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CROSS-REFERENCE TO RELATED APPLICATIONS 
     This application is a Continuation in Part, and claims priority to U.S. patent application Ser. No. 14/205,057 filed Mar. 11, 2014, and all related priority filings, which are incorporated by reference herein in their entirety. Application Ser. No. 14/205,057 claims priority to provisional application 61/787,184 filed on Mar. 15, 2013 which is incorporated by reference herein in its entirety. 
    
    
     STATEMENT REGARDING FEDERALLY SPONSORED RESEARCH 
     Not applicable. 
     BACKGROUND 
     The present invention applies to flowing fluid wells. Within a flowing well, production tubing moves fluid upward under immense pressures and is potentially exposed to great damage, either accidental, or intentional. Recently, there is increased concern in protecting our production wells from damage, either natural or man-made. The present invention is designed to address the problems of controlling hydrocarbon, and fluid flow, through production tubing after the production tubing is compromised by penetration or severance. 
     SUMMARY 
     In many embodiments of the valve design for the present invention, the present invention is placed, and/or utilized between vertical lengths of production tubing located below the water body, or between vertical lengths of production tubing in a ground based well below the Christmas Tree (i.e. within the borehole.) 
     In several embodiments, the present invention includes the use of an internal control valve located between vertical lengths of production tubing below the water body, or ground well. In one embodiment, the present invention includes the use of an internal control valve positioned between segments of production tubing located below the water body (the borehole), or ground well, and activated by exposure of a valve&#39;s control parts to the surrounding hydrostatic pressure above the water body, or ground well. 
     In one embodiment of the present invention the present invention utilizes the weight of the production tubing between the valve and the point of severance to force the valve closed. In one embodiment, the present invention uses an external control valve. In one embodiment, the present invention utilizes a valve system which combines the internal and external method of control of fluid flow. 
     In one embodiment, the present invention utilizes an internal control valve activated by a change in the rate and/or pressure of upward flow of the hydrocarbon. In one embodiment, the present invention envisions the use of an external control valve activated by exposure of the valve&#39;s control parts to the surrounding hydrostatic pressure above the water body. In several embodiments of the present invention it is envisioned to use the weight of the production tubing between the valve and the point of severance to force the valve closed. 
     In one embodiment, the present invention envisions the use of an external control valve activated by the severance of a supporting medium for an activating weight. In one embodiment, the present invention utilizes a valve system which combines any two or more of the above methods of external and/or internal control of fluid flow. 
     Generally, the present inventive device functions to allow for the stoppage of fluid flow through a pipe or tubing. In several embodiments, one of the novel aspects of the present invention is that it utilizes manual and hydrostatic pressures to regulate the flow of a fluid and can be re-operated through a decrease, or change, in these pressures and/or flow rates. The advantage that the invention provides is that it is a reusable valve that can be reactivated with minimal expenditure of time or resources. 
     In several other embodiments, another novel aspect of the present invention is that it is located subsea floor, or water body bed, and or ground well surface, and therefore is less susceptible to attack or compromise. It is envisioned that there may be multiple valves utilized in the present inventive system. It is also envisioned that the present invention can be utilized in multiple fluid flow applications outside of hydrocarbons. Many other novel advantages will be further disclosed in the detailed description of the invention. 
     In some embodiments, the valve is open when supported by the overlying production tubing and is closed and sealed when supported, at least, by the underlying production tubing. In some embodiments, the valve can be activated by a piston or a probe. In several embodiments, the present invention is a safe and quick shut in mechanism. 
     In some aspects of the present invention, the present invention is located some distance (possibly 200 or 300 feet) below the sea floor, and within the borehole (i.e. bore hole), and therefore is less susceptible to attack or compromise than valves located above the sea floor. It is envisioned that there may be multiple valves utilized in the present inventive system. It is also envisioned that the present invention can be utilized in multiple fluid flow applications outside of hydrocarbons. It is also envisioned that the present inventive device can be made with multiple individual parts, some preassembled parts, and/or some parts welded or joined together. 
     Some of the general principles behind the operation of the present invention may include, without limitation, the following: the rate of flow of fluids and/or hydrocarbons through the valve, the exposure of some of the valve parts to the hydrostatic pressure that exists where an embodiment of the present invention is located, which could be: a) near or around production tubing at or below the sea floor or b) near and/or surrounding all tubulars below any penetration or severance point of the production tubing below which an embodiment of the present invention is located, or c) between segments of production tubing below the sea floor. The weight of the remaining production tubing above the valve, which will cause activation of the valve when the supporting production tubing overlying the valve is severed. Severance of the mechanism of support for an external part of the valve control system, and whereby said valve is closed. A system wherein more than one valve, each activated by different functionalities that, are located within the borehole: thereby creating a backup. 
     In several embodiments of the present invention, the present invention comprises a flow control valve located between segments of production tubing within the borehole (i.e. bore hole) and below the sea floor, of a flowing oil and/or gas well, and wherein said location said valve is relatively secure from wanton or accidental destruction and the resulting uncontrolled and disastrous upward flow of hydrocarbon resulting from such destruction, and wherein said borehole, said valve can be closed automatically by some functionality not requiring surface control. In several embodiments of the present invention, the present invention, comprises a valve body, wherein said valve further comprising an internal sliding piston, said sliding piston having at least one perforation in its side, and further comprising a first and lower sealing surface, and said valve body containing a second and upper sealing element, whereby sufficiently increased upward flowing pressure within the production tubing below said valve makes the piston slide upward so the first sealing element engages the second sealing element, thereby closing the valve. 
     In several embodiments of the present invention, in said borehole said valve is activated to close by the severance of the overlying production tubing attached to, and supporting, said valve. Several embodiments of the present invention, comprise a control valve in which the severance will transfer the weight of any remaining overlying production tubing attached to the upper sliding unit of the upper valve which has a lower sealing surface, and whereby said lower sealing surface will descend to engage the upper sealing surface of the lower valve unit, and whereby said valve is closed, and the upward flow of hydrocarbon is stopped. In several embodiments of the present invention, the opening and closing of said valve can be checked without raising the valve to the surface. 
     In several embodiments of the present invention the borehole of said valve is activated to close by some mechanism including the severance of the mechanism of support for a moving part of a valve assembly. In several embodiments of the present invention, the present invention further comprises an upper sliding piston in mechanical communication with the overlying and attached production tubing, said upper sliding piston having a base probe projecting downward, said valve further comprising a lower sealing unit with an exposed upper trigger unit, whereby severance of the production tubing above or below the sea floor will result in the removal of support for the production tubing overlying the upper sliding piston and thereby force the sliding piston downward, whereby said probe on the base of the upper sliding piston will contact and depress the underlying trigger on the lower sealing unit, and thereby will activate the valve to close. In several embodiments of the present invention, in the control valve of many of the embodiments, when the valve is closed, restoration or replacement of the support of the severed production tubing accompanied by sufficiently increased fluid pressure above the valve, will make the piston slide downward so that the lower sealing element disengages from the uppermost sealing element, therein reopening the valve. 
