Patent Abstract:
A valve having a sealing surface that is rotated 90 degrees on axial floating hinge assemblies is provided. A sleeve moves into position to protect the valve mechanism when the valve is in an open position. A sleeve locks the valve sealing element in place in either a closed or open position. The valve may be used during drilling of wells to prevent flow into the casing when the drill pipe and bit are raised above the valve.

Full Description:
BACKGROUND OF THE INVENTION 
       [0001]    1. Field of the Invention 
         [0002]    This invention relates to an apparatus that may be used in wells during drilling operations. More particularly, a valve having a full-opening bore that may be placed in a tubular such as casing and operated mechanically to isolate pressure when it is closed is provided. 
         [0003]    2. Description of Related Art 
         [0004]    Drilling of wells in an underbalanced or balanced pressure condition has well-known advantages. In this condition, pressure in the formation being drilled is equal to or greater than pressure in the wellbore. When there is a need to withdraw the drill pipe from the well, pressure in the wellbore must be controlled to prevent influx of fluids from a formation into the wellbore. The usual remedy of preventing influx of fluid from a formation—by increasing fluid density in the wellbore—may negate the advantages of balanced or underbalanced drilling. Therefore, downhole valves have been developed to isolate fluid pressure below the valve. They have been variously called “Downhole Deployment Valves” (DDV) or “Downhole Isolation Valves” (DIV). Technical literature includes reports of the usage of such valves in Under-Balanced Drilling (UBD) For example, SPE 77240-MS, “Downhole Deployment Valve Addresses Problems Associated with Tripping Drill Pipe During Underbalanced Drilling Operations,” S. Herbal et al, 2002, described uses of such valves in industry. The DDV or DIV as a tool in the broad area of “Managed Pressure Drilling” can be generally surmised from the survey lecture “Managed Pressure Drilling,” by D. Hannagan, SPE 112803, 2007. There it is listed under “Other Tools” and called a “Downhole Casing Isolation Valve” (DCIV) or “Downhole Deployment Valve.” Services and products for providing Managed Pressure Drilling have been commercialized by AtBalance of Houston, Tex., Weatherford International, Inc. of Houston, Tex. and other companies. 
         [0005]    A DCIV is placed in a casing at a selected depth, considering conditions that may be encountered in drilling the well. The valve is normally placed in an intermediate casing string, and the effective Outside Diameter (OD) of the valve is limited by the Inside Diameter (ID) of the surface casing through which it must pass. For example, in 9⅝-inch intermediate casing, the valve preferably will be full-opening (have a bore at least equal to the ID of the 9⅝ inch casing, about 8.681 inches, or at least be as large as the drill bit to be used) and must pass through the drift diameter of the surface casing, which may be 10.5 inches. Therefore, the valve must be designed to severely limit the thickness of the valve body while being large enough for a bit to pass through. 
         [0006]    A DCIV is disclosed in U.S. Pat. No. 6,209,663. A flapper valve is illustrated, but other types of valves, such as ball valves or other rotary valves are disclosed. The valves may be mechanically operated or operated by biasing means (e.g., springs). U.S. Pat. No. 6,167,974 discloses a flapper-type DCIV valve that is operated by a shifting device that is carried on a drill bit and deposited in the valve when the drill string is tripped out of the well. 
         [0007]    Prior art valves relying on a flapper mechanism have been commercially successful, but improvements in reliability and absence of leakage are needed. A rotary valve having minimum difference between outside diameter and inside diameter is needed. The ability of the valve to seal with differential pressure in two directions is also preferred. 
         [0008]    It should be understood that valves designed for downhole isolation may also be used for a variety of purposes. In wells, there may be a need to open or close a valve to control pressure near the bottom of the well when the hydrostatic pressure of fluid in the well is higher than desired, or there may be a need to isolate pressure in a well bore drilled from another well bore. In industry, valves requiring a minimum of wall thickness between the interior passage through the valve and the exterior surface of the valve may be needed for a variety of applications in any industry utilizing mechanical techniques. 
