CA2812692C - Improved blowout preventer with port for entry between casing and tubing string and/or port for entry into tubing string - Google Patents
Improved blowout preventer with port for entry between casing and tubing string and/or port for entry into tubing string Download PDFInfo
- Publication number
- CA2812692C CA2812692C CA2812692A CA2812692A CA2812692C CA 2812692 C CA2812692 C CA 2812692C CA 2812692 A CA2812692 A CA 2812692A CA 2812692 A CA2812692 A CA 2812692A CA 2812692 C CA2812692 C CA 2812692C
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- Prior art keywords
- tubing string
- blowout preventer
- casing
- tubing
- elongate member
- Prior art date
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- Expired - Fee Related
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- 239000012530 fluid Substances 0.000 claims abstract description 17
- 230000015572 biosynthetic process Effects 0.000 claims abstract description 5
- 239000004576 sand Substances 0.000 description 6
- 239000003129 oil well Substances 0.000 description 5
- 238000000034 method Methods 0.000 description 4
- 239000000523 sample Substances 0.000 description 3
- KJLPSBMDOIVXSN-UHFFFAOYSA-N 4-[4-[2-[4-(3,4-dicarboxyphenoxy)phenyl]propan-2-yl]phenoxy]phthalic acid Chemical compound C=1C=C(OC=2C=C(C(C(O)=O)=CC=2)C(O)=O)C=CC=1C(C)(C)C(C=C1)=CC=C1OC1=CC=C(C(O)=O)C(C(O)=O)=C1 KJLPSBMDOIVXSN-UHFFFAOYSA-N 0.000 description 2
- 230000002250 progressing effect Effects 0.000 description 2
- 238000005086 pumping Methods 0.000 description 2
- 241000282472 Canis lupus familiaris Species 0.000 description 1
- 229910000831 Steel Inorganic materials 0.000 description 1
- 230000007812 deficiency Effects 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 229920001971 elastomer Polymers 0.000 description 1
- 239000000806 elastomer Substances 0.000 description 1
- 238000002347 injection Methods 0.000 description 1
- 239000007924 injection Substances 0.000 description 1
- 238000003780 insertion Methods 0.000 description 1
- 230000037431 insertion Effects 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
- 239000000314 lubricant Substances 0.000 description 1
- 238000007789 sealing Methods 0.000 description 1
- 239000010959 steel Substances 0.000 description 1
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 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
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/02—Surface sealing or packing
- E21B33/03—Well heads; Setting-up thereof
- E21B33/06—Blow-out preventers, i.e. apparatus closing around a drill pipe, e.g. annular blow-out preventers
- E21B33/061—Ram-type blow-out preventers, e.g. with pivoting rams
-
- 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
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/02—Surface sealing or packing
- E21B33/03—Well heads; Setting-up thereof
- E21B33/068—Well heads; Setting-up thereof having provision for introducing objects or fluids into, or removing objects from, wells
-
- 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
- E21B34/02—Valve arrangements for boreholes or wells in well heads
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- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Earth Drilling (AREA)
Abstract
An improved blowout preventer for a well having a casing extending into an underground formation. The blowout preventer has a pair of opposed ram members received within a pair transverse bores within the main housing. The ram members move between an engaged position wherein they engage the pump rod and each other when a pump rod is received through the longitudinal bore in the housing, and a disengaged position where they are retracted from engaging either the pump rod or each other. There are one or more side entry ports within the main housing which permit a fluid or elongate member to be inserted into the casing.
Description
TITLE
Improved Blowout Preventer With Port For Entry Between Casing And Tubing String And/Or Port For Entry Into Tubing String FIELD OF THE INVENTION
This invention relates generally to oil well production equipment, and more particularly to a new and useful blowout preventer for use on an oil or other well -driven into an underground formation.
BACKGROUND OF THE INVENTION
A blowout preventer (BOP) is a device typically used to seal off or close off an oil pumping well. It acts somewhat similar to a valve and generally has apposing rams that move together to seal off well pressure from within the well to atmosphere.
The majority of all BOP's on production wells will have a polish rod extending through their center during use. The polish rod may have a reciprocation motion when used in a pump jack application or a rotating motion when used in a PCP
(progressing cavity pump) application. The ram body is typically made of steel and contains an elastomer seal that squeezes against the polish rod and also squeezes against the inside of the BOP to seal pressure in the well. With the rams in their open position oil is allowed to flow up through the BOP and exit through a flow line.
