  14  enable attachment of shaft  57 . The shaft  57  can be held in position using fasteners such as bolts, for example. Spring  58  can then be attached to tool body  14  at recess  59  using fasteners such as bolts. Curved arrow  60  in  FIG. 15  illustrates rotation of shaft  57  for moving arm  61  between the extended position of  FIG. 1B  and the retracted position of  FIG. 15 . Arm  61  extends through slot  62  in the extended position of  FIG. 1B . 
     The following is a list of parts and materials suitable for use in the present invention. 
     
       
         
               
             
               
               
             
           
               
                   
               
               
                 PARTS LIST 
               
             
          
           
               
                 Part Number 
                 Description 
               
               
                   
               
               
                 10 
                 oil well drilling system 
               
               
                 11 
                 drilling platform 
               
               
                 12 
                 derrick 
               
               
                 13 
                 draw works/lift 
               
               
                 14 
                 tool body 
               
               
                 15 
                 module 
               
               
                 16 
                 casing joint 
               
               
                 17 
                 casing string 
               
               
                 18 
                 casing running tool 
               
               
                 19 
                 upper end/box connection 
               
               
                 20 
                 lower end/pin connection 
               
               
                 21 
                 upper end/box connection 
               
               
                 22 
                 lower end/pin connection 
               
               
                 23 
                 valve 
               
               
                 24 
                 handle 
               
               
                 25 
                 fitting 
               
               
                 26 
                 inlet flow line 
               
               
                 27 
                 valve 
               
               
                 28 
                 handle 
               
               
                 29 
                 arrow 
               
               
                 30 
                 flow line 
               
               
                 31 
                 arm 
               
               
                 32 
                 slips 
               
               
                 33 
                 platform deck 
               
               
                 34 
                 short joint/sub 
               
               
                 35 
                 section 
               
               
                 36 
                 section 
               
               
                 37 
                 section 
               
               
                 38 
                 section 
               
               
                 39 
                 section 
               
               
                 40 
                 dart 
               
               
                 41 
                 upper end 
               
               
                 42 
                 lower end 
               
               
                 43 
                 first valving member 
               
               
                 44 
                 second valving member 
               
               
                 46 
                 threaded connection 
               
               
                 47 
                 threaded connection 
               
               
                 48 
                 threaded connection 
               
               
                 49 
                 threaded connection 
               
               
                 50 
                 threaded portion 
               
               
                 51 
                 flow bore 
               
               
                 52 
                 sleeve section 
               
               
                 53 
                 channel 
               
               
                 54 
                 stem 
               
               
                 55 
                 stem 
               
               
                 56 
                 indicator 
               
               
                 57 
                 shaft 
               
               
                 58 
                 spring 
               
               
                 59 
                 recess 
               
               
                 60 
                 arrow 
               
               
                 61 
                 arm 
               
               
                 62 
                 slot 
               
               
                 63 
                 short joint/sub 
               
               
                 64 
                 long joint/sub 
               
               
                 66 
                 opening position 
               
               
                 67 
                 spacer 
               
               
                 68 
                 outer curved surface 
               
               
                 69 
                 flat surface 
               
               
                 70 
                 flat surface 
               
               
                 71 
                 central flow channel 
               
               
                 72 
                 outer flow channel 
               
               
                 73 
                 fin 
               
               
                 74 
                 tool 
               
               
                 75 
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     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. 
     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.