     In several embodiments of the present invention, the valve is modified so as when the flowing well is drilled on land and the valve is activated to close by the severance of the production tubing above or below ground level. In several embodiments of the present invention, the valve can be reopened by some mechanism including temporarily reversing the flow of hydrocarbon above said valve to downward after the severed tubing is replaced. In several embodiments of the present invention, the present invention comprises a control valve located between segments of production tubing within the borehole (i.e. bore hole) of a flowing oil and or gas well, and whereby severance of said surrounding production tubing and/or a pressure chamber or pressure tube attached to said pressure chamber or valve assembly, will expose the control mechanism of said valve to that high hydrostatic pressure existing, around the riser of said well between sea level and the sea floor, and thereby close said valve. In several embodiments of the present invention, the control valve further comprises a pressure chamber in fluid communication with the control valve, a fluid line attached to said pressure chamber wherein; fluid pumped into the pressure chamber through the fluid line causes the piston to slide so the first sealing element engages the second sealing element. 
     In several embodiments of the present invention, a valve is located within the borehole of a flowing oil and/or gas well between segments of production tubing, and wherein said borehole said valve is activated to close by the severance of a supporting mechanism for a moveable part of said valve assembly. In several embodiments of the present invention, is a control system comprising; multiple valves which can be attached and located between units of the production tubing within the borehole. In several embodiments of the present invention, the present invention contains a control system comprising two or more of the valves. In several embodiments of the present invention, the flow control valves further contain no springs. In some wells flow sulfurous (sour) gas exists which can crystallize springs, and thereby subject them to breakage. If the springs could be eliminated, then the valve could be designed so that the flowing pressure alone would be sufficient to close it. This would be most appropriate for wells containing “sour” (sulfurous) gas which tends to crystallize springs, and whereby they break. 
     In several embodiments of the present invention, there is a flow control valve located between segments of production tubing within a borehole below a solid surface of a flowing oil and/or gas well, and wherein said flow control valve can be closed automatically through hydrostatic pressure change, or flow rate and not requiring surface control. In several embodiments of the present invention, the flow control valve further comprises; a valve body; said valve body further comprising an upper and lower portion said valve body further comprising an internal sliding piston, said sliding piston having at least one perforation in its side; said sliding piston further comprising a first and lower sealing surface; said valve body containing a second and upper sealing element; whereby sufficiently increased upward flowing pressure of a fluid within a production tubing below said valve makes said piston slide upward so the first sealing element engages the second sealing element, thereby closing said valve body. In several embodiments of the present invention, the flow control valve further comprises; said borehole of said flow control valve is activated to close by the severance of a production tubing attached to and supporting said flow control valve. In several embodiments of the present invention, the flow control valve further comprises; overlying production tubing; said severance will transfer the weight of any remaining overlying production tubing of said production tube attached to the upper portion of said valve body which has a lower sealing surface, and whereby said lower sealing surface will descend to engage said upper sealing surface of said flow control valve body, and whereby said flow control valve is closed, and the upward flow of hydrocarbon is stopped. In several embodiments of the present invention, the flow control valve further comprises; within said borehole the opening and closing of said flow control valve can be verified without raising the valve to the surface due fluid flow rate and/or termination by a determination of flow rate above ground. 
     In several embodiments of the present invention, the flow control valve further comprises; a valve assembly; wherein said borehole said valve is activated to close by the severance of the support for a moving part of a valve assembly. In several embodiments of the present invention, the flow control valve further comprises; a water body; an upper sliding piston in mechanical communication with the overlying and mechanically attached to said production tubing; said upper sliding piston having a base probe projecting downward; said valve further comprising a lower sealing unit with an exposed upper trigger unit; whereby severance of the production tubing above or below said water body will result in the removal of support for the production tubing overlying the upper sliding piston and thereby force the sliding piston downward; whereby a probe on the base of the upper sliding piston will contact and depress the underlying trigger on the lower sealing unit, and thereby activate the valve to close. 
     In several embodiments of the present invention, the flow control valve further comprises; a device wherein sufficiently increased fluid pressure above the valve body, will make said sliding piston slide downward so that the lower sealing element disengages from the uppermost sealing element, therein reopening the valve. In several embodiments of the present invention, the flow control valve further comprises a device wherein the flowing well is drilled on land and the fluid control valve is activated to close by the severance of the production tubing above or below ground level. In several embodiments of the present invention, the flow control valve further comprises a device wherein the valve can be reopened temporarily reversing the flow of hydrocarbon above said valve body to downward after said severed production tubing is replaced. In several embodiments of the present invention, the flow control valve further comprises; a control valve located between segments of production tubing within a borehole of a flowing oil and or gas well, under a water body and whereby severance of a pressure chamber and/or pressure tube attached to said pressure chamber or valve assembly, will expose the valve to that high hydrostatic pressure existing, around the riser of said well between sea level and the water body, and thereby closing said valve. In several embodiments of the present invention, the flow control valve further comprises; a pressure chamber in fluid communication with said control valve, a fluid line attached to said pressure chamber wherein; fluid pumped into the pressure chamber through the fluid line causes the piston to slide so a first sealing element engages a second sealing element. In several embodiments of the present invention, the flow control valve further comprises; a production tubing for fluid; a valve located between segments of said production tubing; said valve further comprising a sliding piston; said sliding piston further comprising a first sealing surface and a second sealing element; whereby increased rate of flow in the pipe below the valve makes the piston slide upward so the first sealing element engages the second sealing element therein closing the valve. In several embodiments of the present invention, the flow control valve further comprises; a sliding piston which comprises pawl. In several embodiments of the present invention, the flow control valve further comprises; a pressure chamber in fluid communication with said control valve; a fluid line attached to said pressure chamber; wherein fluid pumped into the pressure chamber through the fluid line causes the piston to slide so the first sealing element engages the second sealing element. In several embodiments of the present invention, the flow control valve further comprises; multiple valves can be located between the production tubing segments. 
     In some embodiments, some of the general principles behind the operation of the present inventions may include, without limitation, the following: the rate of flow of fluids and/or hydrocarbons through the valve, the exposure of some of the valve parts to the hydrostatic pressure that exists where an embodiment of the present invention is located, which could be: a) near or around production tubing at or below the sea floor, or b) near and/or surrounding all tubulars below any penetration or severance point of the production tubing below which an embodiment of the present invention is located, or c) between segments of production tubing below the sea floor. The weight of the remaining production tubing above the valve, which will cause activation of the valve when the supporting production tubing overlying the valve is severed. Severance of the mechanism of support for an external part of the valve control system and whereby said valve is closed. A system wherein more than one valve each activated by different functionalities that are located within the borehole thereby creating a backup. In one embodiment of the present invention, there is a probe supported by a cable that can be lowered in to the control valve to test the valve without having a severance or trauma issue occurring. 