With the rams closed the well is shut off and flow is contained.
A typical oil well is made up of casing which runs the length of the well and has a casing bowl attached to it above the ground. The exterior of the casing is cemented to the drilled oil well hole to provide a tight seal preventing any well pressure from leaking to the surface. Inside the casing is tubing that runs the length of the oil well down to the pump or motor at the bottom of the well. The top of the tubing is attached to a tubing hanger which seals the tubing from well pressure and is usually found in the tubing head just below the BOP. When the well is pumping either by a pump jack or a PCP the oil flows up through the tubing and in to the BOP, where it continues its way through flow lines to a tank, reservoir or pipeline.
A common problem with the production of oil is sand. Sand released out of the oil settles and often causes pumps and motors to become plugged, or surrounds the outside of pumps and motors causing a reduction in oil production and/or resulting in the pump becoming locked in place. To release the sand from the well a procedure called a "flush-by" is performed where a hose or coiled tubing is run down through the tubing, or between the tubing and the casing, to allow high pressure liquids (such as water) to flush the sand out. In the case of well having a PCP drive, for the hose or coil tubing to gain access to the inside of the tubing string the drive head must first be removed and the polish rod and connected sucker rods lifted to remove the rotor from the stator to allow the coiled tubing to pass through the stator and permit access to the well at a point below the pump.
This is time consuming as the drive head, stuffing box and clamps must be removed, requiring in most the use of cases cranes, boom trucks or other lifting devices. To flush the sand from between the tubing and the casing, or from inside the tubing string, the drive head, clamps, stuffing boxes etc (le the top of the wellhead) must be removed. The BOP must then typically be removed to gain access to the tubing hanger located in the casing bowl. The hanger must be lifted out of the casing bowl and high enough to allow the coil tubing to be inserted into the annulus between the tubing and the casing. The coil tubing can then be inserted the length of the tubing string down to the pump or motor. Some wells also collect high amounts of sand beyond the pump and motor so coiled tubing may have to be inserted further down the well. The hanger and tubing is much heavier than the polish rod, sucker rod and rotor, accordingly larger lifting equipment is often needed at the well site when it is necessary to lift the tubing.
Improved Blowout Preventer With Port For Entry Between Casing And Tubing String And/Or Port For Entry Into Tubing String FIELD OF THE INVENTION
This invention relates generally to oil well production equipment, and more particularly to a new and useful blowout preventer for use on an oil or other well -driven into an underground formation.
BACKGROUND OF THE INVENTION
A blowout preventer (BOP) is a device typically used to seal off or close off an oil pumping well. It acts somewhat similar to a valve and generally has apposing rams that move together to seal off well pressure from within the well to atmosphere.
The majority of all BOP's on production wells will have a polish rod extending through their center during use. The polish rod may have a reciprocation motion when used in a pump jack application or a rotating motion when used in a PCP
(progressing cavity pump) application. The ram body is typically made of steel and contains an elastomer seal that squeezes against the polish rod and also squeezes against the inside of the BOP to seal pressure in the well. With the rams in their open position oil is allowed to flow up through the BOP and exit through a flow line.
With the rams closed the well is shut off and flow is contained.
A typical oil well is made up of casing which runs the length of the well and has a casing bowl attached to it above the ground. The exterior of the casing is cemented to the drilled oil well hole to provide a tight seal preventing any well pressure from leaking to the surface. Inside the casing is tubing that runs the length of the oil well down to the pump or motor at the bottom of the well. The top of the tubing is attached to a tubing hanger which seals the tubing from well pressure and is usually found in the tubing head just below the BOP. When the well is pumping either by a pump jack or a PCP the oil flows up through the tubing and in to the BOP, where it continues its way through flow lines to a tank, reservoir or pipeline.
A common problem with the production of oil is sand. Sand released out of the oil settles and often causes pumps and motors to become plugged, or surrounds the outside of pumps and motors causing a reduction in oil production and/or resulting in the pump becoming locked in place. To release the sand from the well a procedure called a "flush-by" is performed where a hose or coiled tubing is run down through the tubing, or between the tubing and the casing, to allow high pressure liquids (such as water) to flush the sand out. In the case of well having a PCP drive, for the hose or coil tubing to gain access to the inside of the tubing string the drive head must first be removed and the polish rod and connected sucker rods lifted to remove the rotor from the stator to allow the coiled tubing to pass through the stator and permit access to the well at a point below the pump.
