Patent Publication Number: US-9404341-B2

Title: Release tool for a drill string inside blowout preventer

Description:
BACKGROUND INFORMATION 
     1. Technical Field 
     The present disclosure relates to apparatus and methods in the onshore and marine (offshore) hydrocarbon exploration, production, drilling, well completion, well intervention, and leak containment fields. More particularly, the present disclosure relates to release tools for inside blowout preventers. 
     2. Background Art 
     A “blowout (or blow out) preventer”, commonly known as a “BOP”, is a valve that may be used to prevent a well, usually a hydrocarbon producing well, from flowing uncontrollably. An “inside BOP” (also sometimes referred to as an “internal BOP”, “IBOP”, “kelly valve”, or “kelly cock”) is a BOP inside a drillpipe or drillstring, usually used to prevent the well from flowing uncontrollably up the drillstring. Industry standards require having an IBOP for every string of pipe in the hole on every rig that is working. 
     Currently, IBOPs, which may weight 300 pounds or more, have no lifting eyes on their cap (also referred to as a “release tool”) or otherwise, although separate lifting devices that attach to the drillpipe and/or IBOP may have one or more lifting eyes, as taught in U.S. Pat. No. 4,291,762. They have been this way for many years.  FIG. 1  is a side elevation view, partially in cross-section, of a non-limiting representative example of such an IBOP. There are many types of IBOP, and the present disclosure is relevant to all. U.S. Pat. Nos. 2,647,728; 4,403,628; 4694855; 4294314; 4478279; 5,507,467; 8,443,876; 8,443,877; 3,667,557; 3,835,925; 3,861,470; 4,291,762; 7,137,453; 7,950,668, and 7,108,081; and U.S. Published patent application no. 2013/0043044A1 all describe various types of IBOPs and/or accessories for same, such as actuators for IBOPs. Other examples of IBOPs may presently be found on the Internet websites of Global Manufacturing and M&amp;M Industries. All of these patents and published patent applications are incorporated herein by reference. 
     In current practice in the field, the drilling rig workers tie a chain, cable, or strap around the IBOP valve cap to pick up the cap and the IBOP valve to which it is attached using a rig hoist and stab it into the drillpipe. The valve must be open (as shown in  FIG. 1 ) in order to screw it into the drill pipe. If closed the pressure will blow it out before the threads can be started. The drilling rig workers turn the valve clockwise by hand to screw it into the drillpipe. In some instances, rig workers grab side handles (round rods welded to the release tool, as depicted in  FIG. 1 ) and turn it with the round rods. Then they loosen the lock screw to release the rod holding the valve open. Then they tighten the threads with the rig tongs and the well is secure. Mud or other drilling fluid may then be pumped through the valve down hole but no pressurized fluids may come out of the drillpipe. One of the above patents, U.S. Pat. No. 4,403,628, implies in Col. 3 of the patent that assembling an IBOP into a drill stem and removing the IBOP therefrom as just described, including lifting and manipulating the IBOP, is conveniently performed, but this is contrary to experience, as accidents can and have occurred. Rig personnel safety is of utmost concern. The inventor herein personally knows of several accidents where the old style cap/release tool and IBOP valve slipped off the chain, cable, or strap, dropping the IBOP. While the “iron” (slang term for rig tools) is used to being dropped and banged around the rig, the rig workers have the difficult tasks of not only using the rig hoist to pick up the IBOP/release tool, using chains or otherwise, but picking it up straight (vertical or substantially vertical) to align with and screw onto the working drillpipe, which more often than not has fluids and possibly solids escaping out at a high rate. Experience shows that when rig workers are required to make a loop with a chain, cable, rope, or strap around the whole valve (for example around two handles  21 ) it rarely if ever picks up straight; it is then necessary to attempt to get it straight to get threads  20  on the lower end started in the drillpipe threads. In the meantime, the valve or other rig components may shift position and the valve slips off the chain, with potential to injure rig workers, and without stopping flow from the drillpipe. Complications only increase on offshore rigs, whether working subsea or “dry” at the surface on the rig. 
     As may be seen, current practice of installing and removing IBOPs may not be adequate for all circumstances. There remains a need for more robust IBOP release tool designs, particularly for apparatus and methods allowing safe and quick connection/disconnection and ease of alignment, without extra tools, lifting frames, or effort. The apparatus and methods of the present disclosure are directed to these needs. 
     SUMMARY 
     In accordance with the present disclosure, improved release tools for IBOPs and methods of assembling the release tools and IBOPs and using same are described which reduce or overcome many of the faults of previously known tools and methods. 
     A first aspect of the disclosure is a modular release tool body for use with inside blowout preventers comprising:
         a one-piece, formed (defined herein as including milled, machined, molded, cast, machined or milled billet, but not welded or brazed), planar metallic upper section having a longitudinal axis, the upper section comprising a pair of longitudinal members defining a central open region, each longitudinal member having a lower end, the longitudinal members joined by a top manipulating end having one or more lifting features formed therein configured to accept one or more manipulators (cables, chains, straps, ropes), the one or more formed lifting features positioned such that when the release tool body and an inside blowout preventer connected thereto are lifted by the one or more manipulators, they are easily moved over, aligned with, and connected with a working drillpipe while minimizing possibility of slipping off the cables or chains; and   a one-piece, formed, tubular metallic lower section removably attached to the upper section having the same longitudinal axis as the upper section, the lower section comprising a threaded (preferably externally tapered pin) end configured to threadedly mate with an end (preferably a box end) of an inside blowout preventer;
           a central longitudinal bore configured to slidingly accept a release rod;   an upper end formed to accept the lower ends of the longitudinal members of the upper section and retaining members therefore;   the upper end further formed to comprise a central axial extension comprising one or more fluid outlets fluidly connected with the central longitudinal bore, the central axial extension of length sufficient to accommodate an internally threaded bore substantially perpendicular to and intersecting the central longitudinal bore, and configured to accept a mating threaded release rod lock screw therein.   
               

