Abstract:
A process of manufacturing a well closure apparatus and using it downhole by releasing components contained within the apparatus. The well closure apparatus is an internal bidirectional tubing plug that is adapted for insertion into a tubing string for sealing the tubing string internally while running the tubing into a fluid filled well. The tubing plug is comprised of a body having an inner surface with a recess or passage extending through the body from one end to the other. The recess holds petals and a keystone petal that are held within the recess by a cork and the cork is held in place by a nut. At depth, the tubing is filled with well fluid, the tubing plug is released at a predetermined hydraulic pressure, and the pieces of the releasing components are pumped to the bottom of the well or are circulated out of the well.

Description:
CROSS-REFERENCE TO RELATED APPLICATIONS 
     The present application is a divisional application claiming priority to U.S. patent application Ser. No. 12/806,353 for Internal Bidirectional Tubing Plug filed on Aug. 11, 2010, which in turn claims priority to U.S. Provisional Patent Application Ser. No. 61/276,097 for Bi-directional Internal Tubing Plug filed on Sep. 8, 2009. 
    
    
     BACKGROUND OF THE INVENTION 
     1. Field of the Invention 
     This invention relates to closure means for well conduits. More particularly, it relates to temporary plugs that are removable without mechanical intervention from the surface above the well. More specifically this invention relates to running new or used tubing, known as a work string, into a well filled with drilling mud or water, well fluids, behind a drill bit and drill collars, a packer or open ended as fast and as safely as possible and at the same time directing the displaced well fluid to a pit or tank while preventing the well fluid from entering the tubing, through a bit, a packer, or open ended. 
     It is also desirable to prevent displaced well fluids from being displaced out the surface open end of the tubing into the atmosphere. The displaced well fluids will take the path of least resistance to the atmosphere. If the displaced well fluids are allowed to enter the tubing well fluids will “spray” out the surface open end of the tubing coating the rig, rig crew, stripping rubber, blow out preventers, wellhead, and ground and generally impair safe working conditions. It is also possible to contaminate the ground or create a fire or chemical hazard as some well fluids contain hazardous chemicals and compounds. 
     In general practice the tubing is lowered very slowly into a well to allow the well fluids to drain from the tubing/annulus casing valve, and slow enough to prevent well fluids from spraying out the open end of the tubing. This method of running a tubing string very slowly is costly to well operators due to the additional rig time. It is desirable to run the tubing as fast as possible, in a safe manner, to reduce the well operators cost. 
     One problem is controlling the well fluids from being displaced from the tubing/casing annulus while the tubing is being lowered into the well. This is accomplished by using a “stripping rubber”, as known in the art. The stripping rubber effectively seals the tubing/casing annulus diverting all displaced well fluids up the tubing and out the casing valve at the same time. The casing valve is generally placed on a kill-choke/spool below the blow out preventers. The casing valve is generally opened to a flow line ending at a flow back tank, frac tank, and or an earth pit. The flow lines that are directed to a flow back tank generally have sufficient restriction in them to not be able handle all of the displaced well fluids through the casing valve which causes more of the displaced well fluids to be directed into the tubing and out the end of it at the surface. 
     The second problem is that if the well operator chooses to run a stripping rubber and a drill pipe float valve above the bit, essentially a check valve, all displaced well fluids will be diverted to the casing valve and to a tank or pit. But using a drill pipe float valve causes another problem. 
     The third problem is that when using a drill pipe float valve and stripping rubber circulation of the well fluid may only occur down the tubing and up the tubing/casing annulus. There are situations where this setup may limit the control of the well by not allowing well fluids to be circulated down the tubing/casing annulus and up the tubing. 
     A fourth problem is that when using a drill pipe float valve with a stripping rubber and drilling out any obstructions in a well such as DV tools (known as stage cementing tools in the art), DV rubbers, primary cementing rubbers and any excess cement left in the well, a high circulation rate is necessary to carry all drilled and washed debris up the tubing/casing annulus through the casing valve, flow line, and to a wash tank. If the casing valve or flow line become plugged circulation up the tubing/casing will be lost. If circulation is lost the annulus debris in the annulus will fall down hole around the tubing “sticking” the tubing. To remove the tubing a “fishing” job is required that is very expensive and for this reason this set up is not used by prudent operators. 
     A fifth problem is created when using a wire line (also known as “slick line” in the art) retrievable “blanking plug” as known in the art. One way to prevent well fluids from entering the tubing is to run a wire line retrievable blanking plug, in a tubing nipple, at or above the bottom end of the tubing. A retrievable blanking plug seals off fluid flow in both directions of the tubing. With a blanking plug in place while running the tubing, in conjunction with a stripping rubber, all displaced fluids are diverted through a casing valve. While picking up a new or used work string and running it into the well, mill scale, rust, dirt, tubing dope, and all manner of debris fall down the tubing and land on top of the blanking plug. 
