CA2001387A1 - Bottom hole blowout preventer - Google Patents
Bottom hole blowout preventerInfo
- Publication number
- CA2001387A1 CA2001387A1 CA002001387A CA2001387A CA2001387A1 CA 2001387 A1 CA2001387 A1 CA 2001387A1 CA 002001387 A CA002001387 A CA 002001387A CA 2001387 A CA2001387 A CA 2001387A CA 2001387 A1 CA2001387 A1 CA 2001387A1
- Authority
- CA
- Canada
- Prior art keywords
- actuating sleeve
- blowout preventer
- ball valve
- valve
- drill string
- 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.)
- Abandoned
Links
- 239000012530 fluid Substances 0.000 abstract description 13
- 238000005553 drilling Methods 0.000 abstract description 10
- 230000000694 effects Effects 0.000 abstract description 3
- 239000003921 oil Substances 0.000 description 4
- 230000006835 compression Effects 0.000 description 2
- 238000007906 compression Methods 0.000 description 2
- 239000010720 hydraulic oil Substances 0.000 description 2
- 238000004519 manufacturing process Methods 0.000 description 2
- 238000000034 method Methods 0.000 description 2
- 230000003111 delayed effect Effects 0.000 description 1
- 238000006073 displacement reaction Methods 0.000 description 1
- 229930195733 hydrocarbon Natural products 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 230000000717 retained effect Effects 0.000 description 1
- 235000002020 sage Nutrition 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
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
- E21B21/10—Valve arrangements in drilling-fluid circulation systems
-
- 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
- E21B34/08—Valve arrangements for boreholes or wells in wells responsive to flow or pressure of the fluid obtained
-
- 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
Landscapes
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Life Sciences & Earth Sciences (AREA)
- Mining & Mineral Resources (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- Physics & Mathematics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Mechanical Engineering (AREA)
- Drilling And Boring (AREA)
- Consolidation Of Soil By Introduction Of Solidifying Substances Into Soil (AREA)
- Taps Or Cocks (AREA)
Abstract
TITLE: BOTTOM HOLE BLOWOUT PREVENTER
INVENTOR: DONALD H. LINEHAM
ABSTRACT
A ball valve type bottom hole blowout preventer operates under normal drilling conditions in a fully open position with an unrestricted bore. This operating condition is maintained by a combination of spring and mud flow pressure acting against the upper surfaces of the valve. In the event of a well kick or blowout, pressures from gas or fluid volumes acting against the lower surfaces of the valve force it into the fully closed position. A system of ports and check valves within the blowout preventer forces hydraulic fluid from one chamber to another. The metering effect of these ports determines the rate of closure of the valve, thereby allowing normal running and pulling of the drill string or tubing, without interference to pipe fill-up or drainage, from valve closure. This blowout preventer is placed in a sub that is an integral park of the drill string and can be incorporated in a string in any location.
INVENTOR: DONALD H. LINEHAM
ABSTRACT
A ball valve type bottom hole blowout preventer operates under normal drilling conditions in a fully open position with an unrestricted bore. This operating condition is maintained by a combination of spring and mud flow pressure acting against the upper surfaces of the valve. In the event of a well kick or blowout, pressures from gas or fluid volumes acting against the lower surfaces of the valve force it into the fully closed position. A system of ports and check valves within the blowout preventer forces hydraulic fluid from one chamber to another. The metering effect of these ports determines the rate of closure of the valve, thereby allowing normal running and pulling of the drill string or tubing, without interference to pipe fill-up or drainage, from valve closure. This blowout preventer is placed in a sub that is an integral park of the drill string and can be incorporated in a string in any location.
Description
3~7' FIE:LD OF INVENTION
. .
This invention relates to blowout preventers used near the bottom of a well duriny drilling of the well.