     In certain embodiments, the one or more lifting features may be a single centered lifting eye formed through the top (manipulating) end of the upper section. Certain embodiments may comprise one or more formed, elongate slots in each longitudinal member of size sufficient to define one or more manipulating handles for a rig worker or mechanical manipulator to grasp the upper section and rotate the release tool and thread the pin end of the lower section into the box end of the inside blowout preventer. In certain embodiments the upper end of the lower section may be formed to include a pair of vertical receptacles for the lower ends of the upper section, wherein the retaining members may comprise one or more screws, bolts, pins, and the like threaded (or otherwise positioned and secured) through corresponding threaded (or other) bores through the receptacles and lower ends. In certain embodiments the central open region is sufficiently large to allow a rig worker or mechanical manipulator to engage a release rod and move the release rod downward, opening a valve in the inside blowout preventer. 
     Another aspect of the disclosure is a modular release tool for use with inside blowout preventers comprising: 
     the release tool body; 
     a release rod slidingly positioned in the lower section central bore and dimensioned so as to be accessible by a rig worker or remotely operated device through the central region of the upper section, the central region having a width substantially larger than diameter of the release rod; and 
     one or more formed, elongate slots in each longitudinal member of size sufficient to define one or more manipulating handles for a rig worker or mechanical manipulator to grasp the upper section and rotate the release tool and thread the pin end of the lower section into the box end of an inside blowout preventer. 
     Another aspect of the disclosure is a combination modular release tool and inside blowout preventer for threadedly attaching to a drillpipe, the drillpipe having a threaded end (preferably an enlarged external diameter internally threaded upset end) for engaging the inside blowout preventer, the combination comprising an inside blowout preventer having a lower end threadably engageable with the drillpipe threaded end and an upper box end threadably engaged with a modular release tool of the present disclosure. 
     In addition to the features already mentioned, modular release tools and combinations of release tool/IBOP may further comprising a combination of metallurgy and structural reinforcement such as to prevent failure of the inside blowout preventer and/or release tool upon exposure to inner pressure up to 10,000 psia, or up to 15,000 psia, or up to 20,000 psia, or up to 25,000 psia, or up to 30,000 psia or higher, such as may be experience during onshore or offshore subsea drilling operations. Especially for offshore subsea applications, certain embodiments may further comprise one or more of the following features: one or more subsea hot stab ports for subsea ROV (remotely operated vehicle) intervention and/or maintenance of the inside blowout preventer and/or release tool; one or more ports allowing pressure and/or temperature monitoring inside the inside blowout preventer and/or release tool; one or more subsea umbilicals fluidly connected to one or more locations on the IBOP selected from the group consisting of a kill line, a choke line, and both kill and choke lines, optionally wherein one of the umbilicals is fluidly connected to a subsea manifold. 
     Another aspect of the disclosure is a method of easily and safely attaching a combination inside blowout preventer and modular release tool having a lower threaded end to a threaded end of a working drillpipe, the method comprising the steps of:
         (a) assembling the combination;   (b) pressing down on a top end of the release rod, moving the release rod down into a position holding a valve of the inside blowout preventer open;   (c) locking the valve open by tightening the release rod lock screw;   (d) lifting the combination of step (c) to a position over the drillpipe threaded end using the one or more formed lifting features on the release tool;   (e) threading the combination of step (c) onto the drillpipe and continue turning the combination of step (c) so that the threads of the lower end of the inside blowout preventer thread into the threads of the drillpipe; and   (f) loosening the release rod lock screw, allowing closing of the valve and stopping flow of fluid through the inside blowout preventer.       