     In several embodiments of the present invention, the present invention comprises a flow control valve located between segments of production tubing within the borehole (i.e. bore hole) and below the sea floor of a flowing oil and/or gas well, and wherein said location said valve is relatively secure from wanton or accidental destruction and the resulting uncontrolled and disastrous upward flow of hydrocarbon resulting from such destruction, and wherein said borehole, said valve can be closed automatically by some functionality not requiring surface control. In one embodiment of the present invention, there is a probe supported by a cable that can be lowered in to the control valve to test the valve without having a severance or trauma issue occurring. 
     In several embodiments of the present invention, the present invention comprises a valve body, wherein said valve further comprising an internal sliding piston, said sliding piston having at least one perforation in its side, and further comprising a first and lower sealing surface, and said valve body containing a second and upper sealing element, whereby sufficiently increased upward flowing pressure within the production tubing below said valve makes the piston slide upward so the first sealing element engages the second sealing element, thereby closing the valve. 
     In several embodiments of the present invention, in said borehole said valve is activated to close by the severance of the overlying production tubing attached to and supporting said valve. Several embodiments of the present invention, comprise a control valve in which the severance will transfer the weight of any remaining overlying production tubing attached to the upper sliding unit of the upper valve which has a lower sealing surface, and whereby said lower sealing surface will descend to engage the upper sealing surface of the lower valve unit, and whereby said valve is closed, and the upward flow of hydrocarbon is stopped. 
     In several embodiments of the present invention, the opening and closing of said valve can be checked without raising the valve to the surface. In one embodiment of the present invention, there is a probe supported by a cable that can be lowered in to the control valve to test the valve without having a severance or trauma issue occurring. 
     In several embodiments the present invention is a fluid control valve comprising: an upper chamber with an interior; a probe attached to a cable, said probe attached to a cable being capable of being suspended in said chamber with an interior; a piston chamber with an interior in communication with said upper chamber, said piston chamber further comprising a piston located in said piston chamber with an interior and a sealing plate on the bottom of said piston chamber with an interior; wherein fluid can flow through said piston chamber and into said upper chamber and thereafter out of said fluid control valve. In several embodiments, the fluid control valve of further comprises an upper casing attached to the fluid control valve and a lower casing attached to the fluid control valve. In several embodiments, when said upper casing attached to the fluid control valve supports said fluid control valve then said fluid control valve is open. In several embodiments, when said lower casing attached to the fluid control valve supports said fluid control valve then said fluid control valve is closed. 
     In other embodiments, the present invention has a probe attached to a cable that can be lowered through said upper chamber with an interior and come into mechanical communication with said piston, causing said piston to lower onto said sealing plate therein sealing said valve and preventing any fluid from flowing into said piston chamber or said upper chamber with an interior. In several embodiments of the present invention said probe is substantially hollow so as to allow fluid to flow through said probe. 
     In several embodiments of the present invention said piston is perforated distal from the center. In several embodiments of the present invention said probe attached to a cable can be raised into said upper chamber with an interior and release mechanical communication with said piston causing said piston to rise from said sealing plate therein unsealing said valve and allow fluid to flow into said piston chamber or said upper chamber with an interior. 
     In several embodiments the present invention is a fluid control valve comprising a body in sealed communication with a unattached tubular; an upper chamber with an interior; a probe attached to a cable, said probe attached to a cable being capable of being suspended in said chamber with an interior; a piston chamber with an interior in communication with said upper chamber, said piston chamber further comprising a piston located in said piston chamber with an interior and a sealing plate on the bottom of said piston chamber with an interior; wherein fluid can flow through said piston chamber and into said upper chamber and thereafter out of said fluid control valve. 
     In several embodiments of the present invention, said probe attached to a cable can be lowered through said upper chamber with an interior and come into mechanical communication with said piston causing said piston to lower onto said sealing plate therein sealing said valve and preventing any fluid from flowing into said piston chamber or said upper chamber with an interior. In several embodiments of the present invention, said probe is substantially hollow so as to allow fluid to flow through said probe. In several embodiments of the present invention, said probe attached to a cable can be raised into said upper chamber with an interior and release mechanical communication with said piston causing said piston to rise from said sealing plate therein unsealing said valve and allow fluid to flow into said piston chamber or said upper chamber with an interior. In several embodiments of the present invention, said piston is perforated distal from the center. 
     In several embodiments of the present invention, said body, when released from sealed communication with said unattached tubular and will move down through said unattached tubular causing said body to come into mechanical communication with said piston causing said piston to lower onto said sealing plate therein sealing said valve and preventing any fluid from flowing into said piston chamber or said upper chamber with an interior. In several embodiments of the present invention, a tongue attached to said body to assist with guiding said body through said unattached tubular if said sealed communication is broken between said body and said unattached tubular. 
     In several embodiments, the present invention has a method for using fluid control valve comprising the steps of: obtaining a fluid control valve with: an upper chamber with an interior; a probe attached to a cable; said probe attached to a cable being capable of being suspended in said chamber with an interior a piston chamber with an interior in communication with said upper chamber; said piston chamber further comprising a piston located in said piston chamber with an interior and a sealing plate on the bottom of said piston chamber with an interior; wherein fluid can flow through said piston chamber and into said upper chamber and thereafter out of said fluid control valve; lowering said probe attached to a cable can be lowered through said upper chamber with an interior and come into mechanical communication with said piston causing said piston to lower onto said sealing plate therein sealing said valve and preventing any fluid from flowing into said piston chamber or said upper chamber with an interior. 
     In some embodiments, the method further comprises the step of: raising said probe attached to a cable into said upper chamber with an interior and releasing mechanical communication with said piston causing said piston to rise from said sealing plate therein unsealing said valve and allow fluid to flow into said piston chamber or said upper chamber with an interior. 
    
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
       For a more complete understanding of the present disclosure, and the advantages thereof, reference is now made to the following descriptions to be taken in conjunction with the accompanying drawings describing specific embodiments of the disclosure, wherein: 
         FIG. 1A  illustrates one embodiment of the present invention in cross sectional view with open flow; 
         FIG. 1B  illustrates one embodiment of the present invention in cross sectional view with closed flow; 
         FIG. 2A -illustrates one embodiment of the present invention in cross sectional view with open flow; 
         FIG. 2B -illustrates one embodiment of the present invention in cross sectional view with closed flow; 
         FIG. 3A -illustrates one embodiment of the present invention in cross sectional view with fluid flow blocked; 
         FIG. 3B -illustrates one embodiment of the present invention in cross sectional view with upward fluid flow; 
         FIG. 4A  illustrates one embodiment of the present invention in cross sectional view with open flow; 
         FIG. 4B  illustrates one embodiment of the present invention in cross sectional view with closed flow; 
         FIG. 5A  illustrates one embodiment of the present invention in cross sectional view with open flow; and 
         FIG. 5B -illustrates one embodiment of the present invention in cross sectional view with closed flow. 