BACKGRO~ND OF THE INV~NTION
The bottom hole blowout preventer is a device used to control backflow or displacement of drilling fluids within the drill string by high pressure gas or hydrocarbons encountered while normal drilling or well servicing activities are in progressD
Downhole blowout preventers are known which include a housing engagable in a drill string and which use a ball valve pivotally mounted in the bore of the housing, where the ball valve is rotated from an open to a closed position by means of a cooperating cam sleeve, the cooperating cam sleeve being operated by a solenoid valve in response to a signal received by a downhole unit. The solenoid valve opens up a pa~sage into a chamber above a flanged end oE the cam .sleeve, and mud pressur~ entering the chamber Eorces the cam sleeve down, khus closi.ng the ball valve. Such a downhole blowout preventer is operated ~rom lnstructions ~rom the surface, and i~ described, for example, in European Patent Application No. 86304179.4, published December 17, 1986.
Surface controllable rotary valves, actuated by a sleeve, have also been used in the oil industry in production. That is, in the production of well fluids, such as oil or gas from wells, it has been the prac~ice to provide automatically closeable shut-off or safety valves which are located downhole in the well which are held open by control fluid pressure, the valves closing l3~'~
automatically when control fluid pressure is purposely reduced to allow the valves to close or when damage occurs to the control fluid system at the well head or on an offshore pla~form. ~n example of such a safet~v valve which includes a lateral opening for ease of installing the valve, is described in United Kingdom Patent No.
1,416,085.
However, there does not exist an adequate automatic downhole blowout preventer useable for drilling purposes. Autornatic rotary valves tend to close at times when closure is not desired, for example, from excess running-in rates, which interferes with pipe fill-up or drainage.
SUMMARY OF Tf~E: INVENTION
_ The inventor has provided an automatic down hole blowout preventer for a drill string, the blowout preventer comprising:
a rotary valve pivotally mountable in a drill string:
an actuatlng sleeve disposed ahout the ball valve within the drill string and having a ~low passage, the actuating sleeve being slideable in relation to the drill string in response to downhole over pressure conditions from a first position in which the ball valve is open to a second position in which the ball valve is closed;
reset means disposed against the actuating sleeve for biasing the actuating sleeve to the open position; and Z(~ 3~
means connected to the actuating sleeve to regulate the closure rate of the rotary valve.
Further summary of the invention may be found in the claims.
BRIEF DESCRIPTION OF TE~E FIGURE:S
_ .... . _ _ .
There will now be described a preferred embodiment of the invention, with reference to the figures in which like elements are indicated by like numerals, by way of example, and in which:
Figure 1 is a schematic section of a ball valve type bottom hole blowout preventer;
Figure 2 is a schematic section of a ball valve type blowout preventer depicting a vertical cross-section at 90 degrees to the section of Figure l;
Figure 3A i4 an end view of a ball valve for a bottom hole blowout preventer accordirlg to the invention: and Fiyure 3B is a side view, par~i.ally broker away, o~ the ball valve o~ Figure 3A.
I)!:SCRIPTION OF T~E PREFERRE:D EMBODIMENT
Referring to Figures 1 and 2, the bottom hole blowout preventer 10 includes a cylindrical sleeve 56 having a bore 24 for the passage of drilling fluids and suitably disposed within the drill string sub 94. The sleeve 56 has a top cap 70, and a bottom cap 28~ with ~1~3~L3E3'~
suitable threaded connections to enable thern to be threaded onto sleeve 56. In the sleeve bore 24 there is a valve ball 40 which is rotatably mounted on pivot pins 36, which allow it to rotate on a single axis only norrnal to the bore 24. The valve ball pivot pins 36 fit in suitably drilled holes 76 in collets 80 fitted to either side of the ball valve 40, and facing up to flats 78 machined on either side of the ball valve 40.
The collets 80 fit into suitably machined sockets 82 in the sleeve 56.
The ball valve 40 seats spherically between the upper seat 42 and the lower seat 30 in the bore 24 of the sleeve 56. The valve ball 40, and the seats 42 and 30 are retained within the sleeve 56 by the threaded bottom cap 28. There is a bore in the valve ball 40 extending perpendicular to the pivotal axis of the valve ball 40.
