CA2425418C - Expandable lockout for a subsurface safety valve - Google Patents
Expandable lockout for a subsurface safety valve Download PDFInfo
- Publication number
- CA2425418C CA2425418C CA002425418A CA2425418A CA2425418C CA 2425418 C CA2425418 C CA 2425418C CA 002425418 A CA002425418 A CA 002425418A CA 2425418 A CA2425418 A CA 2425418A CA 2425418 C CA2425418 C CA 2425418C
- Authority
- CA
- Canada
- Prior art keywords
- sleeve
- valve
- tubular
- wellbore
- expanded
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Expired - Fee Related
Links
- 238000003780 insertion Methods 0.000 claims abstract description 3
- 230000037431 insertion Effects 0.000 claims abstract description 3
- 239000012530 fluid Substances 0.000 claims description 25
- 238000000034 method Methods 0.000 claims description 24
- 239000010432 diamond Substances 0.000 claims description 3
- 239000000463 material Substances 0.000 claims description 3
- 238000004519 manufacturing process Methods 0.000 description 7
- 239000002184 metal Substances 0.000 description 4
- 238000005516 engineering process Methods 0.000 description 2
- 230000005484 gravity Effects 0.000 description 2
- 229930195733 hydrocarbon Natural products 0.000 description 2
- 150000002430 hydrocarbons Chemical class 0.000 description 2
- 239000007787 solid Substances 0.000 description 2
- 230000002411 adverse Effects 0.000 description 1
- 210000000988 bone and bone Anatomy 0.000 description 1
- 238000004033 diameter control Methods 0.000 description 1
- 229910003460 diamond Inorganic materials 0.000 description 1
- 238000006073 displacement reaction Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 238000011065 in-situ storage Methods 0.000 description 1
- 230000001788 irregular Effects 0.000 description 1
- 230000007257 malfunction Effects 0.000 description 1
- 230000001105 regulatory effect Effects 0.000 description 1
- 230000000246 remedial effect Effects 0.000 description 1
- 238000000926 separation method Methods 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B34/00—Valve arrangements for boreholes or wells
- E21B34/06—Valve arrangements for boreholes or wells in wells
- E21B34/10—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
- E21B34/102—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole with means for locking the closing element in open or closed position
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/02—Subsoil filtering
- E21B43/10—Setting of casings, screens, liners or the like in wells
- E21B43/103—Setting of casings, screens, liners or the like in wells of expandable casings, screens, liners, or the like
- E21B43/105—Expanding tools specially adapted therefor
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B2200/00—Special features related to earth drilling for obtaining oil, gas or water
- E21B2200/04—Ball valves
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B2200/00—Special features related to earth drilling for obtaining oil, gas or water
- E21B2200/05—Flapper valves
Landscapes
- Geology (AREA)
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Mining & Mineral Resources (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- Physics & Mathematics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Safety Valves (AREA)
- Pipe Accessories (AREA)
- Preventing Unauthorised Actuation Of Valves (AREA)
- Earth Drilling (AREA)
Abstract
A locking assembly for a wellbore valve (39) is provided comprising a cylindrical expandable sleeve (10) insertable into an interior of the valve. After insertion into the valve, the body is expanded into interference with a closing mechanism (34) of the valve (39), thereby locking the valve (39) in an open position. <IMG>
Description
EXPANDABLE LOCKOUT FOR A SUBSURFACE SAFETY VALVE
The invention relates to methods a~ld apparatus for locking a wellbore valve in an open position. More particularly, the invention relates to methods and apparatus for permanently locking a subsurface safety valve in an open position through the use of expandable tubulars.
For oil and gas wells, especially those that operate offshore, redundant safety devices typically include a valve located about 500 feet (152 m) below the ocean mud line sealably connected to the production tubing string through which production fluids pass.
The valve, typically referred to as a subsurface safety valve, ensures that if the fluid conduit between the ocean floor and the platform is disrupted (by a passing vessel for instance) that the flow of production fluid from the sub-sea well head will be cut off and the ocean will not be contaminated with production fluid. If the subsurface safety valve malfunctions during its operational life, it may become necessary to permanently lock out the valve in an open position. This is particularly necessary when the safety valve has malfunctioned and closed, commonly due to a control line break or hydraulic chamber lealc. The most common type of subsurface safety valve in use in subterranean wells today is the "surface controlled subsurface safety valve", commonly and hereinafter referred to as an SCSSV. SCSSVs are required by regulatory agencies in all offshore wells worldwide. SCSSVs may also be used in land wells where the risk of wellhead damage and uncontrolled blowout of the well is high. Examples of subsurface safety valves include flapper (as shown in Figure 6), ball (as shown in Figure 7), and annulus type valves. Safety valves are typically actuated by a reciprocating flow tube or choke. In the case of a flapper type valve, the flapper pivots about a hinge to close and block the flow of fluid through the valve. In essence, SCSSVs are "normally closed"
downhole valves which are operated by pressurized hydraulic fluid in a small diameter control Iine extending from an actuator integral to the valve to a control panel on the earth's surface. Pressure in the control line exerted by the control panel holds the SCSSV in the open position, permitting fluid to pass through the valve and to the surface of the well for collection. Disruption of that pressure for any reason causes the valve to close. For example, if a control line or hydraulic seal failure occurs, loss of hydraulic pressure causes inadvertent closure of the flapper.
Valves, including SCSSVs; may be held in an open position by placing a spring metal band which expands from a contracted, run-in position to a radially enlarged locking position adjacent the flapper thereby holding the valve member open. For example;
U.S. Pat. No. 4,577,694, discloses a running tool that holds a metal band spring in the collapsed position for placement in the well. When released , the spring expands into contact with the valve member, thereby holding it in the open position. One disadvantage to a metal band spring is that hydrocarbons flowing past the metal band spring cause eddies and low pressure areas that can cause the spring to inadvertently collapse and flow upward with production. This action can permit the "permanently locked out" SCSSV to inadvertently shut, thereby stopping the flow of hydrocarbons from the well. This results in costly remedial workover operations and lost production.