     Once the tubing is at depth the tubing is filled with fluid to equalize differential pressure across the retrievable blanking plug so that it may be removed from the tubing. This is accomplished by running a wireline blanking plug retrieval tool and equalizing prong (in some cases) to release the retrievable blanking plugs latching members from a tubing sub known as a nipple. However, in most cases the tubing debris, a mentioned above, have fallen down and covered the retrievable blanking plug such that the retrievable tool and equalizing prong cannot engage the blanking plug to equalize, release, and pull it from the tubing to the surface. At this time the debris must be washed off the retrievable blanking plug before it is pulled from the tubing. This may be accomplished by using coiled tubing and or snubbing operations or other methods, as known in the art which incur additional cost and time. Sometimes the fluid laden tubing must be pulled from the well. Experience has shown that using a retrievable blanking plug is not a cost effective way to prevent well fluids from entering a tubing string. 
     A sixth problem occurs when running a “pump-out-plug” as known in the art. The pumped-out portion of the pump-out-plug has an outside diameter greater than the internal diameter of the tubing and therefore it may not be circulated out of the well up the tubing. Further, the pumped-out portion of the pump-out-plugs outside diameter is generally of a dimension that prevents is from being circulated from the well up the tubing/casing annulus. Additionally the pumped-out portion of a pump-out-plug is generally made from a metal, generally aluminum, which will fall on top of any cased-hole tools below the pump-out-plug and prevent them from being pulled from the well at a later date as the pumped-out portion may become wedged between the casing internal surface and the outer surface of the cased-hole tools (known as retrievable packers, retrievable bridge plugs, and others) as know in the art. Therefore, in general, pump-out-plugs are only run in a well at the bottom end of a tubing string, sometimes below a retrievable packer, and the pumped-out portion of the pump-out-plug falls into the rat hole at the bottom of the well. Pump-out-plugs are not compatible and with a drill bit. 
     A seventh problem occurs when running a “rupture disk” as known in the art. A rupture disk is run above the bit and drill collars in the tubing in a tubing nipple or a J-J (the small internal area in a tubing collar between the two pin ends of tubing) to prevent well fluid from entering the tubing when it is run into a well full of well fluid. When it is time to establish circulation the tubing is filled with fluid and pressure applied on top of the rupture disk rupturing it and establishing circulation in the well. The debris left in the J-J or tubing nipple of the rupture disk are protrusions into the internal diameter of the tubing string. These protrusions may hang debris circulated up the tubing and plug it off causing the operator to pull the work string. Many times surface intervention may be required to pierce the rupture disk to facilitate it to rupture. Experience has shown that the use of a rupture disk is fraught with potential problems and unnecessary economic expense. 
     An eight problem occurs when lowering tubing into a well containing drilling mud with lost circulation material (cotton seed hulls, walnut chunks, cellophane particles, and others) in it. Experience has shown that the lost circulation material, when entering the bit, may plug it off, or the tubing above the bit. This situation reminds us that in this situation it is generally a good idea to run some type of tubing plugging apparatus. 
     Therefore, the primary object of this invention is to prevent well fluids from entering the tubing as it is lowered into a well full of fluid. 
     A second object of this invention is to remove the plugging apparatus with well fluids leaving no debris in the tubing. 
     A third object of this invention is to remove the plugging apparatus without surface intervention. 
     A fourth object of this invention is to be able to establish circulation at any time allowing the operator full control of the well. 
     A fifth object of this invention is to allow the well operator, when pumping out the plugging apparatus, to monitor the tubing pressure at the surface, to identify when the internal bidirectional tubing plug has released, by observing a pressure build up and fall off, and then establish that the well is circulating. 
     A sixth object of this invention is to leave the internal diameter of the tubing constant when the plugging apparatus is removed. 
     A seventh object of this invention is to blank off the tubing with very small parts that may be circulated through a workover bit, up the tubing/casing annulus, or through the workover bit up the tubing to the surface. 
     An eight object of this invention is to manufacture the small parts of this plugging apparatus of a material recognized as biodegradable. 
     A ninth object of this invention is to manufacture the internal parts of this plugging apparatus of a material that is sufficient for the pressures and temperatures encountered in most well conditions. 
     A tenth object of this invention is to manufacture the parts of this plugging apparatus from a material that is easily drillable. 
     2. Description of the Related Art 
     U.S. Pat. No. 2,153,812, Newton, 1939, teaches us that wireline plugs run in casing or tubing require surface intervention to run or retrieve a check valve or blanking plug, and most generally a prong or rod to equalize and release the in place device then pull it to the surface. 