This is time consuming as the drive head, stuffing box and clamps must be removed, requiring in most the use of cases cranes, boom trucks or other lifting devices. To flush the sand from between the tubing and the casing, or from inside the tubing string, the drive head, clamps, stuffing boxes etc (le the top of the wellhead) must be removed. The BOP must then typically be removed to gain access to the tubing hanger located in the casing bowl. The hanger must be lifted out of the casing bowl and high enough to allow the coil tubing to be inserted into the annulus between the tubing and the casing. The coil tubing can then be inserted the length of the tubing string down to the pump or motor. Some wells also collect high amounts of sand beyond the pump and motor so coiled tubing may have to be inserted further down the well. The hanger and tubing is much heavier than the polish rod, sucker rod and rotor, accordingly larger lifting equipment is often needed at the well site when it is necessary to lift the tubing.
2 Flush by's are a very important procedure for maximizing oil production, but in many cases they can be time consuming, resulting in increased costs from the perspective of labour, necessary equipment to perform the procedure and down time for the well. The improved BOP of the present invention is designed to save time, and as a result costs, when performing a flush by, and also helps to keep the well head manageable in terms of size, and the number of well head components.
SUMMARY OF THE INVENTION
The invention therefore, in one of its aspects, provides an improved blowout preventer that addresses some of the deficiencies of current blowout preventers and that enhances the ability to insert fluid or an elongate member into a well.
In one aspect the invention concerns an improved blowout preventer for a well having a casing extending into an underground formation, said improved blowout preventer comprising a main housing having a generally longitudinally oriented bore therethrough for releasably receiving a pump rod therein; a pair of opposed ram members received within a pair of generally transverse bores within said main housing, said ram members moveable between an engaged position wherein they sealingly engage the pump rod and each other when a pump rod is received through said longitudinal bore, and a disengaged position wherein they are retracted from engaging either the pump rod or each other; and, one or more side entry ports within said main housing, said side entry ports permitting a fluid or elongate member to be inserted into the casing.
BRIEF DESCRIPTION OF THE DRAWINGS
For a better understanding of the present invention, and to show more clearly how it may be carried into effect, reference will now be made, by way of example, to the accompanying drawings which show the preferred embodiments of the present invention in which:
SUMMARY OF THE INVENTION
The invention therefore, in one of its aspects, provides an improved blowout preventer that addresses some of the deficiencies of current blowout preventers and that enhances the ability to insert fluid or an elongate member into a well.
In one aspect the invention concerns an improved blowout preventer for a well having a casing extending into an underground formation, said improved blowout preventer comprising a main housing having a generally longitudinally oriented bore therethrough for releasably receiving a pump rod therein; a pair of opposed ram members received within a pair of generally transverse bores within said main housing, said ram members moveable between an engaged position wherein they sealingly engage the pump rod and each other when a pump rod is received through said longitudinal bore, and a disengaged position wherein they are retracted from engaging either the pump rod or each other; and, one or more side entry ports within said main housing, said side entry ports permitting a fluid or elongate member to be inserted into the casing.
BRIEF DESCRIPTION OF THE DRAWINGS
For a better understanding of the present invention, and to show more clearly how it may be carried into effect, reference will now be made, by way of example, to the accompanying drawings which show the preferred embodiments of the present invention in which:
3 Figure 1 is a vertical cross-sectional view through a typical oil well that employs a progressing cavity pump and having attached to the well head an improved blowout preventer generally constructed in accordance with one of the preferred embodiments of the present invention;
Figure 2 is a side elevational view of the improved blowout preventer shown in Figure 1, together with some of the related well head components;
Figure 3 is a cross-sectional view taken along the line 3-3 of Figure 2;
Figure 4 is a side elevational view of an alternate embodiment of the improved blowout preventer shown in Figure 1, together with some of the related well head components;
Figure 5 is a cross-sectional view taken along the line 5-5 of Figure 4;
Figure 6 is a side elevational view of an alternate embodiment of the improved blowout preventer shown in Figure 1, together with some of the related well head components;
Figure 7 is a cross-sectional view taken along the line 7-7 of Figure 6;
Figure 8 is side elevational view of one of the preferred embodiments of the improved blowout preventer constructed in accordance with the present invention;
Figure 9 is a cross-sectional view taken along the line 9-9 of Figure 8; and, Figure 10 is a cross-sectional view taken along the line 10-10 of Figure 8.