Other methods of locking out the SCSSV include incoiporation of a lockout device integrally into a valve actuating mechanism. However, this solution complicates the design and adds to the total cost of the valve. An example of this type of lockout mechanism is described in U.S. Patent No. 4, 624,315. Because of the high degree of reliability and longevity of modern SCSSVs, the need arises very infrequently for locking most SCSSVs open. Furthermore, the integral lock open mechanism has an adverse effect on the reliability of the SCSSV by being continuously subjected to subsurface well conditions during normal operations. As such, it may be damaged, corroded or stuck in the retracted position, preventing a necessary lock open operation when required.
Insertable locking devices far safety valves are also hampered by the physical characteristics of wellbores. Wellbores and inside diameters thereof vary greatly from well to well. Also, the inside diameter of a wellbore may vary at different depths. The "drift" diameter of a wellbore refers to a maximum diameter of a length of bar that will pass unimpeded through the inside diameter of a wellbore. Any insertable locking device must therefore meet limitations in space inherent in a particular wellbore.
The invention relates to methods a~ld apparatus for locking a wellbore valve in an open position. More particularly, the invention relates to methods and apparatus for permanently locking a subsurface safety valve in an open position through the use of expandable tubulars.
For oil and gas wells, especially those that operate offshore, redundant safety devices typically include a valve located about 500 feet (152 m) below the ocean mud line sealably connected to the production tubing string through which production fluids pass.
The valve, typically referred to as a subsurface safety valve, ensures that if the fluid conduit between the ocean floor and the platform is disrupted (by a passing vessel for instance) that the flow of production fluid from the sub-sea well head will be cut off and the ocean will not be contaminated with production fluid. If the subsurface safety valve malfunctions during its operational life, it may become necessary to permanently lock out the valve in an open position. This is particularly necessary when the safety valve has malfunctioned and closed, commonly due to a control line break or hydraulic chamber lealc. The most common type of subsurface safety valve in use in subterranean wells today is the "surface controlled subsurface safety valve", commonly and hereinafter referred to as an SCSSV. SCSSVs are required by regulatory agencies in all offshore wells worldwide. SCSSVs may also be used in land wells where the risk of wellhead damage and uncontrolled blowout of the well is high. Examples of subsurface safety valves include flapper (as shown in Figure 6), ball (as shown in Figure 7), and annulus type valves. Safety valves are typically actuated by a reciprocating flow tube or choke. In the case of a flapper type valve, the flapper pivots about a hinge to close and block the flow of fluid through the valve. In essence, SCSSVs are "normally closed"
downhole valves which are operated by pressurized hydraulic fluid in a small diameter control Iine extending from an actuator integral to the valve to a control panel on the earth's surface. Pressure in the control line exerted by the control panel holds the SCSSV in the open position, permitting fluid to pass through the valve and to the surface of the well for collection. Disruption of that pressure for any reason causes the valve to close. For example, if a control line or hydraulic seal failure occurs, loss of hydraulic pressure causes inadvertent closure of the flapper.
Valves, including SCSSVs; may be held in an open position by placing a spring metal band which expands from a contracted, run-in position to a radially enlarged locking position adjacent the flapper thereby holding the valve member open. For example;
U.S. Pat. No. 4,577,694, discloses a running tool that holds a metal band spring in the collapsed position for placement in the well. When released , the spring expands into contact with the valve member, thereby holding it in the open position. One disadvantage to a metal band spring is that hydrocarbons flowing past the metal band spring cause eddies and low pressure areas that can cause the spring to inadvertently collapse and flow upward with production. This action can permit the "permanently locked out" SCSSV to inadvertently shut, thereby stopping the flow of hydrocarbons from the well. This results in costly remedial workover operations and lost production.
Other methods of locking out the SCSSV include incoiporation of a lockout device integrally into a valve actuating mechanism. However, this solution complicates the design and adds to the total cost of the valve. An example of this type of lockout mechanism is described in U.S. Patent No. 4, 624,315. Because of the high degree of reliability and longevity of modern SCSSVs, the need arises very infrequently for locking most SCSSVs open. Furthermore, the integral lock open mechanism has an adverse effect on the reliability of the SCSSV by being continuously subjected to subsurface well conditions during normal operations. As such, it may be damaged, corroded or stuck in the retracted position, preventing a necessary lock open operation when required.
Insertable locking devices far safety valves are also hampered by the physical characteristics of wellbores. Wellbores and inside diameters thereof vary greatly from well to well. Also, the inside diameter of a wellbore may vary at different depths. The "drift" diameter of a wellbore refers to a maximum diameter of a length of bar that will pass unimpeded through the inside diameter of a wellbore. Any insertable locking device must therefore meet limitations in space inherent in a particular wellbore.
One attempt to compensate for variable physical characteristics of a wellbore has been to utilize expandable tubular technology. Both slotted and solid tubulars can be expanded in situ to enlarge a fluid path through the tubular and also to fix a smaller tubular within the inner diameter of a larger tubular therearound. Tubulars are expanded by the use of a cone-shaped mandrel or by an expansion tool with expandable, fluid actuated members disposed on a body and run into the wellbore on a tubular string. During expansion of a tubular, the tubular walls are expanded past their elastic limit. Examples of expandable tubulars include slotted screen, joints, packers, and liners. Figures la and 1b are perspective and cross-sectional views of an exemplary expansion tool 100 and Figure lc is an exploded view thereof. The expansion tool 100 has a body 102 which is hollow and generally tubular with connectors 104 and 106 for connection to other components (not shown) of a downhole assembly. The connectors 104 and 106 are of a reduced diameter (compared to the outside diameter of the longitudinally central body part 108 of the tool 100), and together with three longitudinal flutes 110 on the central body part 108, allow the passage of fluids between the outside of the tool 100 and the interior of a tubular therearound (not shown). The central body part 108 has three lands 112 defined between the three flutes 110, each land 112 being formed with a respective recess 114 to hold a respective roller 116.