     An important feature of the apparatus and methods disclosed herein is the modularity, that is, the lower and upper sections of the release tool body may quickly and easily be disassembled, and the same upper section joined and used with another lower section of same or different outside diameter, such as if a one section cracks or otherwise becomes unusable. In certain embodiments the lower section may be changed to accommodate a different diameter working drillpipe, although that may rarely occur. In certain embodiments, the method comprises changing the lower section of the release tool body to match size (outside diameter) of another inside blowout preventer prior to attaching the release tool to the other inside blowout preventer. 
     These and other features of the apparatus and methods of the disclosure will become more apparent upon review of the brief description of the drawings, the detailed description, and the claims that follow. 
    
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
       The manner in which the objectives of this disclosure and other desirable characteristics can be obtained is explained in the following description and attached drawings in which: 
         FIG. 1  is a schematic side elevation view, partly in cross-section, of a prior art combination inside blowout preventer and release tool; 
         FIG. 2  is a schematic perspective view of one release tool body embodiment within the present disclosure; 
         FIGS. 3A and 3B  illustrate schematic side elevation and plan views, respectively, of the lower section of the release tool body embodiment illustrated in  FIG. 2 , while  FIG. 3C  is a side elevation view of a release rod lock screw useful therewith; 
         FIG. 4  is a schematic side elevation view, partly in cross-section, of a combination inside blowout preventer and release tool within the present disclosure; and 
         FIGS. 5A, 5B, 5C, and 5D  are schematic perspective, side elevation (partially in phantom), reverse side elevation, and end views, respectively of an optional shaft collar useful in certain embodiments; 
         FIGS. 6A, 6B, and 6C  are schematic perspective, end, and side elevation (partially in phantom) views, respectively, of an optional rod cap useful in certain embodiments; 
         FIG. 7  is a logic diagram of a method of installing the combination of  FIG. 4  onto a working drillpipe; 
         FIG. 8  is a side elevation view of another embodiment of the disclosure; 
         FIG. 9  is a perspective view of another embodiment of the disclosure; and 
         FIG. 10  is a side elevation view of the embodiment of  FIG. 9 . 
     
    
    