Figure 2 is a side elevational view of the improved blowout preventer shown in Figure 1, together with some of the related well head components;
Figure 3 is a cross-sectional view taken along the line 3-3 of Figure 2;
Figure 4 is a side elevational view of an alternate embodiment of the improved blowout preventer shown in Figure 1, together with some of the related well head components;
Figure 5 is a cross-sectional view taken along the line 5-5 of Figure 4;
Figure 6 is a side elevational view of an alternate embodiment of the improved blowout preventer shown in Figure 1, together with some of the related well head components;
Figure 7 is a cross-sectional view taken along the line 7-7 of Figure 6;
Figure 8 is side elevational view of one of the preferred embodiments of the improved blowout preventer constructed in accordance with the present invention;
Figure 9 is a cross-sectional view taken along the line 9-9 of Figure 8; and, Figure 10 is a cross-sectional view taken along the line 10-10 of Figure 8.
4 DESCRIPTION OF THE PREFERRED EMBODIMENT
The present invention maybe embodied in a number of different forms. However, the specification and drawings describe and disclose only some of the specific forms of the invention and are not intended to limit the scope of the invention as defined in the claims that follow herein.
The new improved BOP design combines several wellhead servicing procedures that are done on various wellhead components to be completed in the BOP 26. In the past drive heads, stuffing boxes, polish rod clamps and BOP's 26 had to be unbolted and removed to gain access to the tubing string 18 and sucker rods, rotors, stators, pumps 32, etc. Such items are typically the main components that have to be replaced over time or that get sanded in and need to be flushed out by a flush-by unit. The improved BOP 26 of the present invention will allow for the servicing and the operation of the wellhead to be contained in one unit. The BOP 26 has a removable stuffing box built into a rod hanger 12. The rod hanger 12 is preferably situated internally in the top of the BOP 26 with the entrance to the tubing string 18 being through the rod hanger 12.
With the use of seals and lock down screws 14 the rod hanger 12 is sealed and secured to the BOP 26. The top of the rod hanger 12 receives the shaft of a PCP drive head or some form of rotating input shaft that transmits rotating torque through the rod hanger 12 to an end of the rod hanger shaft which is connected to the sucker rods for driving a PCP rotor. The BOP rams 34 are able to clamp on the hanger shaft and seal off all well pressure. If desired, a second set of blind rams could be positioned above the sealing rams 34 that could also seal off the well pressure if there were no rods in the center of the BOP 26. The BOP 26 could also have more than two sets of rams 34. In addition, the rod input shaft 30 may be connected to a secondary shaft below it, the secondary shaft having an area for the rams 34 to clamp the shaft securely with teeth, spline etc. This shaft would be useful when lifting the rod hanger 12 out of the BOP 26 where the rams 34 would clamp on the secondary rod and secure it to disconnect the rod hanger shaft. The rod hanger shaft could also be extended and be supported by the rams 34 and sealed and clamped from preventing rotation.
In prior PCP wellheads, drive heads typically have had a rotating polish rod through the center and extending out of the top where a clamp would transmit the rotational torque from the motor to the rotor. This structure can present a hazard to workers. With the improved BOP 26 of the present invention the drive motor 10 only needs to have a shaft engagement in the rod hanger 12, leaving no rotating members sticking out of the top of the drive motor 10.
In certain applications the hanger may be hollow and may include a plug for closing off its hollow interior. The plug may be a valve or other mechanism for closing the hollow bore of the rod hanger 12. Alternately, there could be more than one plug, or a combination of plugs and valves.
The new BOP 26 also receives the tubing hanger 16 below the rams 34. The tubing hanger 16 is sealed and held in place with lock down screws 14. In prior wells the tubing hanger 16 would typically be placed in a casing bowl or tubing head 28.
Having the hanger 16 placed in the BOP 26 saves time, since in prior wells the BOP 26 would have to be removed to gain access to the tubing hanger 16.