         FIG. 6  illustrates one embodiment of the present invention in cross sectional view with open flow; 
         FIG. 7  illustrates one embodiment of the present invention in cross sectional view with closed flow by weight of tube; 
         FIG. 8  illustrates one embodiment of the present invention in cross sectional view with open flow with two tubulars with double seal pistons; 
         FIG. 9  illustrates one embodiment of the present invention in cross sectional view with closed flow due to severance of a production tube; 
         FIG. 10  illustrates one embodiment of the present invention in cross sectional view with fluid flow in open valve position with two tubulars and a sealing valve. 
         FIG. 11  illustrates a cross sectional view of another embodiment of the invention in an open position. 
         FIG. 12  illustrates a cross sectional view of another embodiment of the invention in a closed position. 
     
    
    
     DETAILED DESCRIPTION 
     One or more illustrative embodiments incorporating the invention disclosed herein are presented below. Applicant has created a revolutionary and novel pipe valve control and method of use. 
     In the following description, certain details are set forth such as specific quantities, sizes, etc. so as to provide a thorough understanding of the present embodiments disclosed herein. However, it will be evident to those of ordinary skill in the art that the present disclosure may be practiced without such specific details. In many cases, details concerning such considerations and the like have been omitted inasmuch as such details are not necessary to obtain a complete understanding of the present disclosure and are within the skills of persons of ordinary skill in the relevant art. 
     Referring to the drawings in general, it will be understood that in some embodiments of the present invention, the present invention can be rotated 180 degrees and still have full functionality. 
     Referring to the drawings in general, it will be understood that the illustrations are for the purpose of describing particular embodiments of the disclosure and are not intended to be limiting thereto. Drawings are not necessarily to scale and arrangements of specific units in the drawings can vary. 
     While most of the terms used herein will be recognizable to those of ordinary skill in the art, it should be understood, however, that when not explicitly defined, terms should be interpreted as adopting a meaning presently accepted by those of ordinary skill in the art. In cases where the construction of a term would render it meaningless or essentially meaningless, the definition should be taken from Webster&#39;s Dictionary, 11th Edition, 2008. Definitions and/or interpretations should not be incorporated from other patent applications, patents, or publications, related or not, unless specifically stated in this specification or if the incorporation is necessary for maintaining validity. “Christmas Tree” as defined herein includes an oil-well control device consisting of an assembly of fittings placed at the top of the well. 
     One or more illustrative embodiments incorporating the invention disclosed herein are presented below. Applicants have created a revolutionary and novel pipe valve control. In many preferred embodiments of the present invention it is preferable to place the inventive valve within a borehole at some distance below the sea floor, or surface of a ground well. In many embodiments, the weight of a portion of string or piping can be sufficient to activate the valve mechanism. 
     In many embodiments of the present invention, several different embodiments of the invention may be used between segments of the production tubing to increase the redundancy and backup systems. In some embodiments of the present invention it is envisioned that control parts might be miniaturized and placed within the inventive valve body itself. In several embodiments of the present invention, it is envisioned that the inventive valve may be reopened by reversing the fluid flow and pressure in production tubing, thereby preventing actual removal of the inventive valve and allowing the inventive valve to be reused. In several embodiments, the internal control valve, and all component parts, are preferably composed of materials as used in normal drilling operations for drilling, drill strings, and/or well bores. 
       FIG. 1A  illustrates a cross sectional view of one embodiment of the present inventive valve  1000  in open position.  FIG. 1B  illustrates a cross sectional view of one embodiment of the present inventive valve  1000  in closed position. As illustrated in  FIG. 1A  there is an internal control valve  12 . In this embodiment of the present invention, the internal control valve  12 , activates to close when the upward rate of fluid flow  4  exceeds a predetermined rate. This rate may vary depending on wellbore size, flow rate and other factors and should be determined in advance of application of the present inventive device. The present inventive device, in all embodiments, may be comprised of various sized, shapes and weights for component parts so as to achieve desired, and predetermined flow rates with fluid flow applications. 
     In this embodiment of the present invention, the valve closure of the present inventive valve  1000  is governed, in part by the weight (and port opening  3 ), of the sliding piston  2 . Sliding piston  2  is preferably designed so that when fluid flow  4  is at a normal predetermined level. The weight of sliding piston  2  can be of sufficient mass to be in the open position during normal levels. It should be noted that various predetermined flow rates can be established and utilized in several applications of the present invention. Sliding piston  2  is preferably designed to fit within the upper sealing surface  10  and between the production tubing  14  and  16 . Sliding piston  2  can also preferably be constructed with multiple flow port opening(s)  3 . The flow ports or openings  3  can be constructed of varying sizes and diameters based upon the pre-established flow rate parameters. 
     It is envisioned that the internal control valve  12  can be attached to the production tubing in the manner known in the art for such attachments with production tubing to allow for the flow, or stoppage of flow of fluids through the internal control valve. It is for this reason that the present inventive device can be constructed in variable sizes, and weights so as to accommodate various sizes, tolerances, and requirements of drill string utilized in the industry. In one embodiment of the present invention, the internal control valve  12 , activates to close when the upward rate of fluid flow  4  exceeds the predetermined rate and the valve closure is governed in part by the weight of the sliding piston  2 . 
     In several embodiments of the present invention it is possible to lower the effective weight of the sliding piston  2  by including a hollow flotation chamber with the sealing base  7 . It should be noted that various predetermined flow rates can be established and utilized in several applications of the present invention. It should also be noted, that the present invention may be constructed so as to tolerate the corrosive effects of many types of fluids that may flow through the present inventive device. 
     In one embodiment of the invention, the internal control valve  12 , is preferably located between segments of production tubing  14  and  16 , and preferably below the sea floor, although in several embodiments of the present invention, it can be located below the surface of a ground well or at another location. 
     In several embodiments, the internal control valve  12  preferably contains a downward facing upper sealing surface  10 , which is internal and part of the valve wall  1 . The valve wall  1 , in this embodiment, contains, and is located adjacent to, a sliding piston  2 , having side ports  3 , through which hydrocarbon can flow upward  4 , or downward  5 , a sliding piston  2  having a sealing base  7 , having a lower and upward facing sealing surface  8 , and a piston flange stop  6  which limits the downward movement of the sliding piston  2 . 
     In some embodiment of the invention, the internal control valve  12 , is preferably located between segments of production tubing  14  and  16  preferably below the sea floor. In several embodiments, the internal control valve  12  preferably contains an upper sealing surface  10  which is internal and part of the valve wall  1 . The valve wall  1  in this embodiment is located adjacent to a sliding piston  2 , but not in mechanical communications with valve wall  1 . 
