WO2012034227A1 - 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
- WO2012034227A1 WO2012034227A1 PCT/CA2011/001048 CA2011001048W WO2012034227A1 WO 2012034227 A1 WO2012034227 A1 WO 2012034227A1 CA 2011001048 W CA2011001048 W CA 2011001048W WO 2012034227 A1 WO2012034227 A1 WO 2012034227A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- tubing string
- blowout preventer
- casing
- tubing
- elongate member
- Prior art date
Links
- 239000012530 fluid Substances 0.000 claims abstract description 10
- 230000015572 biosynthetic process Effects 0.000 claims abstract description 4
- 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
- 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
- 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
Definitions
- 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.
- a blowout preventer 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.
- 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.
- 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.
- 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.
- 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.
- 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.
- 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.
- 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.
- Figure 10 is a cross-sectional view taken along the line 10-10 of Figure 8. DESCRIPTION OF THE PREFERRED EMBODIMENT
- the new improved BOP design combines several wellhead servicing procedures that are done on various wellhead components to be completed in the BOP.
- stuffing boxes, polish rod clamps and BOP's had to be unbolted and removed to gain access to the tubing string and sucker rods, rotors, stators, pumps, 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 of the present invention will allow for the servicing and the operation of the wellhead to be contained in one unit.
- the BOP has a removable stuffing box built into a rod hanger.
- the rod hanger is preferably situated internally in the top of the BOP with the entrance to the tubing string being through the rod hanger. With the use of seals and lock down screws the rod hanger is sealed and secured to the BOP.
- the top of the rod hanger receives the shaft of a PCP drive head or some form of rotating input shaft that transmits rotating torque through the rod hanger to an end of the rod hanger shaft which is connected to the sucker rods for driving a PCP rotor.
- the BOP rams 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 that could also seal off the well pressure if there were no rods in the center of the BOP.
- the BOP could also have more than two sets of rams.
- the rod input shaft may be connected to a secondary shaft below it, the secondary shaft having a area for the rams to clamp the shaft securely with teeth, spline etc. This shaft would be useful when lifting the rod hanger out of the BOP where the rams 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 and sealed and clamped from preventing rotation.
- 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.
- the drive motor only needs to have a shaft engagement in the rod hanger, leaving no rotating members sticking out of the top of the drive motor.
- the rod 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. Alternately, there could be more than one plug, or a combination of plugs and valves .
- the new BOP also receives the tubing hanger below the rams.
- the tubing hanger is sealed and held in place with lock down screws.
- the tubing hanger would typically be placed in a casing bowl or tubing head. Having the hanger placed in the BOP saves time, since in prior wells the BOP would have to be removed to gain access to ' the tubing hanger.
- the BOP of the present invention has an entry port that allows fluid, coiled tubing, a cable, probe or other elongate member to enter the BOP 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 is used for inserting probes or sensors) the angle of entry could be greater.
- the coil tubing fluid or other elongate member
- the BOP can be constructed with one or more entry ports.
- Those entry ports may also be at different locations about the main body of the BOP, may have different angles of inclination and may terminate at either the bottom surface of the BOP or within the longitudinal bore through the BOP main housing.
- the entry ports may allow direct access to .
- the interior of the tubing string (for example, see Figure 5), may allow direct access to the annulus between the casing and the tubing string (for example, see Figure 3) or may allow direct access to both the interior of the tubing string and the annulus between the casing and the tubing string (for example, see Figure 7).
- the entry port would commonly be positioned above the rams, it could also be located below the rams and/or below the rams and tubing hanger.
- the entry port saves time as the hanger does not have to be removed or lifted from the BOP to perform a flush by operation.
- This improved BOP 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 also helps to reduce wellhead height which has advantages in terms of strain on wellhead equipment in non-vertical wells.