     It is to be noted, however, that the appended drawings of  FIGS. 1-6 and 8-10  may not be to scale, and illustrate only typical apparatus embodiments of this disclosure. Furthermore,  FIG. 7  illustrates only one of many possible methods of this disclosure. Therefore, the drawing figures are not to be considered limiting in scope, for the disclosure may admit to other equally effective embodiments. 
     DETAILED DESCRIPTION 
     In the following description, numerous details are set forth to provide an understanding of the disclosed apparatus, combinations, and methods. However, it will be understood by those skilled in the art that the apparatus, combinations, and methods disclosed herein may be practiced without these details and that numerous variations or modifications from the described embodiments may be possible. All U.S. published patent applications and U.S. Patents referenced herein are hereby explicitly incorporated herein by reference, irrespective of the page, paragraph, or section in which they are referenced. 
     The primary features of the apparatus, combinations, and methods of the present disclosure will now be described with reference to the drawing figures, after which some of the construction and operational details, some of which are optional, will be further explained. The same reference numerals are used throughout to denote the same items in the figures. 
     One aspect the present disclosure is a replacement for a release tool  14  ( FIG. 1 ) that is already on at least 1000 drilling rigs in operation today. The primary focus was to replace the old release tools  14  with a new design (one embodiment  100  of which is illustrated in schematic perspective view in  FIG. 2 ) so rig workers or rig tools operated by rig workers could place chain or other lifting attachment through a lifting eye, and also provide hand slots to “make it up” (slang term for attaching two oilfield components, here the new release tool to an IBOP). 
     Prior to explaining features of the new release tool and other inventive aspects, reference should be made to  FIG. 1 , which is a schematic side elevation view, partly in cross-section, of a prior art combination 1 of an inside blowout preventer and release tool  14  known under the trade designation “WN-2 Inside BOP Dart Valve”, available from WNCO Valve International, Odessa, Tex. (USA). The inside blowout preventer (“IBOP”) includes an upper sub  2  and a lower sub  4  joined using tapered threads as illustrated. One-piece IBOP bodies are also known, and the release tools of the present disclosure are applicable to either variety of IBOP body. The IBOP may include a spring  6  biased to push up a dart  8  into mating relationship with a dart “O” ring  10  and dart seat  12 . Other types of IBOP may feature a check valve (flap valve), and the release tools of the present disclosure are suitable for use with any type of IBOP. Lower sub  4  includes a lower threaded end  20  (either pin or box, usually a pin end as illustrated) to threadably mate with a working drillpipe (either box or pin end, usually a box end). The drillpipe is not illustrated. 
     Still referring to  FIG. 1 , prior art release tool  14  includes a lower body  15  that mates with upper sub  2 . Usually, lower body  15  includes external tapered threads and upper sub  2  includes mating internal tapered threads, as illustrated, but other arrangements are possible. Prior art release tool  14  further includes a release rod  16  that extends through a bore of an axial extension  17 , and a rod lock screw  18 , the operation of which are very familiar to those of ordinary skill and require no further explanation. Some axial extensions include an open or closed archway such as  19 , and some suppliers may provide one or more lateral “grab handles”  21  welded to the axial extension if asked for by rig workers or rig owners (or rig workers/owners may weld them on after purchasing them). 
     Using prior art release tools such as  14 , rig workers would attempt to lift and move the combination IBOP/release tool into position over a working drillpipe for attachment using a rig hoist. The problem is that the open archway  19 , if present, and/or lateral grab handles  21 , are not lifting eyes. They are hard to tie onto. Rig workers formerly would wrap a manipulator (chain, cable, strap, or rope) around the grab handles  21  and pick up the device using the rig hoist, align threads  20  with threads of the working drillpipe, and turn (rotate) the IBOP/release tool using grab handles  21 , with or without a chain tongs. The IBOP may weigh from 200 to 300 pounds (91 to 136 kg). Injury to rig workers is of utmost concern. While the “iron” (oilfield term for rig tools) is accustomed to being dropped and banged around the rig, the rig workers have the difficult tasks of not only picking up the IBOP/release tool using the rig hoist, but picking it up straight (vertical or substantially vertical) to align with and screw onto the working drillpipe, which more often than not has fluids and possibly solids escaping out at a high rate. Experience shows that when rig workers are required to make a loop with a chain, cable, strap, or rope around the whole valve (for example around two handles  21 ) it rarely if ever picks up straight; it is then necessary to attempt to get it straight to get threads  20  started in the drillpipe threads. In the meantime, the valve or other rig components shift position and the valve slips off the chain, with potential to injury rig workers, and without stopping flow from the drillpipe. 
     With these problems in mind, the release tools of the present disclosure were developed.  FIG. 2  is a schematic perspective view of one release tool body embodiment  100  within the present disclosure. Release tool body  100  includes an upper “flat iron” section  22  having a longitudinal axis “L”, and a lower tubular section  24  of same longitudinal axis. Upper section  22  is comprised of two longitudinal members  26 ,  28 , joined by a top manipulating end  30 . Upper section  22  is a one-piece, formed, planar, metallic component with no welds, brazing or components welded or brazed thereto. This eliminates the need for pull testing (tensile testing) in offshore applications. Longitudinal members  26 ,  28  define a central open region  54  there between, each longitudinal member having a lower end  34 ,  36 , respectively. Top manipulating end  30  includes one or more lifting features  32  formed therein configured to accept one or more manipulator cables or chains (not illustrated), the one or more formed lifting features  32  (lifting eye in  FIG. 2 ) positioned such that when the release tool body  100  and an inside blowout preventer connected thereto (such as depicted schematically in  FIG. 4 ) are lifted by the rig hoist using cables, chains, and like manipulators, they are easily moved over, aligned with, and connected with a working drillpipe while minimizing possibility of slipping off the cables or chains. Severe injury to rig workers is thereby avoided, or at least the possibility greatly reduced, compared with previous designs. 