Each of the recesses 114 has parallel sides and extends radially from the radially perforated tubular core 115 of the tool 100 to the exterior of the respective land 112.
Each of the mutually identical rollers 116 is near-cylindrical and slightly barreled. Each of the rollers 116 is mounted by means of a bearing 118 at each end of the respective roller for rotation about a respective rotational axis which is parallel to the longitudinal axis of the tool 100 and radially offset therefrom at 120-degree mutual circumferential separations around the central body 108. The bearings 118 are formed as integral end members of radially slidable pistons 120, one piston 120 being slidably sealed within each radially extended recess 114. The inner end of each piston 120 (Figure la) is exposed to the pressure of fluid within the hollow core of the tool 100 by way of the radial perforations in the tubular core 115. In this manner, pressurized fluid provided from the surface of the well, via a tubular, can actuate the pistons 120 and cause them to extend outward and to contact the inner wall of a tubular to be expanded.
Therefore, a need exists to provide a method and apparatus for permanently holding open the SCSSV by a mechanism which is entirely separate from the SCSSV
mechanism, and one which would not tend to flow out of position during production operations. Additionally, a need exists to provide a lockout sleeve device utilizing expandable tubular technology which can be subsequently inserted in the well conduit only when it becomes necessary to permanently lock the SCSSV in an open position.
In one aspect of the invention, a locking assembly for a wellbore valve is provided comprising a cylindrical sleeve insertable into an interior of the valve.
After insertion into the valve, the body is expanded into interference with a closing mechanism of the valve, thereby locking the valve in an open position.
In one embodiment, a method and apparatus for locking out a safety valve in a wellbore is provided in which a tubular, or a lockout sleeve, having an outer diameter substantially equal to or less than a drift diameter of the wellbore and an expansion tool are placed in the wellbore. The safety valve is located and the lockout sleeve and expansion tool are landed adjacent the safety valve. With the valve in an open position, the lockout sleeve and the expansion tool are positioned within an inner diameter thereof. The expansion tool is energized causing extendable members therein to extend radially to contact an inner diameter of the lockout sleeve. The lockout sleeve is expanded into substantial contact with the inner diameter of the safety valve, wherein the inner diameter of the expanded lockout sleeve is substantially equal to or greater than the drift diameter of the wellbore.
In one embodiment, a method for locking out a safety valve in a wellbore is provided in which a tubular, or lockout sleeve, having an outer diameter substantially equal to or less than a drift diameter of the wellbore and an expansion tool are placed in the wellbore. The lockout sleeve and expansion tool are landed adjacent the safety valve and a flow tube disposed within the safety valve is located. With the valve in an open position, the lockout sleeve and the expansion tool are positioned within an inner diameter thereof. The expansion tool is energized causing extendable members therein to extend radially to contact an inner diameter of the lockout sleeve. The lockout sleeve is expanded into substantial contact with the inner diameter of the safety valve adjacent the flow tube, wherein the inner diameter of the expanded lockout sleeve is substantially equal to or greater than the drift diameter of the wellbore.
In one embodiment, an apparatus for locking out a safety valve in a wellbore is provided having a tubular, or lockout sleeve, with an outer diameter substantially equal to or less than a drift diameter of the wellbore. Preferably, the lockout sleeve has one or more surface features. The lockout sleeve is made of a .ductile material and the surface features may be slots, holes, ovals, diamonds, perforations, or a combination thereof.
Further, an inner diameter of the lockout sleeve is expandable to a diameter substantially equal to or greater than the drift diameter of the wellbore.
According to an aspect of the present invention there is provided a lockout sleeve for a safety valve in a wellbore, comprising an expandable tubular having an initial outer diameter substantially equal to or less than a drift diameter of the wellbore, wherein the tubular is arranged to be expanded by means of an expansion tool.
Some preferred embodiments of the invention will now be described by way of example only and with reference to the accompanying drawings, in which:
Figure la is a perspective view of an expansion tool; _ Figure 1b is a perspective end view in section thereof;
Figure lc is an exploded view of the expansion tool;.
Figure 2 is a perspective view of an embodiment of an unexpanded lockout sleeve according to the invention;
Figure 3 is a perspective view of the embodiment shown in Figure 2 in an expanded state;
Sa Figure 4 is a section view of a flapper section of a subsurface safety valve having an expansion tool and an unexpended tubular disposed therein;
Figure S is a section view of the erilbodiment shown in Figure 4, wherein the tubular is expanded;
Figure 6 is a section view of a flapper, type surface controlled subsurface safety valve, having an expanded tubular according to an embodiment of the invention disposed therein; and Figure 7 is a section view of a ball type surface controlled subsurface safety valve, having an expanded tubular according to an embodiment of the invention disposed S therein.
Figure 2 is a perspective view of an embodiment of an unexpanded lockout sleeve 10 according to the invention. The lockout sleeve 10 has a generally tubular body having an outer diameter (OD), an inner diameter (ID), and a predetermined length L1.
The lockout sleeve 10 is preferably made of a ductile material having sufficient properties to resist forces designed to yield the lockout sleeve, yet able to plastically and/or elastically deform during application of such forces to a larger diameter without breaking or rupturing. Preferably, the lockout sleeve 10 has a plurality of slots 16 formed in its wall 18. Alternatively, the lockout sleeve may be a solid tubular without any surface features or have a single longitudinal slot extending the length (L1) of the sleeve. The slots 16 are preferably arranged in a longitudinal pattern in an overlapping fashion to facilitate expansion. However, it should be understood that the slots 16 may be any appropriate shape of configuration to enable the lockout sleeve 10 to expand with the application of a radial force. Other surface features include slits, ellipses, ovals, holes, perforations, irregular shapes, such as dog bone slots, or combinations thereof.
Prior to expansion of the lockout sleeve, the outside diameter 12 of the lockout sleeve 10 is substantially equal to or less than the maximum diameter that will drift to a desired location in the wellbore. After expansion of the sleeve, the inside diameter 14 of the lockout sleeve 10 is preferably greater than or equal to the drift diameter of the wellbore.