       SUMMARY OF INVENTION 
       [0009]    A mechanically activated, bi-directional (will isolate fluid pressure in either direction) valve is disclosed, referred to herein as the Mechanical Bi-directional Isolation Valve (MBIV). The valve element is mounted on a hinge plate assembly. As a protective sleeve exposes the “Wedgelock” (sealing element having curved surfaces), the hinge plate assembly will move the valve into the closed position. When the protective sleeve moves in the opposite direction, the hinge plate assembly will move the Wedgelock into the open position. After closing, the valve is locked into position by a locking sleeve to isolate fluid pressure differential across the valve in either direction. 
     
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
         [0010]      FIG. 1  is a sketch of a well having an MBIV in an intermediate casing. 
           [0011]      FIG. 2  is a composite drawing showing the segments in the following detailed drawings of the valve in the open position. 
           [0012]      FIG. 3  is a composite drawing showing the segments in the following detailed drawings of the valve in the closed position. 
           [0013]      FIGS. 2   a - 2   h  illustrate the valve disclosed herein in the open position. 
           [0014]      FIGS. 3   a - 3   h  illustrate the valve disclosed herein in the closed position. 
           [0015]      FIG. 4  is an isometric view of the “Wedgelock” in the open position. 
           [0016]      FIG. 5  is an isometric view of the Wedgelock hinge assembly. 
           [0017]      FIG. 6  is an isometric view of the Wedgelock in the partially closed position. 
           [0018]      FIG. 7  is an isometric view of a protective sleeve with an upper valve seat area. 
           [0019]      FIG. 8  is an isometric view of the Wedgelock. 
           [0020]      FIG. 9  is an isometric view of a lower valve seat with valve seat area. 
           [0021]      FIG. 10  is an isometric view of a hinge plate for the Wedgelock. 
           [0022]      FIG. 11  is an isometric view of a spring for the Wedgelock. 
           [0023]      FIG. 12  is an isometric view of a split ring of the valve assembly. 
           [0024]      FIG. 13  is an isometric view of the spring-loaded actuation assembly on the bottom-hole assembly. 
       
    
    
     DETAILED DESCRIPTION 
       [0025]      FIG. 1  illustrates well  10  that is being drilled. As an example, surface casing  12  has been placed in the well. Intermediate casing  14 , containing the MBIV  20 , used as a downhole casing isolation valve, has also been placed in the well. Inside diameter  21  of the MBIV  20  must be large enough to allow passage of drill bit  16  on the drill pipe  15 . The MBIV  20  disclosed here is adapted to allow a lesser difference in diameter between the inside diameter  21  of MBIV  20  and the inside diameter of intermediate casing  14  than is allowed by downhole isolation valves cited in the references disclosed above. MBIV  20  is mechanically actuated by actuation assembly on the BHA  22  as drill bit  16  and drill pipe  15  travel in and out of the well  10 . 
         [0026]    The MBIV assembly is illustrated in sectional views  2   a - 2   h  and  3   a - 3   h . In  FIG. 2 , the valve is in the open position and in  FIG. 3  it is in the closed position Some parts of the valve assembly extend over multiple figures. 
         [0027]      FIG. 2   a  shows upper connection housing  130 . Threads on upper connection housing  130  are adapted for joining to the casing in which the MBIV  20  is to be employed. 
         [0028]      FIG. 2   b  shows upper connection housing  130  which is joined to the uphole end of upper release housing  126 . Upper release housing  126  is joined to intermediate housing  85  on its downhole end. This joining may be a threaded connection, as shown. Upper locking sleeve  110  is placed in upper release housing  126 . Upper locking sleeve split ring  118  is expanded into upper release housing downhole split ring groove  117 . Upper release housing uphole split ring groove  116  is also shown.  FIG. 2   b  also shows upper locking sleeve actuation groove  112  with upper locking sleeve actuation groove uphole chamfer  113  and upper locking sleeve actuation groove downhole chamfer  114 , which are used for locking the tool. 