The BOP 26 of the present invention has an entry port 24 that allows fluid, coiled tubing 22, a cable, probe or other elongate member to enter the BOP 26 on the side or face with an angle of entry angle that in most cases would typically be no greater than 30 degrees. In some cases (for example where the entry port 24 is used for inserting probes or sensors) the angle of entry could be greater. When inserted through the entry port 24 the coil tubing 22 (fluid or other elongate member) will be allowed to travel down the well between the casing string 20 and the tubing string 18, and/or down the tubing. It will be appreciated from a thorough understanding of the invention, and from a review of the attached drawings, that depending on the particular needs and depending on the nature of a particular well, the BOP 26 can be constructed with one or more entry ports 24. Those entry ports 24 may also be at different locations about the main body of the BOP 26, may have different angles of inclination and may terminate at either the bottom surface of the BOP 26 or within the longitudinal bore through the BOP main housing. Hence, depending upon the relative positioning of the BOP 26 and the tubing string hanger 16, and depending on the nature and point of termination of the entry ports 24, the entry ports 24 may allow direct access to the interior of the tubing string 18 (for example, see FIG.
The present invention maybe embodied in a number of different forms. However, the specification and drawings describe and disclose only some of the specific forms of the invention and are not intended to limit the scope of the invention as defined in the claims that follow herein.
The new improved BOP design combines several wellhead servicing procedures that are done on various wellhead components to be completed in the BOP 26. In the past drive heads, stuffing boxes, polish rod clamps and BOP's 26 had to be unbolted and removed to gain access to the tubing string 18 and sucker rods, rotors, stators, pumps 32, etc. Such items are typically the main components that have to be replaced over time or that get sanded in and need to be flushed out by a flush-by unit. The improved BOP 26 of the present invention will allow for the servicing and the operation of the wellhead to be contained in one unit. The BOP 26 has a removable stuffing box built into a rod hanger 12. The rod hanger 12 is preferably situated internally in the top of the BOP 26 with the entrance to the tubing string 18 being through the rod hanger 12.
With the use of seals and lock down screws 14 the rod hanger 12 is sealed and secured to the BOP 26. The top of the rod hanger 12 receives the shaft of a PCP drive head or some form of rotating input shaft that transmits rotating torque through the rod hanger 12 to an end of the rod hanger shaft which is connected to the sucker rods for driving a PCP rotor. The BOP rams 34 are able to clamp on the hanger shaft and seal off all well pressure. If desired, a second set of blind rams could be positioned above the sealing rams 34 that could also seal off the well pressure if there were no rods in the center of the BOP 26. The BOP 26 could also have more than two sets of rams 34. In addition, the rod input shaft 30 may be connected to a secondary shaft below it, the secondary shaft having an area for the rams 34 to clamp the shaft securely with teeth, spline etc. This shaft would be useful when lifting the rod hanger 12 out of the BOP 26 where the rams 34 would clamp on the secondary rod and secure it to disconnect the rod hanger shaft. The rod hanger shaft could also be extended and be supported by the rams 34 and sealed and clamped from preventing rotation.
In prior PCP wellheads, drive heads typically have had a rotating polish rod through the center and extending out of the top where a clamp would transmit the rotational torque from the motor to the rotor. This structure can present a hazard to workers. With the improved BOP 26 of the present invention the drive motor 10 only needs to have a shaft engagement in the rod hanger 12, leaving no rotating members sticking out of the top of the drive motor 10.
In certain applications the hanger may be hollow and may include a plug for closing off its hollow interior. The plug may be a valve or other mechanism for closing the hollow bore of the rod hanger 12. Alternately, there could be more than one plug, or a combination of plugs and valves.
The new BOP 26 also receives the tubing hanger 16 below the rams 34. The tubing hanger 16 is sealed and held in place with lock down screws 14. In prior wells the tubing hanger 16 would typically be placed in a casing bowl or tubing head 28.
Having the hanger 16 placed in the BOP 26 saves time, since in prior wells the BOP 26 would have to be removed to gain access to the tubing hanger 16.