Figure 3 is a perspective view of an embodiment of an expanded lockout sleeve according to the present invention. The expanded slots 16 form a diamond shape as the lockout sleeve 10 is expanded. In use, the expansion tool 100 is lowered into the wellbore (not shown) to a predetermined position and thereafter pressurized fluid is provided in the run-in tubular 130. In the preferred embodiment, some portion of the fluid is passed through an orif ce or some other pressure increasing device and into the expansion tool 100 where the fluid urges the rollers 116 outwards to contact the wall of the tubular, or lockout sleeve 10, therearound. The expansion tool 100 exerts forces against the wall of the lockout sleeve 10 therearound while rotating and, optionally, moving axially within the wellbore. The result is the lockout sleeve is expanded past its elastic limits along at least a portion of its outside diameter. Gravity and the weight of the components urges the expansion tool 100 downward in the wellbore even as the rollers 116 of the expander tool 100 are actuated. The expansion can also take place in a "bottom up" fashion by providing an upward force on the run-in tubular string. A
tractor (not shown) may be used in a lateral wellbore or in some other circumstance when gravity and the weight of the components are not adequate to cause the actuated expansion tool 100 to move downward along the wellbore. The run-in string of tubulars may include coiled tubing and in that instance, a mud motor may be utilized adjacent the expansion tool to provide rotational force to the tool. The structure of mud motors is well known. The mud motor can be a positive displacement Moineau-type device and includes a Iobed rotor that turns within a lobed stator in response to the flow of fluids under pressure in the coiled tubing string. The mud motor provides rotational force to rotate the expansion tool in the wellbore while the rollers are actuated against an inside surface of a tubular therearound. Additionally, the run-in string may be replaced by wire (or e-line) line providing electrical energy to an electrical motor and also having the strength to hold the weight of the appartus in the wellbore.
In this embodiment, the electrical motor runs a downhole pump providing a source of pressurized fluid to an expander tool, tractor and/or a mud motor.
Figure 4 is a section view of a flapper section 34 of a subsurface safety valve 39 having an expansion tool 100 and an unexpanded lockout sleeve 10 disposed therein.
The lockout sleeve 10 and expansion tool 100 are disposed on the end of a run-in string 130, or coil tubing, which may be used to provide hydraulic fluid to the expansion tool 100.
The lockout sleeve 10 and expansion tool 100 are shearably connected and are placed in the wellbore as an assembly. The assembly is lowered to a desired location within the safety valve 39. The flapper section 34 of the safety valve 39 rotates about a hinge pin 36 (shown in an open position). Once the assembly is located at the desired location in the wellbore, the flapper section 34 is opened by the downward force of the assembly on the flapper section 34. Fluid pressure to actuate the rollers 116 of the expansion tool 100 is provided from the surface of the well through the run-in string 130.
The rollers 116 are then actuated and extended radially outward to contact the inner diameter 14 of the lockout sleeve 10. The lockout sleeve 10 is then expanded into substantial contact with the inner diameter of the safety valve 39.
Figure 5 is a section view of the embodiment shown in Figure 4, wherein the lockout sleeve 10 is expanded into substantial contact with an inner diameter of the safety valve 39. The lockout sleeve 10 in its expanded condition is substantially greater than or equal to the smallest inner diameter of the safety valve 39 or a tubular (not shown) disposed between the safety valve 39 and the wellbore. This allows the locked out safety valve 39 to maintain its full open inner diameter and ensure that no flow capacity is lost with the addition of the lockout sleeve.
Figure 6 is a section view of a flapper type surface controlled subsurface safety valve 30, having an expanded lockout sleeve 10 disposed therein. Hydraulic fluid is provided to the safety valve 30 via a control line 34 operated by a control panel 32 on the earth's surface. A valve operator 35, such as a rod piston, moves downward in response to increasing fluid pressure in the control line 34. A flow tube 40 moves downward in tandem with the movement of the valve operator 35, thereby opening the flapper 34. A
return means 38, such as a spring, a gas charge, or a combination thereof, biases the safety valve 30 in the closed position by acting to urge the flow tube 40 upwards, opposing the force of hydraulic pressure. Lowering (or loss of) the hydraulic fluid pressure in the control line 34 serves to move the flow tube 40 upwards thereby closing the safety valve 30. The lockout sleeve 10 has been expanded into a recess 42 above the flow tube 40, thereby prohibiting an upward movement of the flow tube 40. This causes the flapper to remain in the open position, permanently locking out the safety valve 30.
Figure 7 is a section view of a ball type surface controlled subsurface safety valve, having an expanded tubular according to the invention disposed therein. A
valve operator 35, such as an annular piston, moves downward in response to increasing fluid pressure in the control line 34. A flow tube 40 moves downward in tandem with the movement of the valve operator 35, thereby rotating and opening the ball closure mechanism 44. A return means 38, such as a spring, a gas charge, or a combination thereof, biases the safety valve 31 to the closed position by acting to move the flow tube 40 upwards, opposing the force of hydraulic pressure. Reduced hydraulic fluid pressure in the control line 34 serves to move the flow tube 40 upwards thereby closing the safety valve 30. The lockout sleeve 10 has been expanded into a recess 42 above the flow tube 40, thereby preventing any upward movement of the flow tube 40. This causes the ball 44 to remain in the open position, permanently locking out the safety valve 30.
As illustrated by the forgoing, the present invention solves problems associated with wellbore valves, especially subsurface safety valves by providing an easy means to permanently opening the valves without substantially restricting the flow capacity of the valve.
Each of the recesses 114 has parallel sides and extends radially from the radially perforated tubular core 115 of the tool 100 to the exterior of the respective land 112.