     U.S. Pat. No. 2,856,003, J. V. Fredd, 1958, teaches us that wireline plugs run in casing or tubing require surface intervention to run or retrieve a check valve or blanking plug, and most generally a prong or rod to equalize and release the in place device then pull it to the surface a different way. 
     U.S. Pat. No. 6,427,773 B1, Albers, 2002, and the U.S. Documents Cited dated through September 1998, refer to wireline retrievable devices require surface intervention. 
     Any discussion of the prior art throughout the specification should in no way be considered as a discussion that such prior art is known or forms part of common general knowledge in the field. 
     SUMMARY OF THE INVENTION 
     The present invention provides a method and apparatus for establishing a temporary internal bidirectional tubing plug within well conduits that can be removed upon demand to permit fluid flow past the plugged point within a short period of time. It is anticipated that the plugging apparatus and methods disclosed herein will be applicable in any size conduit. The dimensions of the plug will be dependent upon the area to be plugged and the service conditions into which it will be placed. Removal of the plug is accomplished without mechanical intervention from the well&#39;s surface. Furthermore, the resulting debris or “fall out” from the bidirectional internal plug comprises sufficiently small members that are easily transported by the fluids of the well without blocking or fouling other aspects and equipment of the well. These benefits, as well as others that will become apparent, to someone versed in the art, from the disclosure made herein, provide time, and cost savings to a well operator. 
     In one or more embodiments described herein, the internal bidirectional tubing plug consists of a number of small petals and a cork or balls that transfer the forces applied to them by the differential pressure across the plug into the body of the plug that is screwed into the tubing string. 
     During the initial completion of a well, the tubing, generally with a drill bit on the bottom of the tubing, is lowered into a fluid filled casing string. As the tubing is lowered the tubing displaces its volume out of the well. The displaced fluid may be water, drilling mud; oil based drilling mud, drilling mud with lost circulation material in it, drilling mud with harmful chemicals in it, or a combination of the above described fluids. As the tubing is lowered into the well the well fluid is displaced both out of the annulus of the tubing/casing and up the inside of the tubing string. The fluid from the tubing/casing annulus may be directed to a pit or tank by the use of a stripping rubber. When using a stripping rubber some of the displaced casing fluid is displaced up the tubing string into the atmosphere spraying fluid on the rig, rig crew, stripping rubber, rig blow-out-preventers, and well head filling the well head cellar with casing fluid. It is desirable to temporarily plug off the tubing string above the bit, and to displace all of the displaced well fluid to a pit or tank using a stripping rubber. When displacing fluids from a well casing containing drilling mud with lost circulation material in it many times this type of fluid will bridge off and plug the interior of the tubing string causing lost time and either significant expense and rig downtime. 
     Regarding oil and gas wells, there are many types of temporary plugs that are used for different applications. Temporary plugs that may be removed from a well intact are referred to as “retrievable” plugs. Removal, however, requires mechanical intervention from the surface of the well. Common intervention techniques include re-entry into the well with wireline, coiled tubing, or a smaller tubing string. 
     After a wire line retrievable blanking plug has been set in a tubing sub at the surface, screwed into the tubing, and run in the well and it subsequently becomes necessary to remove the blanking plug to establish well circulation, any retrievable tools that have been designed to remove the blanking plug must be run into the tubing to latch onto the blanking plug prior to removing it from the tubing. The installation and effort of installing the wire line and the pulling of tools and removal of the plug to reestablish flow within a downhole conduit often entails significant cost and rig downtime. It is, therefore, desirable to develop an internal bidirectional tubing plug which may be readily removed or destroyed without either significant expense or rig downtime. 
     Some temporary non-retrievable tubing plugs are in the form of frangible rupture disks or sand plugs that leave debris on the inside diameter of the tubing leaving a restriction to the inside diameter of the tubing that may potentially causing operational problems in the future. 
     The present invention is a internal bidirectional tubing plug that is run in place at any position in the tubing string, generally above a bit, or above the drill collars above the bit, preventing fluid entry into the tubing being run into the well. When using this invention in conjunction with a stripping rubber all of the displaced fluid in the well bore is displaced to a pit or tank, through a casing valve, eliminating fluid from being sprayed on the rig, and rig crew, or contamination the environment which allows more control of the well and allows the tubing to be run into the well at a faster rate. After the tubing string reaches its desired depth the tubing is filled with well fluid to equalize the hydrostatic pressure differential across the internal bidirectional tubing plug. Applying hydraulic pressure on top of the equalized internal bidirectional tubing plug acts on the cork of the internal bidirectional tubing plug releasing it which is displaced by tubing fluid, that then allows the tubing fluid to displace the small petals of the present invention out the end of the tubing or bit establishing communication between the tubing and tubing/casing annulus. The small petals and cork fall to the bottom of the well or are circulated to the surface. 
    
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
         FIG. 1  is a front view with hidden lines shown of the internal bidirectional tubing plug. 