         [0029]      FIG. 2   c  shows intermediate housing  85  connected to the upper release housing  126  on its uphole end and to spline housing  68  on its downhole end. This joining may be a threaded connection. Upper locking sleeve  110  and upper locking tube  88  are located inside intermediate housing  85 . Upper locking fingers  120  are shown in the unlocked position on the outside diameter of upper locking tube  88 . Upper locking groove  102 , located on the outside diameter of upper locking tube  88 , is also shown.  FIG. 2   c  also shows the upper locking tube actuation groove  103  and the upper locking tube actuation groove uphole chamfer  104  located on the inside diameter of the upper locking tube  88 . Upper positioning ring  122  shouldering on the intermediate housing shoulder limit  125  is also shown. 
         [0030]      FIG. 2   d  shows spline housing  68  connected to intermediate housing  85  on its uphole end and carrier sleeve housing  80  on its downhole end. This joining may be a threaded connection. Upper locking tube actuation groove downhole chamfer  105  is located on the inside diameter of upper locking tube  88  and protective sleeve  52  is located inside the spline housing  68 . Upper locking tube  88  with intermediate housing shoulder limit A  101  is also shown. 
         [0031]      FIG. 2   e  shows carrier sleeve housing  80  connected to spline housing  68  on its uphole end and to the “Wedgelock” housing  84  on its downhole end. This joining may be a threaded connection. Carrier sleeve housing  80  contains the connection between upper locking tube  88  and valve body  97 . Shown also are protective sleeve shoulder limit  51  of protective sleeve  52  to spline housing  68 , and a pressure equalization configuration consisting of protective sleeve  52 , protective sleeve pressure equalization ports  64 , valve body pressure equalization ports  98 , carrier housing pressure equalization cavity  91  and valve body pressure equalization seal  100 . Shown also is protective sleeve actuation groove  54 , protective sleeve actuation groove uphole chamfer  56  and protective sleeve actuation groove downhole chamfer  57 . Valve body split ring  99  is placed on the inside diameter of valve body  97  and may be expanded into protective sleeve uphole split ring groove  58 . Protective sleeve downhole split ring groove  59  is also shown. 
         [0032]    The term “Wedgelock” is used herein to identify the sealing element of the valve. It preferably has two curved surfaces, and may be formed by machining curved surfaces from round stock, the surfaces being separated by the selected thickness of the valve element, to form a “saddle-like” shape. The thickness is selected according to the pressure differential expected across the valve. 
         [0033]      FIG. 2   f  shows Wedgelock housing  84  connected to carrier sleeve housing  80  on its uphole end and to lower locking housing  41  on its downhole end. Wedgelock  70  and hinge assembly  72 , shown in the open position, is covered by protective sleeve  52  and debris sleeve  50  forming Wedgelock pocket  82 . Any joining connection may be threaded. Shown also are valve body  97  with lower valve seat  96 , lower lock housing split ring  86 , lower locking tube open split ring groove  94 , valve body shoulder limit  106  and lower lock housing shoulder limit  43 . 
         [0034]      FIG. 2   g  shows lower lock housing  41  joined to the Wedgelock housing  84  on its uphole end and to lower connection housing  36  on its downhole end. This joining may be a threaded connection. Lower locking tube  92  also contains the lower locking sleeve  30  with open locking groove  93  on its outside diameter, lower locking fingers  40  and lower positioning ring  45 .  FIG. 2   g  also shows lower connection housing split ring  39 , positioned in lower connection housing  36 , expanding into lower connection housing open split ring groove  37  and lower connection housing closed split ring groove  38 . Shown also are lower locking tube closed split ring groove  95 , lower locking sleeve actuation groove  32 , lower locking sleeve actuation groove downhole chamfer  34  lower locking sleeve actuation groove uphole chamfer  33 , lower lock housing shoulder limit  44  and lower connection housing shoulder limit  42 . 
         [0035]      FIG. 2   h  shows intermediate housing  85  connected to lower connection housing  36  on its downhole end. This connection may be a threaded connection.  FIG. 2   h  also shows the lower end of the lower locking sleeve  30  with the lower locking sleeve actuating groove  32 . 
         [0036]      FIG. 3   a  shows upper connection housing  130 . Threads on upper connection housing  130  are adapted for joining to the casing in which MBIV  20  is to be employed. 