Each of the mutually identical rollers 116 is near-cylindrical and slightly barreled. Each of the rollers 116 is mounted by means of a bearing 118 at each end of the respective roller for rotation about a respective rotational axis which is parallel to the longitudinal axis of the tool 100 and radially offset therefrom at 120-degree mutual circumferential separations around the central body 108. The bearings 118 are formed as integral end members of radially slidable pistons 120, one piston 120 being slidably sealed within each radially extended recess 114. The inner end of each piston 120 (Figure la) is exposed to the pressure of fluid within the hollow core of the tool 100 by way of the radial perforations in the tubular core 115. In this manner, pressurized fluid provided from the surface of the well, via a tubular, can actuate the pistons 120 and cause them to extend outward and to contact the inner wall of a tubular to be expanded.
Therefore, a need exists to provide a method and apparatus for permanently holding open the SCSSV by a mechanism which is entirely separate from the SCSSV
mechanism, and one which would not tend to flow out of position during production operations. Additionally, a need exists to provide a lockout sleeve device utilizing expandable tubular technology which can be subsequently inserted in the well conduit only when it becomes necessary to permanently lock the SCSSV in an open position.
In one aspect of the invention, a locking assembly for a wellbore valve is provided comprising a cylindrical sleeve insertable into an interior of the valve.
After insertion into the valve, the body is expanded into interference with a closing mechanism of the valve, thereby locking the valve in an open position.
In one embodiment, a method and apparatus for locking out a safety valve in a wellbore is provided in which a tubular, or a lockout sleeve, having an outer diameter substantially equal to or less than a drift diameter of the wellbore and an expansion tool are placed in the wellbore. The safety valve is located and the lockout sleeve and expansion tool are landed adjacent the safety valve. With the valve in an open position, the lockout sleeve and the expansion tool are positioned within an inner diameter thereof. The expansion tool is energized causing extendable members therein to extend radially to contact an inner diameter of the lockout sleeve. The lockout sleeve is expanded into substantial contact with the inner diameter of the safety valve, wherein the inner diameter of the expanded lockout sleeve is substantially equal to or greater than the drift diameter of the wellbore.
In one embodiment, a method for locking out a safety valve in a wellbore is provided in which a tubular, or lockout sleeve, having an outer diameter substantially equal to or less than a drift diameter of the wellbore and an expansion tool are placed in the wellbore. The lockout sleeve and expansion tool are landed adjacent the safety valve and a flow tube disposed within the safety valve is located. With the valve in an open position, the lockout sleeve and the expansion tool are positioned within an inner diameter thereof. The expansion tool is energized causing extendable members therein to extend radially to contact an inner diameter of the lockout sleeve. The lockout sleeve is expanded into substantial contact with the inner diameter of the safety valve adjacent the flow tube, wherein the inner diameter of the expanded lockout sleeve is substantially equal to or greater than the drift diameter of the wellbore.
In one embodiment, an apparatus for locking out a safety valve in a wellbore is provided having a tubular, or lockout sleeve, with an outer diameter substantially equal to or less than a drift diameter of the wellbore. Preferably, the lockout sleeve has one or more surface features. The lockout sleeve is made of a .ductile material and the surface features may be slots, holes, ovals, diamonds, perforations, or a combination thereof.
Further, an inner diameter of the lockout sleeve is expandable to a diameter substantially equal to or greater than the drift diameter of the wellbore.
According to an aspect of the present invention there is provided a lockout sleeve for a safety valve in a wellbore, comprising an expandable tubular having an initial outer diameter substantially equal to or less than a drift diameter of the wellbore, wherein the tubular is arranged to be expanded by means of an expansion tool.
Some preferred embodiments of the invention will now be described by way of example only and with reference to the accompanying drawings, in which:
Figure la is a perspective view of an expansion tool; _ Figure 1b is a perspective end view in section thereof;
Figure lc is an exploded view of the expansion tool;.
Figure 2 is a perspective view of an embodiment of an unexpanded lockout sleeve according to the invention;
Figure 3 is a perspective view of the embodiment shown in Figure 2 in an expanded state;
Sa Figure 4 is a section view of a flapper section of a subsurface safety valve having an expansion tool and an unexpended tubular disposed therein;
Figure S is a section view of the erilbodiment shown in Figure 4, wherein the tubular is expanded;
Figure 6 is a section view of a flapper, type surface controlled subsurface safety valve, having an expanded tubular according to an embodiment of the invention disposed therein; and Figure 7 is a section view of a ball type surface controlled subsurface safety valve, having an expanded tubular according to an embodiment of the invention disposed S therein.
Figure 2 is a perspective view of an embodiment of an unexpanded lockout sleeve 10 according to the invention. The lockout sleeve 10 has a generally tubular body having an outer diameter (OD), an inner diameter (ID), and a predetermined length L1.
The lockout sleeve 10 is preferably made of a ductile material having sufficient properties to resist forces designed to yield the lockout sleeve, yet able to plastically and/or elastically deform during application of such forces to a larger diameter without breaking or rupturing. Preferably, the lockout sleeve 10 has a plurality of slots 16 formed in its wall 18. Alternatively, the lockout sleeve may be a solid tubular without any surface features or have a single longitudinal slot extending the length (L1) of the sleeve. The slots 16 are preferably arranged in a longitudinal pattern in an overlapping fashion to facilitate expansion. However, it should be understood that the slots 16 may be any appropriate shape of configuration to enable the lockout sleeve 10 to expand with the application of a radial force. Other surface features include slits, ellipses, ovals, holes, perforations, irregular shapes, such as dog bone slots, or combinations thereof.
Prior to expansion of the lockout sleeve, the outside diameter 12 of the lockout sleeve 10 is substantially equal to or less than the maximum diameter that will drift to a desired location in the wellbore. After expansion of the sleeve, the inside diameter 14 of the lockout sleeve 10 is preferably greater than or equal to the drift diameter of the wellbore.