Landscapes
- 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
Description
Claims
Priority Applications (3)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US13/824,091 US20130181147A1 (en) | 2010-09-16 | 2011-09-16 | Blowout preventer with port for entry between casing and tubing string and/or port for entry into tubing string |
AU2011301740A AU2011301740A1 (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 |
CA2812692A 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 |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US38361310P | 2010-09-16 | 2010-09-16 | |
US61/383,613 | 2010-09-16 |
Publications (1)
Publication Number | Publication Date |
---|---|
WO2012034227A1 true WO2012034227A1 (en) | 2012-03-22 |
Family
ID=45830900
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
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 |
Country Status (4)
Country | Link |
---|---|
US (1) | US20130181147A1 (en) |
AU (1) | AU2011301740A1 (en) |
CA (1) | CA2812692C (en) |
WO (1) | WO2012034227A1 (en) |
Cited By (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
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 |
Families Citing this family (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US8567489B2 (en) * | 2008-02-11 | 2013-10-29 | Cameron International Corporation | Angled-penetrator device and system |
US9828823B2 (en) * | 2014-04-01 | 2017-11-28 | Cameron International Corporation | Rod hang-off system |
AU2019273874A1 (en) * | 2018-05-25 | 2020-12-17 | 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 |
US20220251917A1 (en) * | 2021-02-05 | 2022-08-11 | Nexus Energy Technologies Inc. | Annular fracturing cleanout apparatus and method |
Citations (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3664415A (en) * | 1970-09-14 | 1972-05-23 | Halliburton Co | Method and apparatus for testing wells |
US6457530B1 (en) * | 2001-03-23 | 2002-10-01 | Stream-Flo Industries, Ltd. | Wellhead production pumping tree |
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 |
Family Cites Families (8)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3151680A (en) * | 1961-11-15 | 1964-10-06 | Warren E Parkhurst | Well pressure control apparatus |
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 |
EP1270870B1 (en) * | 2001-06-22 | 2006-08-16 | Cooper Cameron Corporation | Blow out preventer testing apparatus |
CA2611316C (en) * | 2005-06-08 | 2011-02-22 | Bj Services Company | Wellhead bypass method and apparatus |
BRPI0820743A2 (en) * | 2007-12-12 | 2015-06-16 | Cameron Int Corp | Function reel |
-
2011
- 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 US US13/824,091 patent/US20130181147A1/en not_active Abandoned
- 2011-09-16 CA CA2812692A patent/CA2812692C/en not_active Expired - Fee Related
Patent Citations (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3664415A (en) * | 1970-09-14 | 1972-05-23 | Halliburton Co | Method and apparatus for testing wells |
US6457530B1 (en) * | 2001-03-23 | 2002-10-01 | Stream-Flo Industries, Ltd. | Wellhead production pumping tree |
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 |
Cited By (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
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 |
Also Published As
Publication number | Publication date |
---|---|
AU2011301740A1 (en) | 2013-04-04 |
US20130181147A1 (en) | 2013-07-18 |
CA2812692A1 (en) | 2012-03-22 |
CA2812692C (en) | 2018-03-13 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
CA2812692C (en) | Improved blowout preventer with port for entry between casing and tubing string and/or port for entry into tubing string | |
US6827147B2 (en) | Reciprocating lubricator | |
US8002028B2 (en) | Hydraulic connector apparatuses and methods of use with downhole tubulars | |
US4683944A (en) | Drill pipes and casings utilizing multi-conduit tubulars | |
US8794351B2 (en) | Device and method for drilling with continuous tool rotation and continuous drilling fluid supply | |
CA2967933C (en) | Subsea slanted wellhead system and bop system with dual injector head units | |
US7740074B2 (en) | Tree mounted well flow interface device | |
US20050109514A1 (en) | Tree mounted well flow interface device | |
US20080060815A1 (en) | Wellhead seal unit | |
WO2009098473A2 (en) | Hydraulic connector apparatuses and methods of use with downhole tubulars | |
US11624358B2 (en) | Measuring backlash of a pump gear train | |
EP4303398A2 (en) | Modular head for well tubulars | |
EP3516157B1 (en) | Combined casing and drill-pipe fill-up, flow-back and circulation tool | |
US20220268110A1 (en) | Systems and Methods For Rotating a Casing String In a Wellbore | |
EP3807494B1 (en) | Method for replacing a chemical injection valve connected to a well head via an injection line housing and injection line plugging tool | |
RU2326267C2 (en) | Screw-type pumping unit for sand-containing oil production | |
RU2143052C1 (en) | Sealing fittings (versions) | |
OA21231A (en) | A Continuous Rod Pump Drive System. |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
121 | Ep: the epo has been informed by wipo that ep was designated in this application |
Ref document number: 11824400 Country of ref document: EP Kind code of ref document: A1 |
|
DPE1 | Request for preliminary examination filed after expiration of 19th month from priority date (pct application filed from 20040101) | ||
ENP | Entry into the national phase |
Ref document number: 2812692 Country of ref document: CA |
|
WWE | Wipo information: entry into national phase |
Ref document number: 13824091 Country of ref document: US |
|
NENP | Non-entry into the national phase |
Ref country code: DE |
|
ENP | Entry into the national phase |
Ref document number: 2011301740 Country of ref document: AU Date of ref document: 20110916 Kind code of ref document: A |
|
122 | Ep: pct application non-entry in european phase |
Ref document number: 11824400 Country of ref document: EP Kind code of ref document: A1 |