Machined into the flats 78 of valve ball 40 are slots 34 extending radially at 45 degrees from the vertical axis as shown in Figure 3~, and as shown in the broken away portion 35 in Fiyure 3B. Each slot 34 is designed to be engaged by an actuating pin 32 attached to the drill striny sub 94 and ~rav~lling within a rn~lled slot 38 in the sleeve 56. ~n identical set of slots and actuating pins (not shown) are on the other side of the valve to the side seen in Figure 2.
Fitted over the upper outsid~ diameter of sleeve 56 is a retainer 58 with a machined collar 84 on its inside diameter, made to have a close tolerance fit over-the sleeve 56 and with an O-ring seal 86 between the sleeve outside diameter and the retainer inside diameter.
The retainer 58 lirnits the vertical movement of the sleeve 56. Two drilled channels 88 connect a lower hydraulic ~q~ L3~3'7 chamber 44 to an upper hydraulic oil chamber 66 throuyh a ball check valve 90 that meters oil flow in the upper direction ~towards chamber 66) and allows free oil passage in the opposite direction. The size of the orifice in the check valve may be varied according to the desired closure rate of the ball valve 40. The two channels 88 and the chambers 44 and 66 comprise means to regulate the closure rate of the ball valve 40. They are hydraulically connected to the actuating sleeve 56 and it will be understood that "connected" as used in the claims includes hydraulic connection.
The outside diameter of the retainer 58 is threaded at 52 over the lower half of its length and has O-ring seal grooves 22 in its outside diameter above and below the threads 52. The retainer 58 threads into a sub 94 or other sub that becomes an intagral part of the drill string and retains the entire blowout preventer assembly in place within the sub.
O-ring seals 14 and molded lip seals 16 help seal the chambers 44 and 66. Opposing compression springs 50 and 62 bias the sleeve 56 to a ready position (not shown) in which the valve baLl ~0 is neither EulLy C1OE~
nor fully open. Pressure from drilling 1uid c.lurincJ
drilling forces the sl~eve S6 to the first position shown in Figure 1, in which the valve bal:L 40 is Eul:ly open.
The spring 62 is held between shoulder 60 of the retainer 58 and the shoulder 64 of the sleeve 56. The spring 50 is held between shoulder 46 of the sleeve 56 and shoulder 54 of the retainer 58. Together the springs 50 and 62 constitute reset means disposed against the actuating sleeve 56.
The manner of operation of the bottom hole blowout preventer is as follows.
l3~37 Forces resulting from a bottom hole over pressure condition act on the lower surfaces 20 of the sleeve 56 and cause it to move vertically within the drill string sub 94 and retainer 58. This upward motion causes the actuating pins 32 to move downward within the milled slots 38 of sleeve 56. The engagement of the actuating pins 32 with the machine slots 34 and the valve ball 40 causes the valve ball 40 to rotate 90 degrees around the pivot pin 36 between the open position shown in Figure 1 and the closed position shown in Figure 2.
As the sleeve 56J top cap 70 and bottom cap 28 traverse vertically up within the sub 94, a chamber 66 is created between the bottom shoulder 68 of the top cap and the top shoulder 72 of the retainer 58. At the same time, the lower hydraulic fluid chamber 44 closes, and forces hydraulic fluid through channel 88 and the check valve 90, into the top chamber 66. As these chambers 44 and 66 are sealed to ensure fluid tight integrity one from the other, and from the outer well fluids, the flow of hydraulic oil 96 from the lower chamber 44 through the metering efEect o check valve 90 inhibits the rotating closure rate o:E the valve ball 40.
In the event oE a well kick or blowout, pressure ~orc~s actlng on the lower blowout preventer surfaces ~orce valve closure at a predetermined rate, and ensure a delayed closure. As pressure i9 equaliæed across the valve, the valve is automatically reset by the springs 50 and 62 to an open position. By allowing limited flow at the surface, bottom hole pressures can readily be taken.
If the drill string is run in the hole at an excess rate, bottom hole pressures will tend to urge the valve ball 40 towards closure, but will re-open as the Z(~ 13~'ï' drill pipe ~ills. The mekering effect oE the check valve 90 avoids unwanted closure.