Figure 3 is a perspective view of an embodiment of an expanded lockout sleeve according to the present invention. The expanded slots 16 form a diamond shape as the lockout sleeve 10 is expanded. In use, the expansion tool 100 is lowered into the wellbore (not shown) to a predetermined position and thereafter pressurized fluid is provided in the run-in tubular 130. In the preferred embodiment, some portion of the fluid is passed through an orif ce or some other pressure increasing device and into the expansion tool 100 where the fluid urges the rollers 116 outwards to contact the wall of the tubular, or lockout sleeve 10, therearound. The expansion tool 100 exerts forces against the wall of the lockout sleeve 10 therearound while rotating and, optionally, moving axially within the wellbore. The result is the lockout sleeve is expanded past its elastic limits along at least a portion of its outside diameter. Gravity and the weight of the components urges the expansion tool 100 downward in the wellbore even as the rollers 116 of the expander tool 100 are actuated. The expansion can also take place in a "bottom up" fashion by providing an upward force on the run-in tubular string. A
tractor (not shown) may be used in a lateral wellbore or in some other circumstance when gravity and the weight of the components are not adequate to cause the actuated expansion tool 100 to move downward along the wellbore. The run-in string of tubulars may include coiled tubing and in that instance, a mud motor may be utilized adjacent the expansion tool to provide rotational force to the tool. The structure of mud motors is well known. The mud motor can be a positive displacement Moineau-type device and includes a Iobed rotor that turns within a lobed stator in response to the flow of fluids under pressure in the coiled tubing string. The mud motor provides rotational force to rotate the expansion tool in the wellbore while the rollers are actuated against an inside surface of a tubular therearound. Additionally, the run-in string may be replaced by wire (or e-line) line providing electrical energy to an electrical motor and also having the strength to hold the weight of the appartus in the wellbore.
In this embodiment, the electrical motor runs a downhole pump providing a source of pressurized fluid to an expander tool, tractor and/or a mud motor.
Figure 4 is a section view of a flapper section 34 of a subsurface safety valve 39 having an expansion tool 100 and an unexpanded lockout sleeve 10 disposed therein.
The lockout sleeve 10 and expansion tool 100 are disposed on the end of a run-in string 130, or coil tubing, which may be used to provide hydraulic fluid to the expansion tool 100.
The lockout sleeve 10 and expansion tool 100 are shearably connected and are placed in the wellbore as an assembly. The assembly is lowered to a desired location within the safety valve 39. The flapper section 34 of the safety valve 39 rotates about a hinge pin 36 (shown in an open position). Once the assembly is located at the desired location in the wellbore, the flapper section 34 is opened by the downward force of the assembly on the flapper section 34. Fluid pressure to actuate the rollers 116 of the expansion tool 100 is provided from the surface of the well through the run-in string 130.
The rollers 116 are then actuated and extended radially outward to contact the inner diameter 14 of the lockout sleeve 10. The lockout sleeve 10 is then expanded into substantial contact with the inner diameter of the safety valve 39.
Figure 5 is a section view of the embodiment shown in Figure 4, wherein the lockout sleeve 10 is expanded into substantial contact with an inner diameter of the safety valve 39. The lockout sleeve 10 in its expanded condition is substantially greater than or equal to the smallest inner diameter of the safety valve 39 or a tubular (not shown) disposed between the safety valve 39 and the wellbore. This allows the locked out safety valve 39 to maintain its full open inner diameter and ensure that no flow capacity is lost with the addition of the lockout sleeve.
Figure 6 is a section view of a flapper type surface controlled subsurface safety valve 30, having an expanded lockout sleeve 10 disposed therein. Hydraulic fluid is provided to the safety valve 30 via a control line 34 operated by a control panel 32 on the earth's surface. A valve operator 35, such as a rod piston, moves downward in response to increasing fluid pressure in the control line 34. A flow tube 40 moves downward in tandem with the movement of the valve operator 35, thereby opening the flapper 34. A
return means 38, such as a spring, a gas charge, or a combination thereof, biases the safety valve 30 in the closed position by acting to urge the flow tube 40 upwards, opposing the force of hydraulic pressure. Lowering (or loss of) the hydraulic fluid pressure in the control line 34 serves to move the flow tube 40 upwards thereby closing the safety valve 30. The lockout sleeve 10 has been expanded into a recess 42 above the flow tube 40, thereby prohibiting an upward movement of the flow tube 40. This causes the flapper to remain in the open position, permanently locking out the safety valve 30.
Figure 7 is a section view of a ball type surface controlled subsurface safety valve, having an expanded tubular according to the invention disposed therein. A
valve operator 35, such as an annular piston, moves downward in response to increasing fluid pressure in the control line 34. A flow tube 40 moves downward in tandem with the movement of the valve operator 35, thereby rotating and opening the ball closure mechanism 44. A return means 38, such as a spring, a gas charge, or a combination thereof, biases the safety valve 31 to the closed position by acting to move the flow tube 40 upwards, opposing the force of hydraulic pressure. Reduced hydraulic fluid pressure in the control line 34 serves to move the flow tube 40 upwards thereby closing the safety valve 30. The lockout sleeve 10 has been expanded into a recess 42 above the flow tube 40, thereby preventing any upward movement of the flow tube 40. This causes the ball 44 to remain in the open position, permanently locking out the safety valve 30.
As illustrated by the forgoing, the present invention solves problems associated with wellbore valves, especially subsurface safety valves by providing an easy means to permanently opening the valves without substantially restricting the flow capacity of the valve.
Claims (32)
1. A locking assembly for a wellbore valve, comprising:
a cylindrical sleeve, the sleeve being insertable into a valve body when unexpended and constructed and arranged to interfere with a closing mechanism of the valve body when expanded by means of an expansion tool.
a cylindrical sleeve, the sleeve being insertable into a valve body when unexpended and constructed and arranged to interfere with a closing mechanism of the valve body when expanded by means of an expansion tool.
2. A locking assembly as claimed in claim 1, wherein the sleeve includes walls with at least one aperture formed therein.
3. A locking assembly as claimed in claim 2, wherein the at least one aperture is slot-shaped prior to expansion and diamond-shaped after expansion of the sleeve.
4. A locking assembly as claimed in claim 2 or 3, wherein the at least one aperture facilitates the expansion of the sleeve.
5. A locking assembly as claimed in any one of claims 1 to 4, further including means for expanding the walls of the sleeve with an outward, radial force.