The BOP 26 of the present invention has an entry port 24 that allows fluid, coiled tubing 22, a cable, probe or other elongate member to enter the BOP 26 on the side or face with an angle of entry angle that in most cases would typically be no greater than 30 degrees. In some cases (for example where the entry port 24 is used for inserting probes or sensors) the angle of entry could be greater. When inserted through the entry port 24 the coil tubing 22 (fluid or other elongate member) will be allowed to travel down the well between the casing string 20 and the tubing string 18, and/or down the tubing. It will be appreciated from a thorough understanding of the invention, and from a review of the attached drawings, that depending on the particular needs and depending on the nature of a particular well, the BOP 26 can be constructed with one or more entry ports 24. Those entry ports 24 may also be at different locations about the main body of the BOP 26, may have different angles of inclination and may terminate at either the bottom surface of the BOP 26 or within the longitudinal bore through the BOP main housing. Hence, depending upon the relative positioning of the BOP 26 and the tubing string hanger 16, and depending on the nature and point of termination of the entry ports 24, the entry ports 24 may allow direct access to the interior of the tubing string 18 (for example, see FIG.
5), may allow direct access to the annulus between the casing string 20 and the tubing string 18 (for example, see FIG. 3) or may allow direct access to both the interior of the tubing string 18 and the annulus between the casing string 20 and the tubing string 18 (for example, see FIG. 7).
While the entry port 24 would commonly be positioned above the rams 34, it could also be located below the rams 34 and/or below the rams 34 and tubing hanger 16.
The entry port 24 saves time as the hanger does not have to be removed or lifted from the BOP 26 to perform a flUsh by operation. This improved BOP 26 also permits for a reduction in operator error at a well site by reducing the need for undoing and redoing connections. Undoing and redoing connections also often requires the replacement of gaskets and can be time consuming. The improved BOP 26 also helps to reduce wellhead height which has advantages in terms of strain on wellhead equipment in non-vertical wells.
Referring to FIG. 3 and FIG. 5, an entry for pressurized lubricant fluid 36, casing vents 38, and side entry 40 are shown. As shown, the drive rod or tubing has an engagement portion 42 with locking teeth or dogs that can engage and rest on the BOP rams. Referring to FIG. 7, a kill line side port 44 may be provided below BOP
rams 34. Referring to FIG. 9, side entry port 22 may have an offset 46 from the center such that the pipe is aligned with the outside of the housing.
It is to be understood that what has been described are the preferred embodiments of the invention and that it may be possible to make variations to these embodiments while staying within the broad scope of the invention. Some of these variations have been discussed while others will be readily apparent to those skilled in the art. For example, while the attached Figures show the insertion of coiled tubing 22 through the entry ports 24 in the BOP 26, it will be appreciated that those ports could be used for direct fluid injection or to receive hoses, tubing, cables, wires, probes, sensors or a wide variety of other elongate or other members with which there may be a desire to access the interior of the tubing string 18 and/or the annulus between the tubing string 18 and the casing 20.
While the entry port 24 would commonly be positioned above the rams 34, it could also be located below the rams 34 and/or below the rams 34 and tubing hanger 16.
The entry port 24 saves time as the hanger does not have to be removed or lifted from the BOP 26 to perform a flUsh by operation. This improved BOP 26 also permits for a reduction in operator error at a well site by reducing the need for undoing and redoing connections. Undoing and redoing connections also often requires the replacement of gaskets and can be time consuming. The improved BOP 26 also helps to reduce wellhead height which has advantages in terms of strain on wellhead equipment in non-vertical wells.
Referring to FIG. 3 and FIG. 5, an entry for pressurized lubricant fluid 36, casing vents 38, and side entry 40 are shown. As shown, the drive rod or tubing has an engagement portion 42 with locking teeth or dogs that can engage and rest on the BOP rams. Referring to FIG. 7, a kill line side port 44 may be provided below BOP
rams 34. Referring to FIG. 9, side entry port 22 may have an offset 46 from the center such that the pipe is aligned with the outside of the housing.
It is to be understood that what has been described are the preferred embodiments of the invention and that it may be possible to make variations to these embodiments while staying within the broad scope of the invention. Some of these variations have been discussed while others will be readily apparent to those skilled in the art. For example, while the attached Figures show the insertion of coiled tubing 22 through the entry ports 24 in the BOP 26, it will be appreciated that those ports could be used for direct fluid injection or to receive hoses, tubing, cables, wires, probes, sensors or a wide variety of other elongate or other members with which there may be a desire to access the interior of the tubing string 18 and/or the annulus between the tubing string 18 and the casing 20.