         [0037]      FIG. 3   b  shows upper connection housing  130 , which is joined to upper release housing  126  on its uphole end and to intermediate housing  85  on its downhole end. This joining may be a threaded connection as shown. Upper locking sleeve  110  is located in upper release housing  126 . Upper locking sleeve split ring  118  is expanded into upper release housing uphole split ring groove  116 . Upper release housing downhole split ring groove  117  is also shown.  FIG. 3   b  also shows upper locking sleeve actuation groove  112  with upper locking sleeve actuation groove uphole chamfer  113  and upper locking sleeve actuation groove downhole chamfer  114  used for locking the tool. In the closed position upper locking tube  88  is shown. 
         [0038]      FIG. 3   c  shows intermediate housing  85  connected to the upper release housing  126  on its uphole end and to spline housing  68  on its downhole end. This joining may be a threaded connection. Upper locking sleeve  110  and the upper locking tube  88  are located inside intermediate housing  85 . Upper locking fingers  120  are shown in the locked position on the outside diameter of upper locking tube  88 . Upper locking groove  102  located on the outside diameter of upper locking tube  88  is also shown.  FIG. 3   c  also shows upper locking tube actuation groove  103 , upper locking tube actuation groove uphole chamfer  104  and upper locking tube actuation groove downhole chamfer  105  located on the inside diameter of upper locking tube  88 . Upper positioning ring  122  shouldering on intermediate housing shoulder limit  125  is also shown. 
         [0039]      FIG. 3   d  shows spline housing  68  connected to intermediate housing  85  on the uphole end and carrier sleeve housing  80  on the downhole end. This joining may be a threaded connection. Protective sleeve  52  is located inside intermediate housing  85 . Shown also is upper locking tube  88  with intermediate housing shoulder limit  101 , protective sleeve  52  with protective sleeve actuation groove  54 , protective sleeve actuation groove uphole chamfer  56  and protective sleeve actuation groove downhole chamfer  57 . 
         [0040]      FIG. 3   e  shows carrier sleeve housing  80  as shown connected to spline housing  68  on its uphole end and to wedgelock housing  84  on its downhole end. This joining may be a threaded connection. Carrier sleeve housing  80  contains the connection between the upper lock tube  88  and the valve body  97 . Shown also are protective sleeve shoulder limit  51  of protective sleeve  52  connected to spline housing  68 , an overpressure equalization arrangement consisting of protective sleeve pressure equalization polls  64 , valve body pressure equalization ports  98 , carrier housing pressure equalization cavity  91 , and valve body pressure equalization seal  100 . The lower portion of  FIG. 3   e  shows debris sleeve  50 , hinge assembly  72  and “Wedgelock”  70  in the closed position. Valve body split ring  99 , located on the inside of valve body  97 , and expands into the protective sleeve uphole split ring groove  58 . Protective sleeve downhole split ring groove  59  is also shown. 
         [0041]      FIG. 3   f  shows Wedgelock housing  84  connected to carrier sleeve housing  80  on its uphole end and to lower locking housing  41  on its downhole end Wedgelock  70  and hinge assembly  72  are shown in the closed position. Any joining connection may be threaded. Shown also is valve body  97  with lower valve seat  96 , lower lock housing split ring  86 , lower locking tube open split ring groove  94 , lower locking tube closed split ring groove  95 , lower lock housing shoulder limit  43 , valve body shoulder limit  106  and lower locking tube  92 . 
         [0042]      FIG. 3   g  shows lower lock housing  41  joined to the Wedgelock housing  84  on the uphole end and to lower connection housing  36  on it downhole end. This joining may be a threaded connection. Lower locking tube  92  also contains lower locking sleeve  30  with open locking groove  93  on its outside diameter, lower locking fingers  40  and lower positioning ring  45 .  FIG. 3   g  also shows lower connection housing split ring  39 , positioned in the lower connection housing  36 , expanding into lower connection housing closed split ring groove  38  lower connection housing open split ring groove  37 . Shown also are lower lock housing shoulder limit  44 , lower connection housing shoulder limit  42 , lower locking sleeve actuation groove  32  with lower locking sleeve actuation groove downhole chamfer  34  and lower locking sleeve actuation groove uphole chamfer  33 . 