Drilling ahead procedures retain the valve in the fully open position with fluid pressures acting upon the upper surfaces of the sleeve 56. During normal running in procedures, the ball valve 40 will normally stay in the half-open pOSitiOIl.
In summary, in the absence of forces from pressure on either of the top or bottom surfaces of the sleeve 56, the compression springs 50 and 62 bias the ball valve 40 in a central half-open position. Forces acting on the upper surfaces of the sleeve, for example during drilling, will bring the valve to a fully open position.
Forces acting on the lower surfaces of the sleeve 56 will bring the ball valve 40 to a fully closed position. With the relaxation of either the upward or downward force, the blowout preventer will always return to the ready position.
It would be understood by persons skilled ln the art that immaterial modiEications can be made to the invention described here and these are intended to b~
covered by the scope o~ the claims that ~ollows
. .
This invention relates to blowout preventers used near the bottom of a well duriny drilling of the well.
BACKGRO~ND OF THE INV~NTION
The bottom hole blowout preventer is a device used to control backflow or displacement of drilling fluids within the drill string by high pressure gas or hydrocarbons encountered while normal drilling or well servicing activities are in progressD
Downhole blowout preventers are known which include a housing engagable in a drill string and which use a ball valve pivotally mounted in the bore of the housing, where the ball valve is rotated from an open to a closed position by means of a cooperating cam sleeve, the cooperating cam sleeve being operated by a solenoid valve in response to a signal received by a downhole unit. The solenoid valve opens up a pa~sage into a chamber above a flanged end oE the cam .sleeve, and mud pressur~ entering the chamber Eorces the cam sleeve down, khus closi.ng the ball valve. Such a downhole blowout preventer is operated ~rom lnstructions ~rom the surface, and i~ described, for example, in European Patent Application No. 86304179.4, published December 17, 1986.
Surface controllable rotary valves, actuated by a sleeve, have also been used in the oil industry in production. That is, in the production of well fluids, such as oil or gas from wells, it has been the prac~ice to provide automatically closeable shut-off or safety valves which are located downhole in the well which are held open by control fluid pressure, the valves closing l3~'~
automatically when control fluid pressure is purposely reduced to allow the valves to close or when damage occurs to the control fluid system at the well head or on an offshore pla~form. ~n example of such a safet~v valve which includes a lateral opening for ease of installing the valve, is described in United Kingdom Patent No.
1,416,085.
However, there does not exist an adequate automatic downhole blowout preventer useable for drilling purposes. Autornatic rotary valves tend to close at times when closure is not desired, for example, from excess running-in rates, which interferes with pipe fill-up or drainage.
SUMMARY OF Tf~E: INVENTION
_ The inventor has provided an automatic down hole blowout preventer for a drill string, the blowout preventer comprising:
a rotary valve pivotally mountable in a drill string:
an actuatlng sleeve disposed ahout the ball valve within the drill string and having a ~low passage, the actuating sleeve being slideable in relation to the drill string in response to downhole over pressure conditions from a first position in which the ball valve is open to a second position in which the ball valve is closed;
reset means disposed against the actuating sleeve for biasing the actuating sleeve to the open position; and Z(~ 3~
means connected to the actuating sleeve to regulate the closure rate of the rotary valve.
Further summary of the invention may be found in the claims.
BRIEF DESCRIPTION OF TE~E FIGURE:S
_ .... . _ _ .
There will now be described a preferred embodiment of the invention, with reference to the figures in which like elements are indicated by like numerals, by way of example, and in which:
Figure 1 is a schematic section of a ball valve type bottom hole blowout preventer;
Figure 2 is a schematic section of a ball valve type blowout preventer depicting a vertical cross-section at 90 degrees to the section of Figure l;
Figure 3A i4 an end view of a ball valve for a bottom hole blowout preventer accordirlg to the invention: and Fiyure 3B is a side view, par~i.ally broker away, o~ the ball valve o~ Figure 3A.