6. A locking assembly as claimed in any one of claims 1 to 5, wherein the expanded sleeve directly interferes with the closing mechanism.
7. A locking assembly as claimed in any one of claims 1 to 5, wherein the expanded sleeve indirectly interferes with the closing mechanism.
8. A method of locking a wellbore valve in an open position, the method comprising:
inserting a cylindrical sleeve into an interior of the valve; and expanding the sleeve within the interior by means of an expansion tool so that the expanded sleeve interferes with a closing mechanism of the valve, thereby locking the valve in an open position.
inserting a cylindrical sleeve into an interior of the valve; and expanding the sleeve within the interior by means of an expansion tool so that the expanded sleeve interferes with a closing mechanism of the valve, thereby locking the valve in an open position.
9. A method as claimed in claim 8, further including opening the valve prior to insertion of the sleeve.
10. A method as claimed in claim 8 or 9, wherein the expander tool includes outwardly extending fluid actuated members.
11. A method as claimed in claim 10, wherein the sleeve is expanded by radial pressure of the members on an interior surface of the sleeve.
12. A method as claimed in claim 10 or 11, wherein each member comprises a roller.
13. The method as claimed in any one of claims 8 to 12, wherein the sleeve is expanded into direct contact with a closing mechanism.
14. A method as claimed in any one of claims 8 to 12, wherein the sleeve is expanded into indirect contact with the closing mechanism.
15. A method as claimed in any one of claims 8 to 14, wherein the valve is a flapper valve.
16. A method as claimed in any one of claims 8 to 14, wherein the valve is a ball valve.
17. A lockout sleeve for a safety valve in a wellbore, comprising:
an expandable tubular having an initial outer diameter substantially equal to or less than a drift diameter of the wellbore, wherein the tubular is arranged to be expanded by means of an expansion tool.
an expandable tubular having an initial outer diameter substantially equal to or less than a drift diameter of the wellbore, wherein the tubular is arranged to be expanded by means of an expansion tool.
18. A lockout sleeve as claimed in claim 17, wherein the expandable tubular is arranged to be expanded by means of an expansion tool so as to lock out a safety valve.
19. A lockout sleeve as claimed in claim 17 or 18, wherein an inner diameter of the tubular is expandable to a diameter substantially equal to or greater than the drift diameter of the wellbore.
20. A lockout sleeve as claimed in claim any one of claims 17 to 19, wherein the tubular comprises a ductile material.
21. A lockout sleeve as claimed in any one of claims 17 to 20, wherein the tubular has one or more surface features.
22. A lockout sleeve as claimed in claim 21, wherein the one or more surface features are slots, slits, holes, ovals, diamonds, perforations, or a combination thereof.
23. A method for locking out a safety valve in a wellbore, comprising:
placing a tubular in the wellbore;
placing an expansion tool in the wellbore;
landing the tubular and the expansion tool adjacent the safety valve;
position the tubular and the expansion tool within an inner diameter of the safety valve;
energizing the expansion tool and causing extendable members therein to extend radially to contact an inner diameter of the tubular; and expanding the tubular into substantial contact with the inner diameter of the safety valve.
placing a tubular in the wellbore;
placing an expansion tool in the wellbore;
landing the tubular and the expansion tool adjacent the safety valve;
position the tubular and the expansion tool within an inner diameter of the safety valve;
energizing the expansion tool and causing extendable members therein to extend radially to contact an inner diameter of the tubular; and expanding the tubular into substantial contact with the inner diameter of the safety valve.
24. A method as claimed in claim 23, wherein the tubular is expanded to a diameter substantially equal to or greater than the drift diameter of the wellbore.
25. A method as claimed in claim 23 or 24, wherein the safety valve is mechanically opened prior to positioning the tubular and the expansion tool within the inner diameter of the safety valve.
26. A method as claimed in any one of claims 23 to 25, wherein the tubular and the expansion tool are placed in the wellbore on a run-in string of tubulars.
27. A method as claimed in claim 26, wherein the run-in string of tubulars is a coiled tubing.
28. A method as claimed in any one of claims 23 to 27, further comprising locating a flow tube disposed within the valve, wherein the tubular is expanded into substantial contact with the inner diameter of the safety valve adjacent the flow tube.
29. A method as claimed in any one of claims 23 to 28, wherein the tubular has an initial outer diameter substantially equal to or less than a drift diameter of the wellbore.
30. A system comprising a locking assembly according to any one of claims 1 to 7, or apparatus according to any one of claims 17 to 22, and an expansion tool for expanding the sleeve.
31. An assembly as claimed in any one of claims 1 to 7, wherein the lockout sleeve is arranged to be expanded past its elastic limit by said expansion tool.
32. A method as claimed in any one of claims 8 to 16 and 23 to 30, wherein expanding the sleeve comprises expanding the sleeve past its elastic limit by said expansion tool.