Claims (13)
1 An improved blowout preventer for a well having a casing extending into an underground formation, the improved blowout preventer comprising a main housing having a generally longitudinally oriented bore therethrough for releasably receiving a pump rod therein;
a pair of opposed ram members received within a pair of generally transverse bores within the main housing, the ram members moveable between an engaged position wherein they sealingly engage the pump rod and each other when a pump rod is received through the longitudinal bore, and a disengaged position wherein they are retracted from engaging either the pump rod or each other;
one or more side entry ports within the main housing, the side entry ports permitting a fluid or elongate member to be inserted into the casing; and an attachment for a tubing string within the main housing.
a pair of opposed ram members received within a pair of generally transverse bores within the main housing, the ram members moveable between an engaged position wherein they sealingly engage the pump rod and each other when a pump rod is received through the longitudinal bore, and a disengaged position wherein they are retracted from engaging either the pump rod or each other;
one or more side entry ports within the main housing, the side entry ports permitting a fluid or elongate member to be inserted into the casing; and an attachment for a tubing string within the main housing.
2. The improved blowout preventer as claimed in claim 1, wherein the attachment for a tubing string is a tubing hanger.
3. The improved blowout preventer as claimed in claim 1 or 2 wherein the casing includes a tubing string supported by the attachment for the tubing string, the fluid or elongate member being inserted into the annulus between the casing and the tubing string.
4. The improved blowout preventer as claimed in claim 1 or 2 wherein the casing includes a tubing string supported by the attachment for the tubing string, the fluid or elongate member being inserted into the hollow interior of the tubing string.
5. The improved blowout preventer as claimed in any one of claims 1 - 4, wherein the casing includes a tubing string extending at least partially therethrough, the blowout preventer including two or more side entry ports within the main housing, the side entry ports permitting fluid or an elongate member to be inserted into the annulus between the casing and the tubing string, and fluid or an elongate member to be inserted into the tubing string.
6. The improved blowout preventer as claimed in any one of claims 1 - 5 wherein the elongate member is a hose, cable, tube or coiled tubing.
7. An improved blowout preventer for a well having a casing extending into an underground formation, the improved blowout preventer comprising.
a main housing having a generally longitudinally oriented bore therethrough for releasably receiving a pump rod therein;
a pair of opposed ram members received within a pair of generally transverse bores within the main housing, the ram members moveable between an engaged position wherein they sealingly engage the pump rod and each other when a pump rod is received through the longitudinal bore, and a disengaged position wherein they are retracted from engaging either the pump rod or each other; and an attachment for a tubing hanger within the main housing.
a main housing having a generally longitudinally oriented bore therethrough for releasably receiving a pump rod therein;
a pair of opposed ram members received within a pair of generally transverse bores within the main housing, the ram members moveable between an engaged position wherein they sealingly engage the pump rod and each other when a pump rod is received through the longitudinal bore, and a disengaged position wherein they are retracted from engaging either the pump rod or each other; and an attachment for a tubing hanger within the main housing.
8 The improved blowout preventer as claimed in claim 7, further comprising one or more side entry ports within the main housing, the side entry ports permitting a fluid or elongate member to be inserted into the casing
9 The improved blowout preventer as claimed in claim 7 or 8, wherein the attachment for a tubing string is a tubing hanger
10. The improved blowout preventer as claimed in any one of claims 8 or 9, wherein the casing includes a tubing string supported by the attachment for the tubing string, the fluid or elongate member being inserted into the annulus between the casing and the tubing string.
11. The improved blowout preventer as claimed in any one of claims 7 - 10, wherein the casing includes a tubing string supported by the attachment for the tubing string, the fluid or elongate member being inserted into the hollow interior of the tubing string.
12. The improved blowout preventer as claimed in any one of claims 8 - 11, wherein the casing includes a tubing string extending at least partially therethrough, the blowout preventer including two or more side entry ports within the main housing, the side entry ports permitting fluid or an elongate member to be inserted into the annulus between the casing and the tubing string, and fluid or an elongate member to be inserted into the tubing string.
13.The improved blowout preventer as claimed in any one of claims 8 - 12 wherein the elongate member is a hose, cable, tube or coiled tubing.