     In some embodiments of the present invention, the sliding piston  2  has side ports  3 , through which hydrocarbon can flow upward flow  4 , or downward  5 , a sliding piston sealing base  8 , having a sealing surface  9 , and a piston flange stop  6  which limits the downward movement of the sliding piston  2 . It is envisioned that the individual components of the present invention can be in a variety of geometric shapes, including the ones disclosed in detail. 
     As shown in  FIG. 1A , the fluid flow through internal control valve  12  can take place automatically, but when the lifting power of the upward rate of flow of hydrocarbon flow  4  exceed a calculated and established upward flow rate, and thereby causes the sealing base  7  to move upward, whereby the surface  8  of the sealing base  7  engages the sealing surface  10  inside the sliding piston  2  and thereby closes the valve to any upward flow  4  of hydrocarbons. The rate of the flow can be varied without removing the valve from the borehole. Under extreme circumstance (including partial penetration of the production tubing) the closing of said internal control valve  12  could be achieved by the operator severing the production tubing  14  above the mud line. 
     As further shown in  FIGS. 1A and 1B , in some embodiments, the opening and closing ability of the flow  4  is also affected by the size of the piston port openings  3  and the weight of the sliding piston  2 . The factors are easily variable; in particular, the weight within the sliding piston  2  (such as by ball bearings dropped down the annulus of the production tubing). Such weights could be removed by techniques currently known in the art to accommodate various pressure applications and parameters. 
     As shown in  FIG. 1B , in some embodiments, closing the internal control valve  12  takes place automatically when the lifting power of the upward rate of flow of hydrocarbon flow  4  exceeds a calculated and established upward flow rate, and thereby causes the sliding piston  2  to move upward, whereby the upward facing sealing surface  8  of the sliding piston sealing base  7  engages the downward facing sealing surface  10  inside the internal control valve  12  and thereby closes the internal control valve  12  to any upward flow  28  of hydrocarbons. The normal rate of flow can be varied without removing the valve from the borehole, by using a flow meter and a normal ball valve inserted between joints of the production or collection tubing on the rig floor, as is known in the art. Under some extreme circumstance (including partial penetration of the production tubing) the closing of said internal control valve  12  could be achieved by the operator severing the production tubing  14  above the sea floor (mud line). 
       FIG. 2A  illustrates another embodiment of the invention  1010  with an external control valve mechanism  30  with open flow.  FIG. 2B  illustrates another embodiment of the invention  1010  with an external control valve mechanism  30  with closed flow. In these embodiments of the invention the control valve mechanism  30  within the riser  34  activates when the hydrostatic pressure surrounding the riser  34  and above the sea floor (or in some embodiments surface of a ground well)  48 , infiltrates the control tubular  32  adjacent to the production tubing  35 , as when the tubular  32  is compromised by penetration or severance.  FIG. 2B . In such a case, the resulting exposure of the pressure chamber  52  and the sliding piston  36 , in the valve activating mechanism  30 , to the immense hydrostatic pressure of the invading seawater will cause the teeth  38  of the sliding piston  36  to rise while engaging the teeth  40  of the ratchet wheel  45  which is connected to the rotating ball  43  in the ball valve  42 . In some embodiments, at this point the ball  43  will rotate within the socket  44  and thereby close and prevent the upward flow  46  of well hydrocarbons. The ratcheting of the ball valve  42  is in a fashion known in the art. 
     In some embodiments, when hydrostatic pressure at, or above, the sea floor (or in some embodiments surface of a ground well)  48  is lessened or removed, as and when the tubular pneumatic fluid line tubular  32  is repaired or replaced, then the ball  43  can rotate to open and restore the upward hydrocarbon flow  46 , and hydrocarbon flow can resume. It is envisioned that in various permutations of the present inventive device, the piston w/pawl  36  and ball valve  42  can be of varying geometrical and solid shapes as would be known in the art to form a sealing mechanism. 
     In one embodiment of the present invention, it is envisioned that a hydrostatic or pneumatic fluid line  54  could be attached to the control valve mechanism  30  by which fluid could be pumped into the pressure chamber  52 . In such situations pressure in the pressure chamber  52  can be controlled by an external user causing the piston  36  to be actuated by which the ratcheted teeth  40  could be raised or lowered causing the ball valve  42  to engage or disengage the socket  44 . The raising, or lowering of the ball valve  42  would be actuated by decreases or increases in fluid pressure in the pressure chamber  52 . Hence, increasing pressure could cause the increased fluid to push up or lower the piston  36 . 
     In several embodiments of the present invention, as shown in  FIGS. 2A and 2B , it is envisioned that the valve aspect of the present invention can be controlled externally, from the exposure to hydrostatic pressure existing at, or near, the seabed floor, automatically, when the riser and pneumatic fluid line are penetrated or severed. It is also envisioned that the external control parts could be miniaturized and contained within the invention  1010 . In one such embodiment of the present invention, it is envisioned that a hydrostatic or pneumatic fluid line  54  could be attached to the control valve activating assembly mechanism  30  by which fluid could be pumped into the pressure tube or chamber  52 . In such situations pressure in the pressure chamber  52  can be controlled from the surface causing the piston  36  to be actuated by which its ratcheted teeth  40  could be raised or lowered causing the ball valve  42  to engage or disengage the socket  44 . Such actuation of the piston  36  would be enabled in the same manner as actuations of piston through fluid lines as is known in the art. The raising, or lowering of the ball valve  42  would be actuated by decreases or increases in fluid pressure in the pressure chamber  52 . 
     In several embodiments, the valve aspect of the present invention can be controlled externally by pressure increase from the surface, or automatically by hydrostatic pressures when the pneumatic fluid line tubular  32  is penetrated or severed, and whereby the interior of the line and the pressure chamber  52  are exposed to the high hydrostatic pressure surrounding the production tubing below sea level and above the sea floor. In some embodiments, it is also envisioned that the external control parts could be miniaturized and contained within the valve body. 
       FIG. 3A  illustrates another embodiment of the present invention  1020  in partial cross-sectional view in open flow state.  FIG. 3B  illustrates another embodiment of the present invention  1020  in partial cross-sectional view in closed flow state. As illustrated in  FIG. 3B , the invention is in closed state, in which the valve  70  is activated by the depressing weight of production tubing  60   a  above the valve  70  when production tubing  60   a  above the valve  70  is severed or broken and the valve head  74  is engaged with the socket  76 . Valve stop upper valve  71  is located above the valve head  74 . The floor  73  is also illustrated in this embodiment. In some embodiments, the valve is open when supported by the overlying production tubing and is closed and sealed when supported, at least, by the underlying production tubing. In some embodiments, the valve can be activated by a piston or a probe. In several embodiments, the present invention is a safe and quick shut in mechanism. 
