PIPE VALVE CONTROL AND METHOD OF USE

Abstract

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.

Description

CROSS-REFERENCE TO RELATED APPLICATIONS

This application claims priority to U.S. provisional patent application 61/787,184 filed Mar. 15, 2013, which are incorporated by reference herein in their 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 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.

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 one embodiment, 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'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 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'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 tubular. 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 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. Many other novel advantages will be further disclosed in the detailed description of the invention.

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 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 somewhere 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 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 somewhere 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 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 somewhere 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 or flow rate 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 somewhere 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 somewhere 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 by 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 a 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.

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.

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 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'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 of the present invention, several different embodiments of the invention maybe 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. 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 the 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 weight, sliding piston 2 will be of sufficient mass to be in the open position. 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 is also preferably 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 is 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. Though not shown, 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 be noted, that the present invention maybe 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 somewhere below the sea floor, although in several embodiments of the present invention, it can be located below the surface of a ground well. 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 this embodiment of the invention, the internal control valve 12, is preferably located between segments of production tubing 14 and 16 preferably somewhere 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 the present embodiment of the present invention, the sliding piston 2 which 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 shapes, including the ones disclosed in detail.

As shown in FIG. 1a, the fluid flow through internal control valve 12 takes 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 somewhere above the mud line.

As further shown in FIGS. 1a and 1b, 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, 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 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 somewhere 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 this embodiment 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. 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 ratching of the ball valve 42 is in a fashion known in the art.

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 increased in fluid pressure in the pressure chamber 52. Hence, increasing pressure would cause the increased fluid to push up 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.

Hence it is envisioned, and disclosed, that, 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 somewhere below sea level and above the sea floor. 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 60a above the valve 70 when production tubing 60a 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.

As illustrated, the embodiments of the invention, as illustrated in FIGS. 3a and 3b, operates as follows: Fluid 72 usually flows upward through the valve 70 on the path indicated. FIG. 3a. The production tubing 60a is supported and attached to additional production tubing units above it when the well is flowing. In the event that the production tubing 60b is severed, then it is envisioned in the present invention that that weight of the higher production tubing 60a 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 is 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 order to open the valve 70, the production tubing 60a 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” means 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 invent the tongue can move vertically 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 will stay closed 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.

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. 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.

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.

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 slideably 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 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.

A 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.

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 somewhere 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.

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.

Claims

1. A flow control valve located between segments of production tubing within a borehole below a sea floor of a flowing oil and/or gas well, and wherein said flow control valve can be closed automatically through hydrostatic pressure change, severance of the production tubing above a mudline, or flow rate and not requiring surface control.

2. The flow control valve of claim 1 further comprising;

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 rate of flow 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.

3. The flow control valve of claim 1 further comprising;

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.

4. The flow control valve of claim 3 further comprising;

overlying production tubing;

said severance will transfer the weight of any remaining overlying production tubing of said production tubing 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 lower flow control valve body, and whereby said flow control valve is closed, and the upward flow of hydrocarbon is stopped.

5. The flow control valve of claim 4 further comprising;

Within said borehole the opening and closing of said flow control valve can be verified without raising the valve to the surface due to fluid flow rate and/or termination by a determination of flow rate above ground.

6. The flow control valve of claim 1 further comprising;

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.

7. The flow control valve of claim 3 further comprising;

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 somewhere 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.

8. The fluid control valve of claim 7 further comprising;

wherein the upward movement of the probe accompanied by 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.

9. The fluid control valve of claim 8 further comprising;

wherein the flowing well is drilled on land and the fluid control valve is activated to close by the severance of the production tubing somewhere above or below ground level.

10. The fluid control valve in claim 9 and wherein the valve can be reopened temporarily by reversing the flow of hydrocarbon above said valve body to downward after said severed production tubing is replaced.

11. 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, and penetration of a riser or of a surrounding tubing 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.

12. The control valve of claim 11 further comprising;

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.

13. A control valve for a pipe and/or production tubing comprising;

A production tubing for fluid;

A valve located between segments of said production tubing and below a water body floor; 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.

14. The control valve of claim 13 further comprising:

said sliding piston further comprises a pawl.

15. The control valve of claim 13 further comprising;

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.

16. The control valve of claim 13 further comprising;

multiple valves which can be located between the production tubing segments.

17. A flow control valve located between segments of production tubing within a borehole below a sea floor of a flowing oil and gas well, and wherein said flow control valve can be closed automatically by the severance of an external lineal unit which supports a sliding weight unit external to said production tubing and whereby the lowering of said weight unit activates said valve to close.