Applications Claiming Priority (3)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US38361310P | 2010-09-16 | 2010-09-16 | |
| US61/383,613 | 2010-09-16 | ||
| PCT/CA2011/001048 WO2012034227A1 (en) | 2010-09-16 | 2011-09-16 | Improved blowout preventer with port for entry between casing and tubing string and/or port for entry into tubing string |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CA2812692A1 CA2812692A1 (en) | 2012-03-22 |
| CA2812692C true CA2812692C (en) | 2018-03-13 |
Family
ID=45830900
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA2812692A Expired - Fee Related CA2812692C (en) | 2010-09-16 | 2011-09-16 | Improved blowout preventer with port for entry between casing and tubing string and/or port for entry into tubing string |
Country Status (4)
| Country | Link |
|---|---|
| US (1) | US20130181147A1 (en) |
| AU (1) | AU2011301740A1 (en) |
| CA (1) | CA2812692C (en) |
| WO (1) | WO2012034227A1 (en) |
Families Citing this family (6)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| GB2470158B8 (en) * | 2008-02-11 | 2013-04-03 | Cameron Int Corp | Apparatus and method for angled routing a cable ina wellhead assembly |
| CN102767345A (en) * | 2012-07-25 | 2012-11-07 | 胜利油田东胜精攻石油开发集团股份有限公司 | Multifunctional sucker rod hanging blowout preventer |
| US9828823B2 (en) * | 2014-04-01 | 2017-11-28 | Cameron International Corporation | Rod hang-off system |
| MX2020012555A (en) * | 2018-05-25 | 2021-04-13 | 2170775 Alberta Ltd | Modular head for well tubulars. |
| RU2745949C1 (en) * | 2020-09-25 | 2021-04-05 | Публичное акционерное общество «Татнефть» имени В.Д. Шашина | Preventer for a well with a double-row pipe string |
| CA3147808A1 (en) * | 2021-02-05 | 2022-08-05 | Nexus Energy Technologies Inc. | Annular fracturing cleanout apparatus and method |
Family Cites Families (11)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US3151680A (en) * | 1961-11-15 | 1964-10-06 | Warren E Parkhurst | Well pressure control apparatus |
| US3664415A (en) * | 1970-09-14 | 1972-05-23 | Halliburton Co | Method and apparatus for testing wells |
| US4090395A (en) * | 1977-03-28 | 1978-05-23 | Exxon Production Research Company | Casing seal and blowout preventer tester and test method |
| US4503879A (en) * | 1983-11-04 | 1985-03-12 | Joy Manufacturing Company | Plug mechanism for wellhead tool |
| CA2077167C (en) * | 1992-08-28 | 1999-04-27 | L. Murray Dallas | Wellhead isolation tool and method of use |
| US5743332A (en) * | 1996-02-16 | 1998-04-28 | Stream-Flo Industries Ltd. | Integral wellhead assembly for pumping wells |
| US6457530B1 (en) * | 2001-03-23 | 2002-10-01 | Stream-Flo Industries, Ltd. | Wellhead production pumping tree |
| EP1270870B1 (en) * | 2001-06-22 | 2006-08-16 | Cooper Cameron Corporation | Blow out preventer testing apparatus |
| US7770653B2 (en) * | 2005-06-08 | 2010-08-10 | Bj Services Company U.S.A. | Wellbore bypass method and apparatus |
| GB2469215B (en) * | 2007-12-12 | 2011-12-14 | Cameron Int Corp | Function spool |
| EP2149670A1 (en) * | 2008-07-31 | 2010-02-03 | Services Pétroliers Schlumberger | Method and apparatus for installing a wireline for logging or other operations in an under-balanced well |
-
2011
- 2011-09-16 US US13/824,091 patent/US20130181147A1/en not_active Abandoned
- 2011-09-16 WO PCT/CA2011/001048 patent/WO2012034227A1/en active Application Filing
- 2011-09-16 AU AU2011301740A patent/AU2011301740A1/en not_active Abandoned
- 2011-09-16 CA CA2812692A patent/CA2812692C/en not_active Expired - Fee Related
Also Published As
| Publication number | Publication date |
|---|---|
| AU2011301740A1 (en) | 2013-04-04 |
| CA2812692A1 (en) | 2012-03-22 |
| US20130181147A1 (en) | 2013-07-18 |
| WO2012034227A1 (en) | 2012-03-22 |
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Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| EEER | Examination request |
Effective date: 20140829 |
|
| MKLA | Lapsed |
Effective date: 20200916 |