     Still referring to  FIG. 2 , upper section  22  includes, in embodiment  100 , a pair of elongate formed slots  56 ,  58 , one each in this embodiment formed into and through longitudinal members  28 ,  26 , respectively. Elongate formed slots  56 ,  58  serve as handles for turning release tool  100  and IBOP attached thereto, (as illustrated in  FIG. 4 ) when positioned and aligned with a working drillpipe. It will be appreciated that more than one slot (or other shaped) through-holes, may be provided in each longitudinal member  26 ,  28 . It is not necessary that slots  56 ,  58 , be the same length or shape; however, in order to provide the best weight balance, and therefore best ease of positioning and making up to the drillpipe, it is preferred that longitudinal member  26  be a substantial mirror image of longitudinal member  28 , with slots of substantially equal length and shape. 
     Again referring to  FIG. 2 , lower section  24  includes a threaded end  38 , illustrated in  FIG. 2  as a pin end, having a central bore  40  illustrated in phantom. Central bore  40  continues up through a lower portion of an axial extension  48 , with central bore  40  having a diameter substantially equal to a generally perpendicular fluid outlet port  50  in axial extension  48 . Central bore  40  and outlet port  50  fluidly cooperate to direct flow of fluids and other matter out of release tool  100  while it and the IBOP to which it is attached are being secured to the working drillpipe. Outlet port  50  may be a bore substantially perpendicular to longitudinal axis L, but that is not strictly required. More than one outlet port may be provided as well. Axial extension  48  also includes a central bore  52  having a diameter slightly larger than a release rod (not illustrated in  FIG. 2 ), the release rod being in sliding engagement with central bore  52 . Lower section  24  further includes a pair of formed receptacles  42 ,  44 , perhaps more clearly illustrated in  FIGS. 3A and 3B  and discussed further herein below. Formed receptacles  42 ,  44  serve to accept and retain lower ends  34 ,  36  of longitudinal members  26 ,  28 , in conjunction with retaining screws, bolts, pins or other components (not shown) inserted through passages  46  (two passages  46  for retaining screws, bolts or pins are illustrated for each receptacle  42 ,  44 ). 
     Referring now specifically to  FIGS. 3A and 3B ,  FIG. 3A  illustrates a schematic side elevation view, and  FIG. 3B  a plan view, respectively, of lower section  24  of the release tool body embodiment  100  illustrated in  FIG. 2 . ( FIG. 3C  is a side elevation view of a release rod lock screw  62  useful therewith; as this component is well-known it is not further discussed in detail, except to note that a threaded through hole  60  is provided in axial extension  48  to accommodate threads  64  of rod lock screw  62 , which is turned using handles  66 ,  68 .) As illustrated in the plan view of  FIG. 3B , receptacles  42  and  44  may each be formed into lower section  24  to form a pair of slots  43 ,  45  (slot  43  formed between sub-receptacles  42   a ,  42   b , and slot  45  formed between sub-receptacles  44   a ,  44   b , as illustrated). Slots  43 ,  45  accept ends  34 ,  36  of longitudinal members  26 ,  28 , as previously explained. It should be noted that in alternative embodiments considered within the present disclosure, ends  34 ,  36  could be formed to form a female connection to fit onto male members  42 ,  44 , respectively. Since torque is effected on upper section  22  when making up to a working drillpipe, the embodiment illustrated in  FIGS. 2 and 3  may be preferred as being somewhat stronger. Slots  43 ,  45  are formed out of the bottom section so that no welding, brazing, or other heat-formed attachment is involved. 
     In practice, upper section  22  with lifting eye  32  is interchangeable with all lower sections  24  so that a relatively small batch of upper sections  22  could be made and distributed, whereby a user (rig owner and rig workers) could fit a single upper section  22  on multiple lower sections  24  to fit corresponding sizes of IBOP, in turn corresponding to a variety of sizes of working drill pipe as a well is drill or otherwise worked. While not strictly necessary, the hand holds formed by longitudinal members  26 ,  28  and slots  56 ,  58  are preferably flat (planar). For subsea use they maybe painted or otherwise colored or made reflective for ease of recognition. Structurally, the new release tool bodies of the present disclosure may support a weight of 3000 pounds (1360 kg) or more when made of 4140HT steel, or equivalent material. 
       FIG. 4  is a schematic side elevation view, partly in cross-section, of a combination inside blowout preventer and release tool  200  within the present disclosure. Quickly aligning and threadably attaching an IBOP to a working drillpipe in the event of a blowout or impending blowout is recognized in the art. What has not been recognized or realized is an apparatus and method to accomplish this without significant risk of the apparatus slipping off lifting devices. As explained previously, external frames have been designed, some with lifting eyes, for effecting alignment, but these add cost and complexity to the procedure, or if available are not necessarily used or favored by rig personnel. Or the prior art simply states that alignment and connection is conveniently done without such external frames, using welded-on handles. The present inventor, however, knows such is not always the case, and knows of multiple accidents that have injured rig workers. 
     Lower section  24  is illustrated as threaded into upper sub  2  of a prior art IBOP, such as previously disclosed in relation to  FIG. 1 , or some other prior art IBOP. One or more subs  70   a ,  70   b , and/or  70   c  may optionally be supplied, especially for subsea use. For example, one or more subs  70   a ,  70   b ,  70   c  may connect to a hydrate inhibition chemical supply line, and when circulating the chemical, it may return to a surface vessel through a return line via a second sub. One or more subs  70   a ,  70   b ,  70   c  may connect a surface chemical supply to subsea choke and kill valves via choke and/or kill lines. One or more of subs  70   a ,  70   b ,  70   c  may be hot stab connections, such as API  17 H standard hot stabs, or a pressure gauge, or facilities to allow other kill line parameters to be measured, for example, temperature, viscosity, and the like. 
       FIGS. 5A, 5B, 5C, and 5D  are schematic perspective, side elevation (partially in phantom), reverse side elevation, and end views, respectively of an optional shaft collar  72  useful in certain embodiments. Referring again to  FIG. 4 , shaft collar  72  provides a “lock on” item to release rod  16  so users can tell if the valve of the IBOP is open or closed. A rig hand or other worker would press down on top of release rod  16 , forcing dart  8  down and compressing spring  6 , forcing open the valve, then turn release rod lock screw  62  (not shown in  FIG. 4 ) to lock the valve open. A worker then will slide on a shaft collar  72  and move it all the way down next to top of central axial extension  48 , clamping and locking shaft collar  72  closed using lever  73 . Workers or other sensor may then visually see or otherwise detect that when shaft collar  72  rises or is at its upper-most position, the IBOP valve is closed. If shaft collar  72  is down all the way to central axial extension  48 , the IBOP valve is open. 