Applications Claiming Priority (5)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US23950600P | 2000-10-11 | 2000-10-11 | |
| US60/239,506 | 2000-10-11 | ||
| US09/903,753 | 2001-07-12 | ||
| US09/903,753 US20020040788A1 (en) | 2000-10-11 | 2001-07-12 | Expandable lockout apparatus for a subsurface safety valve and method of use |
| PCT/GB2001/004473 WO2002031315A1 (en) | 2000-10-11 | 2001-10-08 | Expandable lockout for a subsurface safety valve |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CA2425418A1 CA2425418A1 (en) | 2002-04-18 |
| CA2425418C true CA2425418C (en) | 2006-05-09 |
Family
ID=26932628
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA002425418A Expired - Fee Related CA2425418C (en) | 2000-10-11 | 2001-10-08 | Expandable lockout for a subsurface safety valve |
Country Status (6)
| Country | Link |
|---|---|
| US (1) | US20020040788A1 (en) |
| EP (1) | EP1325211B1 (en) |
| AU (1) | AU2001293973A1 (en) |
| CA (1) | CA2425418C (en) |
| DE (1) | DE60116349D1 (en) |
| WO (1) | WO2002031315A1 (en) |
Families Citing this family (14)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US6684958B2 (en) * | 2002-04-15 | 2004-02-03 | Baker Hughes Incorporated | Flapper lock open apparatus |
| GB0215659D0 (en) * | 2002-07-06 | 2002-08-14 | Weatherford Lamb | Formed tubulars |
| US6991040B2 (en) * | 2002-07-12 | 2006-01-31 | Weatherford/Lamb, Inc. | Method and apparatus for locking out a subsurface safety valve |
| US7137452B2 (en) * | 2002-09-25 | 2006-11-21 | Baker Hughes Incorporated | Method of disabling and locking open a safety valve with releasable flow tube for flapper lockout |
| US7195072B2 (en) * | 2003-10-14 | 2007-03-27 | Weatherford/Lamb, Inc. | Installation of downhole electrical power cable and safety valve assembly |
| US7392849B2 (en) * | 2005-03-01 | 2008-07-01 | Weatherford/Lamb, Inc. | Balance line safety valve with tubing pressure assist |
| US8225871B2 (en) * | 2006-11-09 | 2012-07-24 | Baker Hughes Incorporated | Bidirectional sealing mechanically shifted ball valve for downhole use |
| US8113286B2 (en) * | 2006-11-09 | 2012-02-14 | Baker Hughes Incorporated | Downhole barrier valve |
| US7810571B2 (en) * | 2006-11-09 | 2010-10-12 | Baker Hughes Incorporated | Downhole lubricator valve |
| US8069916B2 (en) * | 2007-01-03 | 2011-12-06 | Weatherford/Lamb, Inc. | System and methods for tubular expansion |
| US9187988B2 (en) * | 2012-05-31 | 2015-11-17 | Weatherford Technology Holdings, Llc | Compliant cone system |
| US9638006B2 (en) * | 2012-10-23 | 2017-05-02 | Tejas Research & Engineering, Llc | Safety system for wells having a cable deployed electronic submersible pump |
| US10087713B2 (en) | 2014-10-01 | 2018-10-02 | Exxonmobil Upstream Research Company | Internal subsurface safety valve for rotating downhole pumps |
| US10480307B2 (en) * | 2016-06-27 | 2019-11-19 | Baker Hughes, A Ge Company, Llc | Method for providing well safety control in a remedial electronic submersible pump (ESP) application |
Family Cites Families (6)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US4475599A (en) * | 1981-05-01 | 1984-10-09 | Baker International Corporation | Valve for subterranean wells |
| FR2536783B1 (en) * | 1982-11-29 | 1986-07-04 | Petroles Cie Francaise | SAFETY VALVE FOR OIL WELLS |
| US4577694A (en) | 1983-12-27 | 1986-03-25 | Baker Oil Tools, Inc. | Permanent lock open tool |
| US4624315A (en) | 1984-10-05 | 1986-11-25 | Otis Engineering Corporation | Subsurface safety valve with lock-open system |
| US5205355A (en) * | 1991-05-13 | 1993-04-27 | Otis Engineering Corp. | Subsurface safety valves and method and apparatus for their operation |
| US6059041A (en) * | 1997-07-17 | 2000-05-09 | Halliburton Energy Services, Inc. | Apparatus and methods for achieving lock-out of a downhole tool |
-
2001
- 2001-07-12 US US09/903,753 patent/US20020040788A1/en not_active Abandoned
- 2001-10-08 CA CA002425418A patent/CA2425418C/en not_active Expired - Fee Related
- 2001-10-08 AU AU2001293973A patent/AU2001293973A1/en not_active Abandoned
- 2001-10-08 WO PCT/GB2001/004473 patent/WO2002031315A1/en active IP Right Grant
- 2001-10-08 DE DE60116349T patent/DE60116349D1/en not_active Expired - Lifetime
- 2001-10-08 EP EP01974458A patent/EP1325211B1/en not_active Expired - Lifetime
Also Published As
| Publication number | Publication date |
|---|---|
| EP1325211B1 (en) | 2005-12-28 |
| CA2425418A1 (en) | 2002-04-18 |
| AU2001293973A1 (en) | 2002-04-22 |
| WO2002031315A1 (en) | 2002-04-18 |
| DE60116349D1 (en) | 2006-02-02 |
| EP1325211A1 (en) | 2003-07-09 |
| US20020040788A1 (en) | 2002-04-11 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CA2428479C (en) | Apparatus and methods for separating and joining tubulars in a wellbore | |
| US5228518A (en) | Downhole activated process and apparatus for centralizing pipe in a wellbore | |
| CA2153643C (en) | Sleeve valve flow control device with locator shifter | |
| EP1640558B1 (en) | Wireline retrievable safety valve with radial cutting device | |
| US7048065B2 (en) | Method and apparatus for expandable liner hanger with bypass | |
| US5197553A (en) | Drilling with casing and retrievable drill bit | |
| US10689926B2 (en) | Lost circulation zone isolating liner | |
| US6508309B1 (en) | Valve assembly | |
| CA2425418C (en) | Expandable lockout for a subsurface safety valve | |
| CA2820842C (en) | Travel joint having an infinite slot mechanism for space out operations in a wellbore | |
| US7314091B2 (en) | Cement-through, tubing retrievable safety valve | |
| AU2002214137A1 (en) | Apparatus and methods for separating and joining tubulars in a wellbore | |
| GB2428715A (en) | Creation and testing of an annular barrier | |
| AU2021201206B2 (en) | Releasable connection mechanism for use within a well | |
| CA2443140C (en) | Internal pressure indicator and locking mechanism for a downhole tool | |
| WO1998038411A2 (en) | Apparatus for use in drilling operations | |
| EP2236741B1 (en) | Capillary hanger arrangement for deploying control line in existing wellhead | |
| US20220098944A1 (en) | Hydraulic landing nipple | |
| CN112041538B (en) | Downhole valve assembly with integrated J-groove | |
| WO1995017577A1 (en) | Apparatus and method for completing a well | |
| GB2388139A (en) | Wellbore isolation valve |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| EEER | Examination request | ||
| MKLA | Lapsed |