         FIG. 2  is a front cross section view of  FIG. 1  except the cork of the internal bidirectional tubing plug. 
         FIG. 3  is a front cross section view of  FIG. 1 , except the nut, cork, and O-ring of the internal bidirectional tubing plug. 
         FIG. 4  is a front cross section view of the body, nut, keystone petal, and upper and lower piston of the internal bidirectional tubing plug. 
         FIG. 4  Detail A is close up of the nut, cork, keystone petal and upper piston of the internal bidirectional tubing plug of  FIG. 4 . 
         FIG. 5  is a front cross section view of the body, upper piston, keystone petal, and displaced lower piston showing a displaced cork with o-ring, and stationary nut of the internal bidirectional tubing plug. 
         FIG. 6  is a front cross section view of the body, all petals, upper piston, and partially displaced keystone petal, showing a displaced cork and o-ring not in cross section of the internal bidirectional tubing plug. 
         FIG. 7  is a front cross section view of the body, of the internal bidirectional tubing plug. 
         FIG. 8  is an isometric view, of the petal assembly of the internal bidirectional tubing plug. 
         FIG. 9  is an isometric view of the petals of the internal bidirectional tubing plug. 
         FIG. 9  Detail A is a rotated view of the petals of the internal bidirectional tubing plug. 
         FIG. 10  is an isometric view of the top petal of the internal bidirectional tubing plug. 
         FIG. 10  Detail A is a rotated view of the top petal of the internal bidirectional tubing plug. 
         FIG. 11  is an isometric view of the bottom petal of the internal bidirectional tubing plug. 
         FIG. 11  Detail A is a rotated view of the bottom petal of the internal bidirectional tubing plug. 
         FIG. 12  is an isometric view of the keystone petal of the internal bidirectional tubing plug. 
         FIG. 12  Detail A is a rotated view of the keystone petal of the internal bidirectional tubing plug. 
         FIG. 13  is an isometric view of the cork, o-ring and nut assembly of the internal bidirectional tubing plug. 
         FIG. 13  Detail A is a front cross sectional view of the cork, o-ring and nut of the internal bidirectional tubing plug. 
         FIG. 14  is a front view of the cork, hidden lines shown, of the internal bidirectional tubing plug. 
         FIG. 15  is an isometric view of the o-ring of the internal bidirectional tubing plug. 
         FIG. 15  Detail A is an isometric view of the upper piston of the internal bidirectional tubing plug. 
         FIG. 15  Detail B is an isometric view of the lower piston of the internal bidirectional tubing plug. 
         FIG. 16  is an isometric view, of the nut of the internal bidirectional tubing plug. 
         FIG. 16  Detail A is a rotated view of the nut of the internal bidirectional tubing plug. 
         FIG. 17  is an isometric view of the assembly device of the internal bidirectional tubing plug. 
         FIG. 18  is an isometric view of the assembly device, shown with a nut in place, of the internal bidirectional tubing plug. 
         FIG. 19  is a front view of the assembly device, with a nut in place, and a body positioned over the assembly device of the internal bidirectional tubing plug. 
         FIG. 20  is a top view of the assembly device, shown with a nut in place, a body positioned over the assembly device, and all petals in place, less the keystone petal of the internal bidirectional tubing plug. 
         FIG. 20  Detail A is a front cross sectional view of the assembly device, shown with a nut in place, a body positioned over the assembly device, and all petals in place, less the keystone petal of the internal bidirectional tubing plug. 
         FIG. 21  is a top view of the assembly device, shown with a nut in place, a body positioned over the assembly device, all petals in place, and the keystone petal pre positioned in place of the internal bidirectional tubing plug. 
         FIG. 21  Detail A is a front cross section view of the assembly device, shown with a nut in place, a body positioned over the assembly device, petals in place, and the keystone petal pre positioned in place of the internal bidirectional tubing plug. 
         FIG. 22  is a front cross section view of the assembly device, shown with a nut in place, a body positioned over the assembly device, petals in place, and the keystone petal positioned in place in the body, and the cork partially screwed into the nut of the internal bidirectional tubing plug. 
         FIG. 23  is a front cross section view of the tubing cork assembled shown with a lower piston of the internal bidirectional tubing plug. 
         FIG. 24  is a front cross section view of an embodiment of the invention using one row of balls, an assembly of pistons, and a lower piston, of the internal bidirectional tubing plug. 
         FIG. 24  Detail A is an isometric view of the one-half piston of the internal bidirectional tubing plug. 
         FIG. 24  Detail B is a rotated view of the one-quarter piston of the internal bidirectional tubing plug. 
         FIG. 24  Detail C is an isometric view of the lower piston of the internal bidirectional tubing plug. 