     In certain embodiments, such as illustrated, shaft collar  72  may be a quick-release one-piece clamp-on shaft collar having a body  74  and a clamp lever  73  attached thereto by a pin or other attachment. Clamp lever  73   a  is illustrated in phantom in its open position in  FIG. 5B , with double-headed arrow showing movement of clamp lever  73  to closed position. Body  74  may include one or more expansion slits or gaps  75 . Body  74  includes an inner surface  76 , preferably smooth so as not to mar release rod  16  when clamp lever  73  is closed. Shaft collar  72  further includes a set screw  77  for adjusting the clamping action. Set screw  77  may include a socket head  78 , as illustrated in  FIG. 5D . Dimensions A, B, and C may vary, and will largely be dictated by diameter of release rod  16 . Dimension A may range from about 20 to about 60, or from about 30 to about 50 mm; dimension B may range from about 10 to about 30, or from about 10 to about 20 mm; and dimension C may range from about 5 to about 20, or from about 5 to about 10 mm. Quick-release one-piece clamp-on shaft collars with A=1.5 inch (about 38 mm), B=⅝ inch (about 16 mm), and C=0.4 inch (about 10 mm) are commercially available from McMaster-Carr Supply Company, Chicago, under trade designation 1511K13. 
     In certain embodiments, an optional rod cap  80  may be placed on the top of release rod  16  to make it easier to push down.  FIGS. 6A, 6B, and 6C  are schematic perspective, end, and side elevation (partially in phantom) views, respectively, of an optional rod cap  80  useful in certain embodiments. In embodiment  80 , rod cap  80  includes a flange or lateral extension  81  having a knurled rim  82 , and a hollow shaft  83  having a non-threaded inner surface  84 . Dimensions D, E, F, G, and H may vary, and will largely be dictated by diameter of release rod  16 . Dimension D may range from about 30 to about 90 mm, or from about 50 to about 70 mm; dimension E may range from about 10 to about 30 mm, or from about 10 to about 20 mm; dimension F may range from about 15 to about 30 mm, or from about 20 to about 30 mm; dimension G may range from about 5 to about 25 mm, or from about 10 to about 20 mm; and dimension H may range from about 20 to about 60 mm, or from about 30 to about 50 mm. Rod caps with D=2.5 inch (about 64 mm), E=⅝ inch (about 16 mm), F= 15/16 inch (about 24 mm), G= 9/16 inch (about 14 mm), and H=1.5 inches (about 38 mm) are commercially available from McMaster-Carr Supply Company, Chicago, under trade designation 6121K51. 
       FIG. 7  is a logic diagram of easily and safely attaching a combination inside blowout preventer and release tool having a lower threaded end to a threaded end of a working drillpipe. In certain embodiments, the method first comprises determining whether lower section  24  will make up to the IBOP, which depends on whether the IBOP will make up to the working drillpipe, and if not, changing the lower section  24  of the release tool body  100  ( FIG. 2 ) to match size (outside diameter) of another IBOP (box  302 ). The method further comprises assembling the combination of IBOP and release tool so that it appears as illustrated in  FIG. 4  (box  304 ). The method further comprises pressing down on a top end of the release rod  16 , moving the release rod down into a position holding a valve of the inside blowout preventer open (box  306 ). The method then comprises locking the valve open by tightening the release rod lock screw  62  as shown in  FIG. 3  (box  308 ). The critical steps are then lifting the combination illustrated in  FIG. 4 , with IBOP valve locked open, to a position over the working drillpipe threaded end using the one or more formed lifting features  32  on the release tool, the lifting feature positioned such that when the release tool body and IBOP thereto are lifted by the cables or chains, they are easily moved over, aligned with, and connected with the working drillpipe while minimizing possibility of slipping off the cables or chains (box  310 ). The method continues with the step of threading the combination such as illustrated in  FIG. 4  onto the working drillpipe and continue turning the combination, using formed handles  56 ,  58 , so that threads  20  of the lower end of the IBOP thread into the threads of the working drillpipe (box  312 ). At this stage, if the IBOP is of the type having a check valve therein, as soon as the IBOP is fixed in position on the working drillpipe, no further escape of fluid or liquids will occur. If the IBOP is the type having a valve therein, then the valve may be closed by turning the release rock lock screw  62 , allowing spring  6  to bias dart  8  upward and seal, terminating flow (box  314 ). 
     An important feature of the apparatus and methods disclosed herein is the modularity, that is, the lower and upper sections  22 ,  24  of the release tool body may quickly and easily be disassembled, and the same upper section  22  joined and used with another lower section  24  of same or different outside diameter, for example if the lower section is cracked or otherwise becomes unusable, or if there is a need to change to a different size drillpipe. In certain embodiments, the method comprises determining whether lower section  24  will make up to the IBOP, which depends on whether the IBOP will make up to the working drillpipe, and if not, changing the lower section  24  of the release tool body  100  ( FIG. 2 ) to match size (outside diameter) of another IBOP. 
       FIG. 8  illustrates schematically another embodiment  400  of upper section  22 , illustrating formed slots  56   a ,  56   b ,  58   a , and  58   b , defining generally horizontal hand holds  57 ,  59 . Also provided are a series of formed through holes  61  (12 total illustrated in embodiment  400 , although this number could vary up or down) allowing a pair of hand guards  502 ,  504  ( FIGS. 9, 10 ) to be attached using threaded bolts  506 ,  508  ( FIG. 9 ). A pair of through holes  47   a ,  47   b  are provided for attachment of embodiment  400  to lower section  24  (not illustrated in  FIGS. 8-10 ). The dimensions of lengths, angles, and radii illustrated in  FIGS. 8-10  are typical and not meant to be limiting in any way. Length dimensions to be noted are designated by the following designations: A′, B′, C′, D′, E′, F′, G′, H, I, J, K, M, N, O, P, Q, R, S, T, U, V, W, X, Y, and Z, where Z is the thickness of the entire embodiment  400 , which is preferably 0.5 inch, but could be thicker or slightly thinner, depending on the strength requirements. Furthermore, although the preferred metal for embodiment  400  is aluminum, other metals and/or metal alloys could be used. Aluminum is preferred for its low weight, although billet aluminum may be preferred for its strength and may weigh more than cast aluminum. Angle “α” is noted in embodiment  400  to be 112.5 degrees, but angle α could vary from 90 to about 135 degrees. Furthermore, the diameter of attachment holes  61  is noted in embodiment  400  to be 0.25 inch (at  61   a ), but this dimension may vary, as may the number of such attachment holes. 
     Still referring to  FIG. 8  and embodiment  400 , the various dimensions and their ranges may be as listed in Table 1, acknowledging that dimensions outside of these ranges may be acceptable: 
     