     As illustrated in  FIGS. 3A and 3B , the embodiments of the invention, operates as follows: Fluid  72  usually flows upward through the valve  70  on the path indicated.  FIG. 3A . The production tubing  60   a  is supported and attached to additional production tubing units above it when the well is flowing. In the event that the production tubing  60   b  is severed, then it is envisioned in the present invention that weight of the higher production tubing  60   a  will push downward on the valve  70  causing the valve head  74  to drop and to engage with socket  76  therein preventing the upward flow of additional fluids  72 . Although illustrated as a plunger type valve, other valve configurations such as a ratchet and pawl can be utilized in the present invention instead of a plunger type valve as illustrated in  FIGS. 3A and 3B . 
     As shown in  FIG. 3A , in one embodiment, in order to open the valve  70 , the production tubing  60   a  is lifted in an upward fashion, thereby lifting the valve head  74  and removing it from the socket  76 . The lifting can be done in a manner known in the art for lifting production tubing. Not shown is an external and vertical tongue and groove, or similar mechanism as used in the art, between the upper valve  71  and the lower valve unit, and whose purpose would be to keep the two parts of the valve from rotating separately. As used herein, “tongue and groove” can mean a joint formed by inserting part of one surface material into a recessed area of a second surface. This joint design offers excellent stress resistance. In several embodiments of the present invention the tongue can move within the groove, but not rotate about the groove. This would mean that when the upper valve  71  is rotated then valve  70  would rotate in the same manner. 
       FIG. 4A  shows another embodiment of the present invention in cross sectional view in open format.  FIG. 4B  shows another embodiment of the present invention in cross sectional view in closed format. One of the advantages as shown in  FIG. 4B  is that the valve  1040  can stay closed and sealed after overlying support is reestablished and the valve  1040  is drawn to the surface. It thereby eliminates any necessity to “kill the well flow” (by heavy mud injection) in order to pull the valve and replace it. In this embodiment, the valve  1040  can be reopened by reversing the fluid flow, temporarily to downward from upward. As shown in  FIG. 4A , fluid  201  usually flows upward through the lower valve assembly  202  that is slideably attached to the upper valve  203 . The upper valve  203  is normally attached to the production tubing  204 , and the hydrocarbon fluid  201  usually flows along the path indicated. See  FIG. 4A . 
     In several embodiments, the upper valve  203  is supported by many segments of production tubing  204  between it and the surface. In the event that the higher production tubing  204  is severed, it is envisioned in the present invention that the tremendous weight of the remaining and higher production tubing  204 , attached to, and above, the upper valve  203 , will push downward on the upper valve  203 . The upper valve  203  will then descend, thereby causing the downward pointing valve head probe  205  to engage with and depress the trigger unit  206  and its attached upper cam  207 . Thereby the attached upper cam  207  forces sideways the sliding piston roller  208  and its attached sliding piston pin  209  which is connected to a shear  210 . 
     In several embodiments, the sideways motion of the sliding piston roller  208  and the sliding piston pin  209  thereby removes the shear  210  from the shear notch  211  in the sliding piston  212 . As a result, the valve mainspring  213  and the upward flow of fluid  214  below the sliding piston base  217  force the upward facing surfaces  215  and  216  of the sliding piston sealing base  217  to engage in a sealing manner with the downward facing sealing surfaces  218  and  219  of the internal valve wall assembly  202  and whereby the upward flow of fluid  201  and  214  is terminated. 
     In some embodiments, as shown in  FIGS. 4A and 4B , lifting the production tubing  204  attached to the upper valve  203  will raise the upper valve  203 , thereby removing the upper valve probe  205  from the trigger unit  206 . Induced downward flow  220  will push downward on the sliding piston base  217  and thereby lowering the sliding piston  212 . In conjunction with this action, the trigger unit  206  is forced upward by the trigger spring  221  until it is stopped by the horizontal spring  222 . This upward movement forces the lower cam  223  upward until it engages and forces the sliding piston roller  208 , along with the sliding piston pin  209 , sideways which forces the shear  210  back into the shear notch  211  in the sliding piston  212 . The sliding piston  212  is then locked in a down (open) position when the downward flow  220  is ceased. When the sliding piston  212  is locked, and the downward flow  220  is stopped, the upward flow of fluid  201  and  214  can recommence. 
     In several embodiments, the following will describe closing, reopening and replacement of the weight activated valve  1040  as per  FIGS. 4A and 4B . In view of  FIGS. 4A and 4B , fluid  201  usually flows upward through the lower valve assembly  202  that is slidably attached to the valve  203 . The valve  203  is normally attached to the production tubing  204 , and the fluid  201  usually flows along the path indicated. See  FIG. 4A . The valve  203  is normally attached and supported by segments of production tubing  204  above it. 
     In some embodiments, in the event that the higher production tubing  204  is severed, it is envisioned, in the present invention that the tremendous weight of the remaining and higher production tubing  204 , attached to and above the valve head assembly  202 , will push downward on the valve head assembly  202 . Valve head assembly  202  will then descend, thereby causing the downward pointing valve head probe  205  to engage with and depress the trigger unit  206  and its attached upper cam  207 . At this point, the attached upper cam  207  forces sideways the sliding piston roller  208  and its attached sliding piston pin  209  which it is connected to. The sideways motion of the sliding roller pin  208  thereby removing the shear  210  from the shear notch  211  in the sliding piston  212 . As a result, the valve mainspring  213  and the upward flow of fluid  214  below the valve assembly  202  force the upward facing surfaces  215  and  216  of the sliding piston sealing base  217  to engage in a sealing manner with the downward facing sealing surfaces  218  and  219  of the internal valve  203  and whereby the upward flow of fluid  201  and  214  is terminated. 
     In some embodiments, one benefit of one embodiment of the present invention is that when the valve has been closed because of severance of the production tubing, if desirable it can be opened in place after reconnection of the production tubing by reversing the flow (as described above). If it is necessary to retrieve the valve to the surface, and the flow is not reversed, the valve will remain closed while the valve clears the rig floor. 
     In some embodiments, if it is necessary to replace the valve, in one embodiment of the invention, a closed system can be maintained by placing a standard ball valve (open) below the described inventive valve before the inventive valve is initially lowered in the borehole. When this standard ball valve clears the rig floor, it can be closed manually. As described in this manner, the inventive valve can be replaced without any danger of exposure to upward fluid flow through the production tubing and the standard ball valve. As described herein, the inventive valve can also be tested in place in the borehole without and danger of exposure or destruction. 
       FIG. 5A  shows one embodiment of the present invention in partial cross-sectional view in open flow.  FIG. 5B  shows one embodiment of the present invention in partial cross-sectional view in closed flow. As shown in  FIG. 5  in one embodiment of the present invention  1050  the valve  300  is activated to close by a weighted assembly  302  positioned above the valve  300  when the line or cable or support mechanism  304  supporting the weighted assembly  302  is severed or broken. It is envisioned that the line or cable or support mechanism  304  can be any supportive mechanism as is known in the art. 