I)!:SCRIPTION OF T~E PREFERRE:D EMBODIMENT
Referring to Figures 1 and 2, the bottom hole blowout preventer 10 includes a cylindrical sleeve 56 having a bore 24 for the passage of drilling fluids and suitably disposed within the drill string sub 94. The sleeve 56 has a top cap 70, and a bottom cap 28~ with ~1~3~L3E3'~
suitable threaded connections to enable thern to be threaded onto sleeve 56. In the sleeve bore 24 there is a valve ball 40 which is rotatably mounted on pivot pins 36, which allow it to rotate on a single axis only norrnal to the bore 24. The valve ball pivot pins 36 fit in suitably drilled holes 76 in collets 80 fitted to either side of the ball valve 40, and facing up to flats 78 machined on either side of the ball valve 40.
The collets 80 fit into suitably machined sockets 82 in the sleeve 56.
The ball valve 40 seats spherically between the upper seat 42 and the lower seat 30 in the bore 24 of the sleeve 56. The valve ball 40, and the seats 42 and 30 are retained within the sleeve 56 by the threaded bottom cap 28. There is a bore in the valve ball 40 extending perpendicular to the pivotal axis of the valve ball 40.
Machined into the flats 78 of valve ball 40 are slots 34 extending radially at 45 degrees from the vertical axis as shown in Figure 3~, and as shown in the broken away portion 35 in Fiyure 3B. Each slot 34 is designed to be engaged by an actuating pin 32 attached to the drill striny sub 94 and ~rav~lling within a rn~lled slot 38 in the sleeve 56. ~n identical set of slots and actuating pins (not shown) are on the other side of the valve to the side seen in Figure 2.
Fitted over the upper outsid~ diameter of sleeve 56 is a retainer 58 with a machined collar 84 on its inside diameter, made to have a close tolerance fit over-the sleeve 56 and with an O-ring seal 86 between the sleeve outside diameter and the retainer inside diameter.
The retainer 58 lirnits the vertical movement of the sleeve 56. Two drilled channels 88 connect a lower hydraulic ~q~ L3~3'7 chamber 44 to an upper hydraulic oil chamber 66 throuyh a ball check valve 90 that meters oil flow in the upper direction ~towards chamber 66) and allows free oil passage in the opposite direction. The size of the orifice in the check valve may be varied according to the desired closure rate of the ball valve 40. The two channels 88 and the chambers 44 and 66 comprise means to regulate the closure rate of the ball valve 40. They are hydraulically connected to the actuating sleeve 56 and it will be understood that "connected" as used in the claims includes hydraulic connection.
The outside diameter of the retainer 58 is threaded at 52 over the lower half of its length and has O-ring seal grooves 22 in its outside diameter above and below the threads 52. The retainer 58 threads into a sub 94 or other sub that becomes an intagral part of the drill string and retains the entire blowout preventer assembly in place within the sub.
O-ring seals 14 and molded lip seals 16 help seal the chambers 44 and 66. Opposing compression springs 50 and 62 bias the sleeve 56 to a ready position (not shown) in which the valve baLl ~0 is neither EulLy C1OE~
nor fully open. Pressure from drilling 1uid c.lurincJ
drilling forces the sl~eve S6 to the first position shown in Figure 1, in which the valve bal:L 40 is Eul:ly open.
The spring 62 is held between shoulder 60 of the retainer 58 and the shoulder 64 of the sleeve 56. The spring 50 is held between shoulder 46 of the sleeve 56 and shoulder 54 of the retainer 58. Together the springs 50 and 62 constitute reset means disposed against the actuating sleeve 56.
The manner of operation of the bottom hole blowout preventer is as follows.
l3~37 Forces resulting from a bottom hole over pressure condition act on the lower surfaces 20 of the sleeve 56 and cause it to move vertically within the drill string sub 94 and retainer 58. This upward motion causes the actuating pins 32 to move downward within the milled slots 38 of sleeve 56. The engagement of the actuating pins 32 with the machine slots 34 and the valve ball 40 causes the valve ball 40 to rotate 90 degrees around the pivot pin 36 between the open position shown in Figure 1 and the closed position shown in Figure 2.