         [0043]      FIG. 3   h  shows intermediate housing  85  connected to the lower connection housing  36  on its downhole end. This connection may be a threaded connection.  FIG. 3   h  also shows the lower end of lower locking sleeve  30  with lower locking sleeve actuating groove  32 . 
         [0044]      FIG. 4  shows an isometric view of Wedgelock  70  in the open position with upper valve seat area  62 . 
         [0045]      FIG. 5  shows an isometric view of hinge assembly  72  with springs  74 , sliding hinge  78  and a hinge pin  73 . 
         [0046]      FIG. 6  shows an isometric view of Wedgelock  70  in the closing position. 
         [0047]      FIG. 7  shows an isometric view of protective sleeve  52  and upper valve seat area  62 . 
         [0048]      FIG. 8  shows an isometric view of Wedgelock  70  with guide pin track  63 . 
         [0049]      FIG. 9  shows an isometric view of lower valve seat  96  with lower valve seat area  90  and guide pins  61 . 
         [0050]      FIG. 10  shows an isometric view of sliding hinge  78 . 
         [0051]      FIG. 11  shows an isometric view of a spring  74 . 
         [0052]      FIG. 12  shows an isometric view of a typical split ring. 
         [0053]      FIG. 13  shows an actuation assembly that may be mounted on BHA  22  and drill pipe  15  to actuate the valve mechanisms when drill pipe  15  and drill bit  16  move through the valve. Retractable, spring-loaded dogs  23  are adapted to enter actuation grooves in the valve that are identified below, which applies forces to move the various elements of the valve. 
         [0054]    To move MBIV  20  from the open position to a closed position after drill bit  16 ,  FIG. 1 , is raised to a location below the MBIV  20 , BHA  22  moves through lower locking sleeve  30 , ( FIG. 2   g, h ) which will permit spring-loaded dogs  23  mounted on the bottom-hole assembly (BHA)  22  to expand into lower locking sleeve actuation groove  32 , which will then move lower locking sleeve  30  ( FIG. 2   g, h ) uphole. When force F exceeds a predetermined force F 1 , set by geometry of lower connection housing open split ring groove  37  and geometry of lower connection housing split ring  39  in lower connection housing  36 , disengages from the lower connection housing open split ring groove  37 , then lower locking sleeve  30  with connection housing split ring  39  moves uphole and engages with the lower connection housing closed split ring groove  38 . This unlocks lower locking fingers  40  from open locking groove  93  located on the outside of lower locking tube  92 , which enables lower locking tube  92  to freely move uphole. Lower locking tube  92  may be considered to be part of an inner locking tube assembly that consists of lower locking tube  92 , lower valve seat  96 , valve body  97  and upper locking tube  88 . As drill bit  16  continues to travel uphole, spring-loaded dogs  23  on the BHA  22  exert an increasing force F onto lower locking sleeve actuation groove uphole chamfer  33  of lower locking sleeve actuation groove  32 . As force F continues to increase and exceeds a predetermined force F 2 , spring-loaded dogs  23  on BHA  22  will collapse and disengage from the lower locking sleeve actuation groove  32 . 
         [0055]    As drill bit  16  travels uphole, spring-loaded dogs  23  on BHA  22  will exert a force, engage with inside diameter of debris sleeve  50  and move debris sleeve  50  ( FIG. 2   f ) uphole. The drill string continues to move uphole until spring loaded dogs  23  on BHA  22  expand into protective sleeve actuation groove  54  ( FIG. 2   e ) located on the protective sleeve  52 . Continuing the uphole movement, valve body split ring  99  may engage with split ring grooves to allow controlled movements of protective sleeve  52 . This will move protective sleeve  52  uphole with drill bit  16  until protective sleeve  52  reaches protective sleeve shoulder limit  51  in spine housing  68 . As drill bit  16  continues to travel uphole, spring-loaded dogs  23  on BHA  22  exert a force F onto protective sleeve actuation groove uphole chamfer  56  until spring-loaded dogs  23  on the BHA  22  exceed a predetermined limit force F 3 , collapsing and disengaging spring-loaded dogs  23  on BHA  22  from protective sleeve actuation groove  54 . 