     As shown, this embodiment of the present invention operates as follows: Fluid  306  usually flows through the valve  300  along the upward path as shown. A weighted assembly  302  is supported by a line, cable or other support mechanism  304 , attached to the production tubing  308  or on the rig floor. In the event that the support mechanism  304  is severed or broken, it is envisioned, in the present invention that the weighted assembly  302  will move downward, thereby causing the teeth  310  of the pawl  312 . This movement in the weighted assembly  302  causes it to engage with the teeth of the ratchet  314  thereby rotating the ball in the socket of the ball valve  316  and preventing upward flow of fluids  306 . In order to open the valve of this embodiment, the weighted assembly  302  must be lifted in an upward fashion and reattached to its original or an additional support unit of the production tubing  308  or rig floor. In some embodiments, the valve is open when supported by the overlying production tubing and is closed and sealed when supported, at least, by the underlying production tubing. In some embodiments, the valve can be activated by a piston or a probe. In several embodiments, the present invention is a safe and quick shut in mechanism. This embodiment the vector is changed from vertical to rotational. 
       FIG. 6  illustrates one embodiment of the present invention in cross sectional view with open fluid flow.  FIG. 6  illustrates the present invention  1000  as applied with a valve comprising one tubular  1045  and a piston  1030  (with a piston head) which is activated to close by the lowering (whether controlled or uncontrolled) of a supported probe  1020  substantially in the middle of the invention  1000 . As shown, the present inventive device  1000  may be encased in an attached tubular  1045 . Attached tubular  1045  is of the kind normally used in the art for sub sea oil exploration. As shown, production tubing  1005  is a mechanical attachment with attached tubular  45  in a manner as known in the art. As illustrated, production tubing  1005  is preferably on the top side of attached tubular  1045  in many embodiments. Production tubing  1005  is of the type typically used in the art. 
     Also, shown in  FIG. 6 , is valve  1500  is preferable constructed to be inside attached tubular  45 . As illustrated, valve  1500  can be designed with a shape such that there is a smaller diameter upper portion  1510  larger diameter middle portion  1520  and piston housing  1530 . In many embodiments, the totality of the diameter of the valve  1500  will not exceed the diameter of the tubular  1045 . As shown, control cable  1015  is located substantially in the middle of valve  1500  and supports probe  1020 . Cable  1015  is of the kind known in the art that can support probe  1020  inside wellbore conditions. Cable  1015  may be comprised of a pliable material capable of supporting probe  1020 . In several embodiments, cable  1015  is designed to be lowered or raised throughout valve  1500 . Cable  1015  is preferably attached to probe  1020  in a manner known in the art. In preferred embodiments, probe  1020  is constructed to allow for fluid to flow  1010  around probe  1020  with marginal impediment to the fluid flow  1010  rate. In some embodiments, probe  1020  is constructed as a cylinder with a hollow interior for fluid flow  1010  through. However, one of ordinary skill in the art would be able to construct probe  1020  in a variety of three dimensional geometric shapes, including, but not limited to cones, cuboids, or half spheres. In several embodiments of the present invention, probe  1020  is constructed of a material capable of withstanding pressures and the corrosive elements found in downhole drilling applications. 
     As shown in  FIG. 6 , in one embodiment of the present invention, the lower portion of valve  1500  is substantially comprised of the piston housing  1530 . Piston housing  1530  is preferably designed to house piston head  1030  and lower valve sealing surface  1035 . Piston  1030  is designed in several embodiments to be able to move vertically throughout piston housing  1530 . Piston head  1030  is preferable created to be able to be actuated into a position of closure with lower sealing surface  1035  when fluid flow rate  1010  falls below a certain threshold, production tubing  1005  is lowered or severed, and or probe  1020  is lowered onto piston head  1030  causing the weight of probe  1020  to push piston head  1030  flush with lower sealing surface  1035 . 
     As shown in  FIG. 6 , piston  1030 , in some embodiments, maybe comprised with perforations  1025  that are distal to the main central stem  1033 . The position of perforations  1025  can vary. In operation, perforations  1025  allow fluid flow  1010  through the piston  1030  itself. The perforations may be designed to be of the type to allow for fluid flow in a downhole drilling application as is known in the art. In several embodiments of the present invention perforations  1025  are designed to substantially align with lower valve sealing surface  1035  when piston  1030  is in a closed position therein creating a seal and preventing the further flow of fluids  1010  up through the valve  1500  and therein the production tubing  1005  as well. As illustrated, in many embodiments of the present invention, piston  1030  is constructed with a solid flat surface  1031  which has perforations  1025  distal to the main stem  1033 . Main stem  1033 , in many embodiments has a stabilizer  1034  on the end opposite of flat surface  1031 . Stabilizer  1034  is preferably designed to prevent rotation of piston  1030  which could cause it to get lodged in production tubing  1040 . Piston  1030  is preferably constructed of materials designed to withstand oil and/or gas drilling operations. 
     As shown in  FIG. 6 , in many embodiments of the present invention, the present invention operates as follows: During normal operating conditions, fluid flows  1010  from the lower portion of the valve  1540  through and around piston  30  and through valve constriction  1525  which separates piston housing  1530  from middle portion  1520 . In some embodiments of the present invention, fluid flow  1010  can continue around, and in some case through probe  1020  attached by cable  1015 . Fluid then flows out of upper portion  1510  and out through production tubing  1005 . 
       FIG. 7 , illustrates one, of many, scenarios in which probe  1020  can be lowered onto piston head  1030 . In this scenario, a user can lower probe  1020  onto piston head  1030  by providing slack in cable  1015 . The slack in cable  1015  allows for the weight of probe  1020  to push on piston head  1030  (due to the mass of probe  1020 ) and push piston head  1030  into a sealing communication with lower valve sealing surface  1035 . As a seal is formed, fluid flow  1010  is impeded from proceeding past production tubing  1040 . It is by this manual method of providing slack to cable  1015  that a user can test to see is piston head  1030  and valve  1020  are working properly to shut in production tubing in case of a breach or perforation of production tubing/drill string. In  FIGS. 6-10  there is no need for severance of a production tubing above the valve. In some of these embodiments, the valve is open when supported by the overlying production tubing and is closed and sealed when supported, at least, by the underlying production tubing. In some embodiments, the valve can be activated by a piston or a probe. In several embodiments, the present invention is a safe and quick shut in mechanism. 
     As shown in  FIG. 8 , in one embodiment, valve  2500  is preferable constructed to be attached to tubular  1190 , more specifically to production tube  1100 . As illustrated, valve  2500  can be designed with a shape such that there is a smaller diameter upper portion  2510  larger diameter middle portion  2520  and piston housing  2530 . In many embodiments, the totality of the diameter of the valve  2500  will not exceed the diameter of the tubular  1180 . As shown, control cable  1125  is located substantially in the middle of valve  2500  and supports probe  1130 . Cable  1125  is of the kind known in the art that can support probe  1130  inside wellbore conditions. Cable  1125  may be comprised of a pliable material capable of supporting probe  1130 . 