As the sleeve 56J top cap 70 and bottom cap 28 traverse vertically up within the sub 94, a chamber 66 is created between the bottom shoulder 68 of the top cap and the top shoulder 72 of the retainer 58. At the same time, the lower hydraulic fluid chamber 44 closes, and forces hydraulic fluid through channel 88 and the check valve 90, into the top chamber 66. As these chambers 44 and 66 are sealed to ensure fluid tight integrity one from the other, and from the outer well fluids, the flow of hydraulic oil 96 from the lower chamber 44 through the metering efEect o check valve 90 inhibits the rotating closure rate o:E the valve ball 40.
In the event oE a well kick or blowout, pressure ~orc~s actlng on the lower blowout preventer surfaces ~orce valve closure at a predetermined rate, and ensure a delayed closure. As pressure i9 equaliæed across the valve, the valve is automatically reset by the springs 50 and 62 to an open position. By allowing limited flow at the surface, bottom hole pressures can readily be taken.
If the drill string is run in the hole at an excess rate, bottom hole pressures will tend to urge the valve ball 40 towards closure, but will re-open as the Z(~ 13~'ï' drill pipe ~ills. The mekering effect oE the check valve 90 avoids unwanted closure.
Drilling ahead procedures retain the valve in the fully open position with fluid pressures acting upon the upper surfaces of the sleeve 56. During normal running in procedures, the ball valve 40 will normally stay in the half-open pOSitiOIl.
In summary, in the absence of forces from pressure on either of the top or bottom surfaces of the sleeve 56, the compression springs 50 and 62 bias the ball valve 40 in a central half-open position. Forces acting on the upper surfaces of the sleeve, for example during drilling, will bring the valve to a fully open position.
Forces acting on the lower surfaces of the sleeve 56 will bring the ball valve 40 to a fully closed position. With the relaxation of either the upward or downward force, the blowout preventer will always return to the ready position.
It would be understood by persons skilled ln the art that immaterial modiEications can be made to the invention described here and these are intended to b~
covered by the scope o~ the claims that ~ollows
Claims (4)
PROPERTY OR PRIVILEGE IS CLAIMED ARE DEFINED AS FOLLOWS:
1. A bottom hole blowout preventer for a drill string, the bottom hole blowout preventer comprising:
a ball valve pivotally mountable in the drill string;
an actuating sleeve disposable about the ball valve within the drill string and having a flow passage, the actuating sleeve being slidable in relation to the drill string in response to downhole over pressure conditions from a first position in which the ball valve is open to a second position in which the ball valve is closed;
reset means disposable against the actuating sleeve for biasing the actuating sleeve to the first position; and means connectable to the actuating sleeve to regulate the cloture rate of the ball valve.
a ball valve pivotally mountable in the drill string;
an actuating sleeve disposable about the ball valve within the drill string and having a flow passage, the actuating sleeve being slidable in relation to the drill string in response to downhole over pressure conditions from a first position in which the ball valve is open to a second position in which the ball valve is closed;
reset means disposable against the actuating sleeve for biasing the actuating sleeve to the first position; and means connectable to the actuating sleeve to regulate the cloture rate of the ball valve.
2. The bottom hole blowout preventer of claim 1 in which the means to regulate the closure rate of the ball valve includes:
a first chamber closeable by the actuating sleeve upon sliding of the actuating sleeve to the second position;
a second chamber closeable by the actuating sleeve upon sliding of the actuating sleeve to the first position;
a passageway connecting the first and second chambers and a check valve disposed in the passageway.
a first chamber closeable by the actuating sleeve upon sliding of the actuating sleeve to the second position;
a second chamber closeable by the actuating sleeve upon sliding of the actuating sleeve to the first position;
a passageway connecting the first and second chambers and a check valve disposed in the passageway.