         [0056]    The movement of protective sleeve  52  uphole will open Wedgelock pocket  82 , which provided space for Wedgelock  70  in the open position. As this area becomes exposed, Wedgelock  70  is moved into the valve bore area by a force that may be generated by springs  74  mounted on one or more floating hinge assemblies  72 . 
         [0057]    As drill bit  16  continues to travel uphole, spring-loaded dogs  23  on BHA  22  move to and expand into upper locking tube actuation groove  103  ( FIG. 2   d ). Force F is exerted by lower lock housing split ring  86 , located inside lower lock housing  41 , onto lower locking tube open split ring groove  94  in lower locking tube  92  until it exceeds a predetermined force F 4  and disengages. Upper locking tube  88  moves uphole with drill bit  16 . Guide pins  61  ( FIG. 9 ) engage with guide pin track  63  ( FIG. 8 ) located on the downhole side of Wedgelock  70 , which positions lower valve seat area  90  with Wedgelock  70  into upper valve seat area  62  ( FIGS. 4 ,  7 ), located on protective sleeve  52  to establish bi-directional seating. Simultaneously, valve body split ring  99  expands into protective sleeve uphole split ring groove  58 . Wedgelock  70  is mounted on axially floating hinge assembly  72 . 
         [0058]    As drill bit  16  travels uphole, spring-loaded dogs  23  on the BHA  22  exerts a force F onto upper locking tube actuation groove uphole chamfer  104  ( FIG. 2   c ), located on upper locking tube  88  until it disengages from upper locking tube actuation groove  103 . 
         [0059]    As drill bit  16  continues to travel further uphole, spring-loaded dogs  23  on the BHA  22  move to and expand into upper locking sleeve actuation groove  112  located on upper locking sleeve  110  ( FIG. 2   b ) Upper locking sleeve  110  moves uphole with drill bit  16  until a force F from upper locking sleeve split ring  118  exceeds a predetermined limit force F 6  and disengages from upper release housing downhole split ring groove  117  located on upper release housing  126 . As movement continues further uphole, upper locking sleeve split ring  118  will expand into upper release housing split ring groove  116  located on upper release housing  126 . Simultaneously, upper locking sleeve  110  moves over upper locking fingers  120  and forces upper locking fingers  120  to collapse into upper locking groove  102  ( FIG. 2   c ) located on upper locking tube  88 . This locks MBIV  20  into the closed position. 
         [0060]    The spacing, S, between the bottom of drill bit  16  and spring-loaded dogs  23  is a determining factor in the overall length of MBIV  20 . The spacing between Wedgelock  70  and protective sleeve actuation groove  54  must be greater than the spacing S. 
         [0061]    To move MBIV  20  from a closed position to an open position after drill bit  16 ,  FIG. 1 , is lowered to a location above the MBIV  20 , drill bit  16  moves into upper locking sleeve  110 . spring-loaded dogs  23  mounted on BHA  22  will expand into upper locking sleeve actuation groove  112  ( FIG. 3   b ), moving the upper locking sleeve  110  downhole. Upper locking sleeve split ring  118 , located in upper locking sleeve  110 , disengages from upper release housing uphole split ring groove  116  and expands into upper release housing downhole split ring groove  117 . As upper locking sleeve  110  is guided downhole, it disengages upper locking fingers  120  from upper locking groove  102 . This unlocks MBIV  20  from the closed position. 
         [0062]    When upper locking sleeve  110  reaches the intermediate housing shoulder limit B  125  ( FIG. 3   c ), a force F, is exerted by spring-loaded dogs  23  mounted on BHA  22  on upper locking sleeve actuation groove downhole chamfer  114 . When force F exceeds a predetermined force F 8 , spring-loaded dogs  23  on BHA  22  then collapse and disengage from upper locking sleeve actuation groove  112  and continue to travel downhole. 