       
         
           
               
             
               
                 TABLE 1 
               
             
            
               
                   
               
               
                 Dimensions of Embodiment 400 
               
            
           
           
               
               
               
            
               
                 Dimension 
                 Embodiment 400 (inch) 
                 Preferred Range (inch) 
               
               
                   
               
            
           
           
               
               
               
            
               
                 A&#39; 
                 10.551 
                 5-25 
               
               
                 B&#39; 
                 2.724 
                 1-10 
               
               
                 C&#39; 
                 1.500 
                 0.5-5   
               
               
                 D&#39; 
                 3.000 
                 1-10 
               
               
                 E&#39; 
                 15.000 
                 10-30  
               
               
                 F&#39; 
                 7.500 
                 5-15 
               
               
                 G&#39; 
                 1.899 
                 1-5  
               
               
                 H 
                 2.100 
                 1-5  
               
               
                 I 
                 5.500 
                 2-10 
               
               
                 J 
                 1.685 
                 1-3  
               
               
                 K 
                 0.776 
                 0.5-2   
               
               
                 M 
                 5.055 
                 2-10 
               
               
                 N 
                 0.250 
                 0.125-2    
               
               
                 O 
                 3.028 
                 1-5  
               
               
                 P 
                 1.000 
                 0.25-3    
               
               
                 Q 
                 0.625 
                 0.25-3    
               
               
                 R 
                 2.89 
                 1-5  
               
               
                 S 
                 4.716 
                 2-10 
               
               
                 T 
                 6.500 
                 3-15 
               
               
                 U 
                 2.500 
                 1-10 
               
               
                 V 
                 2.000 
                 1-5  
               
               
                 W 
                 5.000 
                 3-20 
               
               
                 X 
                 14.50 
                 7-40 
               
               
                 Y 
                 1.500 
                 0.5-5   
               
               
                 Z 
                 0.500 
                 0.3-3   
               
               
                 61a 
                 0.250 
                 0.125-2    
               
               
                   
               
            
           
         
       
     