         FIG. 25  is an isometric view of an assembly device for the embodiment shown in  FIG. 24  of the internal bidirectional tubing plug. 
         FIG. 25  Detail A is a front cross sectional view of  FIG. 24  of the internal bidirectional tubing plug. 
         FIG. 26  is a front cross sectional view of the embodiment, shown in  FIG. 24 , as it is assembled, of the internal bidirectional tubing plug. 
         FIG. 27  is an embodiment of the internal bidirectional tubing plug using three rows of balls and a four quarter pistons of the internal bidirectional tubing plug 
         FIG. 27  Detail A is an isometric view of a one-quarter piston of an embodiment of the internal bidirectional tubing plug that uses three rows of balls. 
         FIG. 27  Detail B is an isometric view of a lower piston of an embodiment of the internal Bidirectional Tubing as shown in  FIG. 25 . 
     
    
    
     DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENT 
     Referring now to  FIG. 1 , this is a front view with hidden lines shown of the internal bidirectional tubing plug  1 . The purpose and function of the internal bidirectional tubing plug is to prevent well fluids from passing this plug in a well conduit, in either direction, in a well until it is activated and pumped apart and the pieces are pumped down or up a tubing string (not shown), or down or up a casing/tubing annulus (not shown). 
     Referring now to  FIG. 2 ,  FIG. 2  is a front cross sectional view of the body  10  (see  FIG. 7 ), cork assembly  60  (see  FIG. 11 ), petal assembly  30  (see  FIG. 8 ), upper piston  112  (see  FIG. 13A ), and lower piston  113  (see  FIG. 13B ). The pin Connection  22  of the body  10  (see  FIG. 7 ), screws into a tubing string (not shown) which generally is above the bit (not shown) and drill collars (not shown), and a pin connection (not shown) of the tubing string (not shown) screws into the box connection  12  of the internal bidirectional tubing plug  1  (see  FIG. 1 ). The internal bidirectional tubing plug  1  (see  FIG. 1 ) is now lowered into the fluid filled well (not shown), and the internal bidirectional tubing plug  1  (see  FIG. 1 ) prevents well fluid (not shown) from entering the tubing. The tubing&#39;s outside volume is displaced up the tubing/casing annulus (not shown) against a stripping rubber (not shown) and well fluids (not shown) are forced out of the well (not shown) through a casing valve (not shown) to a pit (not shown). 
     Referring now to  FIG. 3 ,  FIG. 3  shows that as the internal bidirectional tubing plug  1  (see  FIG. 1 ) is lowered into the fluid filled well (not shown), a hydrostatic pressure (not shown), is developed in area  111 , generating a force (not shown) which acts against the lower piston  113  (see  FIG. 13  Detail B), which acts against the bottom  47 , of the petals  40  (see  FIG. 9 ), the bottom  57  of the keystone petal  59  (see  FIG. 12 ), the bottom  127  of the top petal  120  (see  FIG. 10 ), the bottom  137  of the bottom petal  137  (see  FIG. 11 ), and the bottom  77  of the cork  70  (see  FIG. 14 ) which transfers this force into the upper lip  15  of the body  10  (see  FIG. 7 ). Additionally the force generated (not shown) on the bottom  77  of the cork  70  (see  FIG. 14 ), due to the tapered side  75  of the cork  70  (see  FIG. 14 ), directs the vertical and horizontal component of the generated force (not shown) through the petals  40  (see  FIG. 9 ), top petal  120  (see  FIG. 10 ), bottom petal  130  (see  FIG. 11 ), keystone petal  50  (see  FIG. 12 ), outward and upward respectively (not shown), into the recess  17  of the body  10 , and the upper lip  15  of the body  10  (see  FIG. 7 ). 
     Referring now to  FIG. 4 ,  FIG. 4  is step one of the release method. Once the internal bidirectional tubing plug  1  (see  FIG. 1 ) reaches its working depth (not shown), well fluids (not shown) are pumped into the tubing string (not shown) to fill it, which equalized the hydrostatic pressure (not shown) across the internal bidirectional tubing plug  1  (see  FIG. 1 ). To release the internal bidirectional tubing plug  1  (see  FIG. 1 ) hydraulic pressure is applied in area  110  of internal bidirectional tubing plug  1  (see  FIG. 1 ). As seen in Detail A of  FIG. 4 , applied hydraulic pressure (not shown) acts through fluid path  114 , that exerts hydraulic pressure on an area (not shown) as defined by outside diameter of the O-ring  80  (see  FIG. 15 ), that exerts a downward force (not shown), opposing an upward force defined by the area of the recess  73  of the cork  70  (see  FIG. 14 ) outside diameter, and the mechanical properties (not shown) of the material of the cork  70 , held by the nut  90 . When the downward forces (not shown) exceed the upward forces (not shown) the cork fails in tension (not shown) at the recess  73  allowing the cork  70  to move downward (not shown) after it fails. 