3. A bottom hole blowout preventer for a drill string, the bottom hole blowout preventer comprising:
a ball valve pivotally mountable in the drill string;
an actuating sleeve disposed about the ball valve within the drill string and having a flow passage, the actuating sleeve being slideable in relation to the drill string in response to downhole over pressure conditions from a first position in which the ball valve is fully open to a second position in which the ball valve is fully closed, the actuating sleeve passing through a third position between the first and second positions;
reset means disposed against the actuating sleeve for biasing the actuating sleeve to the third position; and means connectable to the actuating sleeve to regulate the closure rate of the ball valve.
a ball valve pivotally mountable in the drill string;
an actuating sleeve disposed about the ball valve within the drill string and having a flow passage, the actuating sleeve being slideable in relation to the drill string in response to downhole over pressure conditions from a first position in which the ball valve is fully open to a second position in which the ball valve is fully closed, the actuating sleeve passing through a third position between the first and second positions;
reset means disposed against the actuating sleeve for biasing the actuating sleeve to the third position; and means connectable to the actuating sleeve to regulate the closure rate of the ball valve.
4. The bottom hole blowout preventer of claim 3 in which the means to regulate the closure rate of the ball valve includes.
a first chamber closeable by the actuating sleeve upon sliding of the actuating sleeve to the second position;
a second chamber closeable by the actuating sleeve upon sliding of the actuating sleeve to the first position;
a passageway connecting the first and second chambers; and a check valve disposed in the passageway.
a first chamber closeable by the actuating sleeve upon sliding of the actuating sleeve to the second position;
a second chamber closeable by the actuating sleeve upon sliding of the actuating sleeve to the first position;
a passageway connecting the first and second chambers; and a check valve disposed in the passageway.
Priority Applications (3)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA002001387A CA2001387A1 (en) | 1989-10-24 | 1989-10-24 | Bottom hole blowout preventer |
| PCT/CA1990/000368 WO1991006743A1 (en) | 1989-10-24 | 1990-10-22 | Bottom hole blowout preventer |
| GB9113255A GB2244505A (en) | 1989-10-24 | 1991-06-19 | Bottom hole blowout preventer |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA002001387A CA2001387A1 (en) | 1989-10-24 | 1989-10-24 | Bottom hole blowout preventer |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CA2001387A1 true CA2001387A1 (en) | 1991-04-24 |
Family
ID=4143388
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA002001387A Abandoned CA2001387A1 (en) | 1989-10-24 | 1989-10-24 | Bottom hole blowout preventer |
Country Status (3)
| Country | Link |
|---|---|
| CA (1) | CA2001387A1 (en) |
| GB (1) | GB2244505A (en) |
| WO (1) | WO1991006743A1 (en) |
Families Citing this family (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| WO2013079926A2 (en) | 2011-11-28 | 2013-06-06 | Churchill Drilling Tools Limited | Drill string check valve |
| CN110513070B (en) * | 2019-09-12 | 2024-02-02 | 康庆刚 | Flap type downhole oil pipe hydraulic control blowout preventer |
Family Cites Families (6)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US3126908A (en) * | 1964-03-31 | figure | ||
| US4074761A (en) * | 1971-12-27 | 1978-02-21 | Hydril Company | Drilling tool |
| US3794112A (en) * | 1972-10-02 | 1974-02-26 | Exxon Production Research Co | Surface controlled subsurface safety valve |
| US4083409A (en) * | 1977-05-02 | 1978-04-11 | Halliburton Company | Full flow bypass valve |
| CA1058477A (en) * | 1978-10-13 | 1979-07-17 | Robert G. Reay | Valve assembly for the remote control of fluid flow having an automatic time delay |
| US4660596A (en) * | 1986-08-19 | 1987-04-28 | Ashford Ronald A | Inside B.O.P. valve |
-
1989
- 1989-10-24 CA CA002001387A patent/CA2001387A1/en not_active Abandoned
-
1990
- 1990-10-22 WO PCT/CA1990/000368 patent/WO1991006743A1/en unknown
-
1991
- 1991-06-19 GB GB9113255A patent/GB2244505A/en not_active Withdrawn
Also Published As
| Publication number | Publication date |
|---|---|
| WO1991006743A1 (en) | 1991-05-16 |
| GB9113255D0 (en) | 1991-08-07 |
| GB2244505A (en) | 1991-12-04 |
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| Date | Code | Title | Description |
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