       FIGS. 9 and 10  illustrate schematic perspective and side elevation views, respectively, of embodiment  500  of upper section  22  of embodiment  400  having two hand guards  502 ,  504  attached thereto using bolts  506 ,  508 . In embodiment  500 , there would be six bolts  506 , and six bolts  508 , corresponding to the twelve through holes  61  illustrated in  FIG. 8 . It will be understood that a similar arrangement would be provided for attaching hand guard  504 , the bolts not being illustrated for clarity. Hand guards  502 ,  504 , are preferably formed from 0.5-inch aluminum pipe that is split in half and milled to provide threaded holes for receiving bolts  506 ,  508 . Embodiment  500  and equivalents thereof provide a lightweight upper section  22 , while providing added protection to workers hands. In other embodiments, one hand guard, say  502  for example, may be attached to the opposite side of upper section  22 , so that one hand guard is on each side of upper section  22 . In yet other embodiments, hand guards  502 ,  504  need not be round or cylindrical in shape, but could for example be box-shaped, elliptical, triangular, pyramidal, and the like. The side elevation view of  FIG. 10  illustrates a preferred arrangement of hand guards  502 ,  504 , in that their inside edges  503 ,  505  are substantially co-extensive with edges of central open region  54 , and their outer edges  507 ,  509  are substantially co-extensive with respective outer edges of the upper section  22 , but this arrangement is not strictly necessary in all embodiments. For example, one or more edges  503 ,  505 ,  507 ,  509  could be rounded inward to allow easier access to hand holds  57 ,  59  ( FIG. 9 ), or rounded outward to provide even more hand protection. 
     The valve in the IBOP, whether a flap valve or dart valve, must stay open at all times during picking up, alignment, and threading onto the working drillpipe. In typical practice, one of the rig workers place their hand on top of the release rod  16  and press&#39;s down. This will press release rod  16  down and compress spring  6  under dart  8  holding the valve open. One of the rig workers will tighten the rod lock screw, then the valve is locked open until the rod lock screw is loosened. Once loosened, spring  6  under dart  8  will expand and slam the valve closed. The release rod  16  will not come completely out of the release tool upper section  22  unless a rig worker unscrews release tool body lower section  24  from upper sub  2  of the IBOP. The IBOP valve must be open in case of an emergency so that rig workers can pick up the complete combination IBOP and release tool using the rig hoist and screw the lower sub threads  20  into the working drillpipe. Drilling fluid, drilling mud, production fluid, and perhaps hydrocarbons and solids may be blowing out the side outlet port  50  while the rig workers are screwing the combination IBOP/release tool into the working drillpipe. Once they have the combination in place they release the rod lock screw  62  and let the valve close and stop the flow of fluid. 
     Thus the apparatus, combinations, and methods described herein provide a quick and safe way of quickly picking up, aligning, and attaching an IBOP to a working drillpipe without extraneous mechanical frames and with significantly reduced risk of injury to rig workers. 
     Certain method embodiments may include using a mobile offshore drilling unit (MODU). Certain method embodiments may comprise disconnecting an umbilical or other flexible conduit using a quick disconnect (QDC) coupling configured as part of one or more subs  70 . Certain subsea method embodiments may include assuring flow of fluid through the IBOP using external wet insulation on at least a portion of the outer IBOP for flow assurance. Certain subsea method embodiments may include assuring flow of fluid through the IBOP using a flow assurance fluid, for example a gas atmosphere in the annulus between the inner and outer body of an insulated IBOP, or hot seawater or other water pumped into the IBOP, or methanol. Certain subsea method embodiments may comprise fluidly connecting a source of hydrate inhibition fluid to the IBOP via one or more subs  70 . 
     Over the past several years, the suitability of using high strength steel materials and specially designed thread and coupled (T&amp;C) connections that are machined directly on the joints at the mill has been investigated. See Shilling et al., “Development Of Fatigue Resistant Heavy Wall Riser Connectors For Deepwater HPHT Dry Tree Risers”, OMAE2009-79518. These connections eliminate the need for welding and facilitate the use of materials like C-110 and C-125 metallurgies that are NACE qualified. The high strength may significantly reduce the wall thickness required, enabling an IBOP to be designed to withstand pressures much greater than can be handled by X-80 materials and installed in much greater water depths due to the reduced weight and hence tension requirements. The T&amp;C connections eliminate the need for 3 rd  party forgings and expensive welding processes—considerably improving apparatus delivery time and overall cost. For onshore use, the release tool and IBOP structural components may be made of 4140HT steel, or equivalent material. 
     From the foregoing detailed description of specific embodiments, it should be apparent that patentable apparatus, combinations, and methods have been described. Although specific embodiments of the disclosure have been described herein in some detail, this has been done solely for the purposes of describing various features and aspects of the apparatus, combinations, and methods, and is not intended to be limiting with respect to their scope. It is contemplated that various substitutions, alterations, and/or modifications, including but not limited to those implementation variations which may have been suggested herein, may be made to the described embodiments without departing from the scope of the appended claims.