     Referring now to  FIG. 5 .  FIG. 5  is step two of the release method. Once the cork  70  has parted, well fluids (not shown) from above the internal bidirectional tubing plug  1  (see  FIG. 1 ) displace the cork  70  and lower piston  113  downward and away from the internal bidirectional tubing plug  1  (see  FIG. 1 ). 
     Referring now to  FIG. 6 ,  FIG. 6  is step three of the release method. After the cork  70  has been displaced from the petal assembly  30  (see  FIG. 8 ) fluid flow through the hole  31  in the petal assembly  30  (see  FIG. 8 ) generates a differential pressure (not shown) across the petal assembly  30  (see  FIG. 8 ), this differential pressure (not shown) acts on the upper surface  51  of the keystone  50  generating a downward force (not shown) that forces the keystone  50  outward, out of the body  10  recess  17  (see  FIG. 7 ), due to its bevel  56  and out of the petal assembly  30  (see  FIG. 8 ). Note that the inner lip  58  of the keystone petal  50  has an inside diameter (not shown) that is less that the inside diameter  14  of the body  10  which allows the bevel  56  of the keystone petal to ride against the inside diameter  14  of the body  10  forcing the keystone petal  50  downward and inward out of the petal assembly  30  (see  FIG. 8 ) leaving a space (not shown). The resulting space (not shown) and fluid flow (not shown) through remainder of the petal assembly  30  (see  FIG. 8 ) allows the remaining components of the petal assembly  30  (see  FIG. 8 ) swept from the recess  17  of the body  10 . 
     Referring now to  FIG. 7 ,  FIG. 7  is a front cross section of the body  10 , consisting of a top  11 , a box connection  12 , inside diameter  14 , upper lip  15 , petal recess  17 , lower lip  18 , pin connection  19  and, bottom  20 . 
     Referring now to  FIG. 8 ,  FIG. 8 , is an isometric view of the petal assembly  30 , consisting of petals  40  (see  FIG. 9 ), top petal  120  (see  FIG. 10 ), bottom petal  130  (see  FIG. 11 ), and keystone petal  50  (see  FIG. 12 ), and hole in the petal assembly  31 . 
     Referring now to  FIG. 9 ,  FIG. 9  is an isometric view of the petals  40 . The petals are assembled into the internal bidirectional tubing plug  1  (see  FIG. 1 ). The petals  40  are composed of a top  41 , side  42 , tapered conical surface  43 , an upper edge  44  and in Detail A, a back  45 , lower edge  46  and bottom  47 . 
     Referring now to  FIG. 10 ,  FIG. 10  is an isometric view of the top petals  120 . The top petal is assembled into the internal bidirectional tubing plug  1  (see  FIG. 1 ). The top petal  120  is composed of a top  121 , side  122 , tapered conical surface  123 , upper edge  124  and in Detail A, a back  125 , lower edge  126  and bottom  127 . 
     Referring now to  FIG. 11 ,  FIG. 11  is an isometric view of the bottom petals  130 . The bottom petal is assembled into the internal bidirectional tubing plug  1  (see  FIG. 1 ). The bottom petal  130  is composed of a top  131 , side  132 , tapered conical surface  133 , upper edge  134  and in Detail A, a back  135 , lower edge  136  and bottom  137 . 
     Referring now to  FIG. 12 ,  FIG. 12  is an isometric view of the keystone petal  50 . The keystone petal  50  is assembled into the internal bidirectional tubing plug  1  (see  FIG. 1 ). The keystone petal  50  is composed of a top  51 , tapered conical surface  53 , an upper edge  52 , and in Detail A, a back  54 , a bevel  56 , an inner lip  58 , bottom  57 , and sides  55 . 
     Referring now to  FIG. 13 ,  FIG. 13  is an isometric view of the cork assembly  60 . In Detail A consists of a nut  90  (see  FIG. 16 ), a cork  70  (see  FIG. 14 ), and an O-ring  80  (see  FIG. 15 ). 
     Referring now to  FIG. 14 ,  FIG. 14  is a front view of the cork  70 . The cork  70  has a top  71 , threads  72 , a recess  73 , a fluid groove  74 , a tapered conical surface  75 , an O-ring groove  76 , a bottom  77 , and a slot  78  used to screw the cork  70  into the nut  90  as described in  FIG. 22  below. 
     Referring now to  FIG. 15 ,  FIG. 15  is an isometric view of the O-ring  80 .  FIG. 15  Detail A is an isometric view of the upper piston  112 .  FIG. 15  Detail B is an isometric view of the lower piston  113 . 