         [0063]    As actuation assembly on the BHA  22  travels downhole, it will expand into upper lock tube actuation groove  103  and start to move upper locking tube  88  downhole. When valve body equalization seal  100  shifts into the carrier housing pressure equalization cavity  91 , downhole pressure is then released into valve body pressure equalization port  98 . The excess pressure is discharged through the protective sleeve pressure equalization port  64  into the well bore uphole of Wedgelock  70 . The pressure on both sides of Wedgelock  70  is now equalized for safe MBIV  20  operation. Increasing the actuation force F will disengage lower lock housing split ring  86  from lower locking tube closed split ring groove  95 . Lower lock housing split ring  86  will then expand into the lower locking tube open split ring groove  94 . During this operation, lower valve seat  96  moves away from Wedgelock  70 . Actuation tool assembly on the BHA  22  continues to travel downhole until valve body  97  reaches its lower lock housing shoulder limit  43 . A force F is then exerted onto the upper locking tube actuation groove downhole chamfer  105 . When force F exceeds predetermined force F 9  spring-loaded dogs  23  on the BHA  22  collapse and disengage from upper locking tube actuation groove  103 . 
         [0064]    As actuation assembly on BHA  22  travels downhole, it will expand into protective sleeve actuation groove  54  located in protective sleeve  52 . As protective sleeve  52  begins to move downhole, valve body split ring  99  will disengage from protective sleeve downhole split ring groove  59  due to exceeding a force F 10 . Protective sleeve  52  will then continue to move downhole and expand into protective sleeve uphole split ring groove  58 . During this movement downhole, protective sleeve  52  will drive Wedgelock  70  from upper valve seat area  62 . Wedgelock  70  will shift and rotate from the closed position into the open position. After protective sleeve  52  reaches valve body shoulder limit  106  Wedgelock  70  will be contained in Wedgelock pocket  82  and will be isolated from the flow path by protective sleeve  52 . Actuation tool assembly on BHA  22  exerts a force F onto the protective sleeve actuation groove downhole chamfer  57  until it exceeds a predetermined force F 11 , collapsing and disengaging from the protective sleeve actuation groove  54 . 
         [0065]    Spring-loaded dogs  23  on BHA  22  continue to travel downhole engaging and moving debris sleeve  50  downhole until it reaches valve body shoulder limit  106  in order to cover the downhole end of protective sleeve  52 . 
         [0066]    As spring-loaded dogs  23  on BHA  22  continue to travel further downhole, they expand into lower lock sleeve actuation groove  32  located in the lower lock sleeve  30 . As lower lock sleeve  30  moves downhole, a force F is exerted onto the lower connection housing split ring  39  until it disengages from lower connection housing closed split ring groove  38  and expands into the lower connection housing open split ring groove  37 . As lower lock sleeve  30  moves downhole it slides over the lower locking fingers  40  and forces them to collapse into open locking groove  93 . Lower lock sleeve  30  moves downhole until it comes in contact with lower connection housing shoulder limit  42 . Spring-loaded dogs  23  on BHA  22  start to exert a force F onto lower locking sleeve actuation groove downhole chamfer  34 . When force F exceeds a predetermined limit F 12 , spring-loaded dogs  23  on BHA  22  collapse and disengage from lower locking sleeve actuation groove  32 . The MBIV  20  is now locked into the open position. 
         [0067]    The actuation mechanism on the drill pipe that moves the elements of the valve as the drill pipe and drill bit are moved in and out of the wellbore has been illustrated here as spring-loaded dogs  23  on the BHA  22 , but it should be understood that the invention disclosed is not limited to a particular actuation mechanism. For example, the actuation mechanism on the drill pipe that exerts a force to operate the valve may be other spring-loaded or pressure-loaded mechanical arrangements or it may be hydraulically or electrically powered by other apparatus placed on the drill pipe  15  or BHA  22 . A signal to operate the valve actuation mechanism or to turn off the valve actuation mechanism may be programmed into apparatus placed on the drill pipe or may be transmitted from the surface. 
         [0068]    Although the present invention has been described with respect to specific details, it is not intended that such details should be regarded as limitations on the scope of the invention, except as and to the extent that they are included in the accompanying claims.

Technology Classification (CPC): 4