     In several embodiments, cable  1125  is designed to be lowered or raised throughout valve  2500 . Cable  1125  is attached to probe  1130  in a manner known in the art. In preferred embodiments, probe  1130  is constructed to allow for fluid to flow around probe  1130  with marginal impediment to the fluid flow rate  1110 . In some embodiments, probe  1130  is constructed as a cylinder with a hollow interior for fluid flow through. However, one of ordinary skill in the art would be able to construct probe  1130  in a variety of three dimensional geometric shapes, including, but not limited to cones, cuboids, or half spheres. In several embodiments of the present invention, probe  1130  is constructed of a material capable of withstanding pressures and the corrosive elements found in downhole drilling applications. In several embodiments of the present invention tongue  1115  is attached to the upper valve tubular  1190  and runs into unattached tubular  1180 . In several embodiments of the present invention unattached tubular  1180  has an interior sealing contact with valve body  2580 . 
     As shown in  FIG. 8 , in several embodiments, the lower portion of valve  2500  is substantially comprised of the piston housing  2530 . Piston housing  2530  is preferably designed to house piston head  1030  and lower valve sealing surface  1035 . Piston  1135  is designed in several embodiments to be able to move vertically throughout piston housing. Piston head  1135  is preferable created to be able to be actuated into a position of closure with lower sealing surface  1150  when fluid flow rate  1110  falls below a certain threshold, production tubing  1100  is severed, and or probe  1130  is lowered onto piston head  1135  causing the weight of probe  1130  to push piston head  1135  flush with lower sealing surface  1150 . 
     As shown in  FIG. 8 , piston  1135 , in some embodiments, maybe comprised with perforations  1136  that are distal to the main central stem  1137 . In operation, perforations  1136  allow fluid flow  1110  through the piston  1135  itself. The perforations maybe designed to be of the type to allow for fluid flow in a downhole drilling application as is known in the art. In several embodiments of the present invention perforations  1136  are designed to substantially align with lower valve sealing surface  1150  when piston  1135  is in a closed position therein creating a seal and preventing the further flow of fluids  1110  up through the valve  2500  and therein the production tubing  1100  as well. 
     As illustrated, in many embodiments of the present invention, piston  1135  is constructed with a solid flat surface  1140  which has perforations  136  distal to the main stem  1137 . Main stem  1137 , in many embodiments has a stabilizer  1138  on the end opposite of flat surface  1140 . Stabilizer  1138  is preferably designed to prevent rotation of piston  1135  which could cause it to get lodged in production tubing  1160 . Piston  1135  is preferably constructed of materials designed to withstand oil and/or gas drilling operations. 
     As shown in  FIG. 8 , in many embodiments of the present invention, the present invention operates as follows. During normal operating conditions, fluid flows  1110  from the lower portion of the valve  2540  through and around piston  1136  and through valve constriction  2525  which separates piston housing  2530  from middle portion  2520 . In some embodiments of the present invention, fluid flow  1110  can continue around, and in some case through probe  1130  attached by cable  1125 . Fluid then flows out of upper portion  2510  and out through production tubing  100 . 
       FIG. 9 , illustrates one scenario in which probe  1130  is held relatively stationary in view of piston head  1135 . In this scenario, however, the sealing contact  1175  is broken between the unattached tubular  1180  and the valve body  2580 . When this occurs, potentially due to a breach or severance of drill string above valve  2500 , valve body  2580  will fall into unattached tubular  1180  pushing valve body  2580  to compress piston housing  1170  and force piston  135  to come into sealing contact with valve sealing part  1150 . In this manner, no fluid flow  1165  can proceed past production tube  1160  therein shutting of the valve  2500 . 
       FIG. 10 , illustrates one scenario in which probe  1130  is lowered onto piston head  1135 . In this scenario, a user can lower probe  1130  onto piston head  1135  by providing slack in cable  1125 . The slack in cable  1125  allows for probe  1130  to push on piston head  1135  (due to the mass of probe  1130 ) and push piston head  1135  into a sealing communication with lower valve sealing surface  1150 . As a seal is formed, fluid flow  1110  is impeded from proceeding past production tubing  1160 . It is by this manual method of providing slack to cable  1125  that a user can test to see if piston head  1135  and valve  2500  are working properly to shut in production tubing in case of a breach or perforation of production tubing/drill string. 
     It must be understood that in extreme emergencies the operator of the production tube and the valve of the present invention can always have the option of deciding to sever at the mud line, any and all, tubing or supporting lines necessary to close any of these valves. This is fundamental for all valves and embodiments associated with this invention. It is envisioned that in one or more of the embodiments of the present invention there can be multiple valves as described herein for increased safety and efficacy. 
       FIG. 11  shows one embodiment of the invention with production tubing  1005  and  1040 . As shown production tubing  1040  is attached to the valve via threaded end plug  2035 . On top of threaded end plug  2035  is unattached valve part sealing  1035 . Attached valve  1030  is located above the unattached valve part sealing  1035  is in the open position and has perforations  1025 . Further shown is packer  2020  and packer activating sliding weight cylinder  2030 . Attached to packer  2020  is attached to the attached part of the valve  2047 . Further, shown is extra tubular  2040 . As shown, in this embodiment, the fluid  1010  is flowing upward and through the valve. 
       FIG. 12  shows one embodiment of the invention with production tubing  1005  and  1040 . As shown production tubing  1040  is attached to the valve via threaded end plug  2035 . On top of threaded end plug  2035  is unattached valve part sealing  1035 . Attached valve  1030  is located adjacent the unattached valve part sealing  1035  is in the closed position and has perforations  1025 . Further shown is packer  2020  and packer activating sliding weight cylinder  2030 . Attached to packer  2020  is attached to the attached part of the valve  2047 . Further shown is extra tubular  2040 . As shown, in this embodiment, the fluid  1010  is closed and not flowing through the valve.  2020 ,  2030 ,  2035  can be constructed of one piece of material in some embodiments. 
     It must be understood that in extreme emergencies the operator of the production tube and the valve of the present invention can always have the option of deciding to sever at the mud line, any and all, tubing or supporting lines necessary to close any of these valves. This is fundamental for all valves and embodiments associated with this invention. It is envisioned that in one or more of the embodiments of the present invention there can be multiple valves as described herein for increased safety and efficacy. 
     Although several preferred embodiments of the present invention have been described in detail herein, the invention is not limited hereto. It will be appreciated by those having ordinary skill in the art that various modifications can be made without materially departing from the novel and advantageous teachings of the invention. Accordingly, the embodiments disclosed herein are by way of example. It is to be understood that the scope of the invention is not to be limited thereby.

Summary:
The present invention applies to flowing wells. Within a flowing well, production tubing moves fluid upward under immense pressures and is greatly exposed to damage, either accidental, or intentional. Recently, there is increased concern in protecting our production wells from damage, either natural or man-made. The present invention is designed to address the problems of controlling hydrocarbon, and fluid flow, through production tubing after the production tubing is compromised by penetration or severance.