     Referring now to  FIG. 16 ,  FIG. 16  is an isometric view of the nut  90 . The threads  92  match the threads  72  of the cork  70  (see  FIG. 14 ). The slots  94  (see Detail A) direct hydraulic pressure (not shown) to the fluid groove  74  of the cork  70  (see  FIG. 14 ). The bottom  95  of the nut  90  (see Detail A) rests against the petal assembly  30  (see  FIG. 8 ) as shown in  FIG. 2  of the internal bidirectional tubing plug  1  (see  FIG. 1 ). 
     Referring now to  FIG. 17 ,  FIG. 17  is an isometric view of the assembly device  100  that consists of a base plate  105 , top of base  107 , with sides  106 , a post  103 , top of post  101 , that has a nut socket  102  in it that fits the nut  90  (see  FIG. 16 ). 
     Referring now to  FIG. 18 ,  FIG. 18  is an isometric view of the first step of the assembly method of the internal bidirectional tubing plug  1  (see  FIG. 1 ). The first assembly step is to insert a nut  90 , slots  94  up (see  FIG. 16 ) into the nut socket  102  of the post  103  of the assembly device  100  (see  FIG. 15 ). 
     Referring now to  FIG. 1 ,  FIG. 19  is the second step of the assembly method of the internal bidirectional tubing plug  1  (see  FIG. 1 ). This front sectional view shows the top  11  of the body  10  (see  FIG. 7 ) placed over the post  103  and down against the top  107  of the assembly device  100  (see  FIG. 17 ). 
     Referring now to  FIG. 20 ,  FIG. 20  is a top view of the third step of the assembly of the internal bidirectional tubing plug  1  (see  FIG. 1 ). Detail A, is a front section view of  FIG. 20 . The top  41  of a petal  40  (see  FIG. 9 ) is inserted, through the bottom  20 , inside diameter  14 , of the body  10  (see  FIG. 7 ), until the top  41 , of the petal  40  (see  FIG. 9 ) is in contact with the top  101 , of the post  103 , of the assembly device  100  (see  FIG. 17 ), then the petal  40  is pushed outward until its back  45  (see  FIG. 9  Detail A) is in contact with the recess  17 , of the body  10  (see  FIG. 7 ), and the upper edge  44  and the lower edge  46  of the petal  40  (see  FIG. 9  and Detail A), is in contact with the upper lip  15  and lower lip  18  of the Body  10  (see  FIG. 7 ) respectively. Each petal  40  (see  FIG. 9 ), four shown, is inserted sequentially, one after the other, and each side  42  of a petal  40  is placed in contact with the previously inserted side  42  of the prior petal  40  (see  FIG. 9 ). After the four, as shown, petals  40  (see  FIG. 9 ) are inserted into the body  10  (see  FIG. 7 ), the top  121  of the top petal of the top petal (see  FIG. 10 ), and the top of the bottom petal  130  (see  FIG. 11 ) are inserted and adjusted as described above leaving room for the keystone petal  50  (see  FIG. 10 ) to be inserted as described in  FIG. 21  below. This third assembly step, when finished, generates a hole  31  in the petal assembly  30  (see  FIG. 8 ). 
     Referring now to  FIG. 21 ,  FIG. 21  is a top view of the fourth step of the assembly of the internal bidirectional tubing plug  1  (see  FIG. 1 ). See  FIG. 21 , Detail A. The top  51  of a keystone petal  50  (see  FIG. 12 ) is inserted, through the bottom  20 , inside diameter  14 , of the body  10  (see  FIG. 7 ), until the top  51 , of the keystone petal  50  (see  FIG. 12 ) is in contact with the top  101  of the post  103  of the assembly device  100  (see  FIG. 17 ) which places the sides  55  of the keystone petal  50  (see  FIG. 10  Detail A) in sliding contact with the side  122  of the top petal  120  (see  FIG. 10 ), and the side  132  of the bottom petal  130  (see  FIG. 11 ). The back  54  of the keystone petal  50  slides down the inside diameter  14  of the body  10  until the bottom  57  of the keystone petal  50  is in contact with the top  101  of the post  103  of the assembly device  100  (see  FIG. 17 ), through the hole  31  in the petal assembly  30  (see  FIG. 8 ). Next, and not shown in this figure, back  54  keystone petal  50  is pushed outward until the back  54  is contact with the recess  17  of the body  10  (see  FIG. 7 ). 
     Referring now to  FIG. 22 ,  FIG. 22  is a front sectional view of the fifth step of the assembly of the internal bidirectional tubing plug  1  (see  FIG. 1 ). The top  71  of a cork  70  (see  FIG. 14 ) is inserted, through the bottom  20 , inside diameter  14 , of the body  10  (see  FIG. 7 ), until the threads  72  of the cork  70  (see  FIG. 14 ) engage the threads  92  of the nut  90  (see  FIG. 16 ), the cork  70  is rotated by a screw driver device (not shown) inserted into slot  78  of the cork  70  until the bottom  77  of the cork  70  (see  FIG. 12 ) is even (not shown) with the bottom  47  of one or more of the petals  40  (see  FIG. 9 ). 
     Referring now to  FIG. 23 ,  FIG. 23 , a front sectional view, of the sixth step of the assembly of the internal bidirectional tubing plug  1  (see  FIG. 1 ). The top  11  of the body  10  (see  FIG. 7 ) is placed on a flat surface (not shown) and a lower piston  113  (see  FIG. 15  Detail B), (composed of a poured RTV material or a flexible rubber like material) is attached to the bottom  47  of the petals  40  (see  FIG. 9 ), the bottom  127  of the top petal (see  FIG. 10  Detail A), the bottom  137  of the bottom petal (see  FIG. 11  Detail A), the bottom  57  of the keystone petal  50  (see  FIG. 12 ), and the bottom  77  of the cork  70  (see  FIG. 14 ) at which time the internal bidirectional tubing plug  1  (see  FIG. 1 ) is rotated (not shown) until the bottom  20 , of the body  10 , (see  FIG. 10 ) is on a flat surface (not shown) and the upper piston  112  (not shown) (see  FIG. 15  Detail A) is attached in a like manner. 
     Referring now to  FIG. 24 ,  FIG. 24 , a front sectional view, of an embodiment of the internal bidirectional tubing plug (see  FIG. 1 ). This embodiment is for use in wells; that have a slight flowing gas condition, which is unsafe to run open ended tubing in, wells that when shut in do not build up enough pressure to require a snubbing unit to run the tubing with a blanking plug in the snubbed tubing, wells that operators do not want to kill with a well fluid to run the tubing, as known in the art. Gas pressure (not shown) acting below the piston  514  (see  FIG. 24 ) pushes upward on the cross sectional area (not shown) of the half-pistons  508  (see Detail A) or the cross sectional area (not shown) of the quarter pistons  510  (see Detail B) when used, transferring the generated force of the gas (not shown) to a plurality of balls  504 , which transfer the force (not shown) in the balls to the groove  506  of the body  500 , preventing any upward flow of liquids of gases through this embodiment. When the well is nippled up (not shown and as known in the art) fluids or gages (not shown) may be directed down the tubing (not shown) to sent the parts of this embodiment out the end of the tubing string (not shown) opening the well to production (not shown). 
     Referring now to  FIG. 25 ,  FIG. 25  is an isometric view of assembly device  600 .  FIG. 25 , Detail A, is a front sectional view of the assembly device  600  used to assemble an embodiment as described in  FIG. 24 . 
     Referring now to  FIG. 26 ,  FIG. 26  is a front cross sectional view of an assembly device  600  (see  FIG. 22 ) and the embodiment as shown in  FIG. 24 . The method of assembly is to place the assembly device  600  on a flat surface (not shown) and place the top  501  of body  500  (see  FIG. 24 ) over the center (not shown) of the post  606  until the top  501  of body  500  (see  FIG. 24 ) is in contact with the top  604  of the assembly device (see  FIG. 23 ). Next, a pre determined number and size of balls  504  are placed on top  602  of the post  606  of the assembly device  600  (see  FIG. 25 ). Next, two half-pistons  508 , or four quarter-pistons  510  (see  FIG. 24  Detail A and B) are placed nose  513  or  510  (See  FIG. 24  Detail A or B) down in the pin  503  of the body  500  and rotated (not shown) until all of the balls  504  are equally distributed in the groove  506  of the body  500 . A piston  514  (a rubber like material) is affixed to the bottom  509  of the half-piston or bottom  511  of the quarter-piston (see  FIG. 24  details A and B respectively). 
     Referring now to  FIG. 27 ,  FIG. 27  is a front cross sectional view of a second embodiment of an internal bidirectional tubing plug (see  FIG. 1 ). Referring now  FIG. 24 ,  FIG. 27  is unlike in its construction and use, only in that it has a center ball  706  and a second row of balls  708  and quarter pistons  710  (Detail A). A piston detail B is placed below the quarter pistons  710  on their bottom  709  (Detail B). 
     It is apparent to those skilled in the art that the size and shape of the body and components of the internal bidirectional tubing plug are variable and only need to be sized and shaped to allow the invention to perform as described in well conduits, in any direction, in any cross sectional area, with any fluid of gas at any temperature. 
     While the invention has been described with a certain degree of particularity, it is manifest that many changes may be made in the details of construction and the arrangement of components without departing from the spirit and scope of this disclosure. It is understood that the invention is not limited to the embodiments set forth herein for the purposes of exemplification, but is to be limited only by the scope of the attached claim or claims, including the full range of equivalency to which each element thereof is entitled.