WO2014124419A2 - Dual bearing rotating control head and method - Google Patents
Dual bearing rotating control head and method Download PDFInfo
- Publication number
- WO2014124419A2 WO2014124419A2 PCT/US2014/015709 US2014015709W WO2014124419A2 WO 2014124419 A2 WO2014124419 A2 WO 2014124419A2 US 2014015709 W US2014015709 W US 2014015709W WO 2014124419 A2 WO2014124419 A2 WO 2014124419A2
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- bearing assembly
- interior space
- pipe
- pressure
- fluid
- Prior art date
Links
- 238000000034 method Methods 0.000 title claims description 18
- 230000009977 dual effect Effects 0.000 title description 5
- 239000012530 fluid Substances 0.000 claims description 55
- 238000004891 communication Methods 0.000 claims description 15
- 239000000314 lubricant Substances 0.000 claims description 12
- 238000005086 pumping Methods 0.000 claims description 5
- 125000006850 spacer group Chemical group 0.000 description 35
- 238000000429 assembly Methods 0.000 description 19
- 230000000712 assembly Effects 0.000 description 19
- 238000005553 drilling Methods 0.000 description 11
- 238000007789 sealing Methods 0.000 description 7
- 230000008878 coupling Effects 0.000 description 5
- 238000010168 coupling process Methods 0.000 description 5
- 238000005859 coupling reaction Methods 0.000 description 5
- 230000013011 mating Effects 0.000 description 3
- 238000005259 measurement Methods 0.000 description 3
- 230000000717 retained effect Effects 0.000 description 3
- 230000003466 anti-cipated effect Effects 0.000 description 2
- 230000015572 biosynthetic process Effects 0.000 description 1
- 239000012267 brine Substances 0.000 description 1
- 230000001143 conditioned effect Effects 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- -1 e.g. Substances 0.000 description 1
- 230000007613 environmental effect Effects 0.000 description 1
- 238000005755 formation reaction Methods 0.000 description 1
- 238000003780 insertion Methods 0.000 description 1
- 230000037431 insertion Effects 0.000 description 1
- 239000010687 lubricating oil Substances 0.000 description 1
- 238000005461 lubrication Methods 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 239000003921 oil Substances 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 description 1
- 239000003381 stabilizer Substances 0.000 description 1
- 230000003068 static effect Effects 0.000 description 1
- 238000012360 testing method Methods 0.000 description 1
- 238000012546 transfer Methods 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- 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
-
- 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
- E21B33/08—Wipers; Oil savers
- E21B33/085—Rotatable packing means, e.g. rotating blow-out preventers
-
- 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
- E21B19/00—Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables
-
- 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
- E21B47/00—Survey of boreholes or wells
- E21B47/06—Measuring temperature or pressure
Definitions
- This disclosure relates generally to the field of wellbore pressure control devices.
- the disclosure relates to pressure control devices that control and diver drilling and wellbore fluids while providing a seal around a tubular component.
- Wellbore pressure control devices include devices known as rotating control heads, rotating diverters, rotating blowout preventers (hereinafter rotating control head or "RCH"). Such pressure control devices are configured to enable a string of pipe and/or wellbore drilling or intervention tools to sealingly pass therethrough axially, and further to enable rotation of the pipe while sealing the wellbore hydraulically.
- RCH rotating control head
- a drill pipe string is passed through a bearing assembly in the RCH.
- the bearing assembly enables a seal element therein and the pipe to rotate relative to a housing that may be affixed to the top of a casing or other pipe disposed at least partially into the wellbore.
- the housing is configured to enable hydraulic communication to the interior of the wellbore below the bearing assembly.
- RCHs may be in managed pressure drilling.
- FIG. 1 is a schematic view of a pipe being inserted into a wellbore through a rotating control head (RCH);
- RCH rotating control head
- FIG. 2 is a first side view of an example RCH according to the present disclosure
- FIG. 3 is a cut away view of the RCH shown in FIG. 1;
- FIG. 4 is a second side view of the assembled RCH shown in FIG. 3;
- FIG. 5 is a cut away view of the RCH shown in FIG. 4.
- FIG. 1 An example wellbore operation in which a rotating control head (RCH) may be used is shown schematically in FIG. 1.
- a wellbore 12 may be drilled into subsurface Earth formations 13 to a selected depth.
- a pipe 14, for example, a drill pipe or drill string may include one or more structures 10, such as centralizers, stabilizers or other drilling tools that have a diameter larger than the nominal outer diameter (diameter) of the pipe 14.
- the pipe 14 may be lowered into the wellbore 12 by a hoisting system such as a drilling rig 16 or the like.
- the drilling rig 16 may include a drawworks 20 or similar hoisting apparatus that extends and retracts a drill line 21. Movement of the drill line 21 cooperates with sheaves or "blocks" 18 to cause upward and downward motion of a top drive 22 or similar device to enable rotational motion of the pipe 14.
- the wellbore 12 is filled with fluid 11, such a
- the fluid 11 is typically lifted from a pit or tank 26 disposed at the surface.
- the tank 26 may include a supply of cleaned or conditioned fluid 28.
- the fluid 28 may be lifted by a pump 24 which discharges the fluid to the top drive 22.
- Internal rotating seal elements in the top drive 22 enable the fluid 28 to be pumped through the interior of the pipe 14 into the wellbore 12.
- the top drive 22 may also be used to rotate the pipe 14, such as for axially lengthening (drilling) the wellbore 12.
- the wellbore 12 may include a pipe or casing 33 ("surface casing") set to a relatively limited depth near the surface.
- An upper end of the surface casing 33 may be coupled to a sealing element called a rotating control head 34.
- the rotating control head 34 may be coupled to the casing by a flange 34B to a corresponding flange 33A at the upper end of the surface casing 33, although the manner of coupling the rotating control head 34 to the surface casing 33 is not a limitation on the scope of the present disclosure.
- the rotating control head 34 seals an annular space 12A between the exterior of the pipe 14 and the interior of the surface casing 33 to prevent uncontrolled release of fluid 11 from the wellbore 12.
- the rotating control head 34 may include a fluid discharge outlet 34A.
- the fluid discharge outlet 34A may be disposed below sealing elements (FIGS. 2 and 3) in the rotating control head 34 to enable flow of the fluid 11 out of the annular space 12A.
- the fluid outlet 34A may be coupled through a controllable choke 32 or similar variable restriction flow control device that ultimately may return the fluid 11 to the tank 26.
- the fluid discharge outlet 34A may include a pump 30 coupled thereto at its discharge side so that fluid pressure in the wellbore 12 outside the pipe 14 may be maintained at a selected level. The pressure of fluid being discharged from the annular space 12A may be measured using a pressure sensor 127C in fluid communication with the fluid discharge outlet 34A.
- FIG. 1 The example shown in FIG. 1 has a pipe 14 in the form of a drill string being inserted into the wellbore 12.
- the rotating control head 34 of the present disclosure is equally applicable to any type of pipe being inserted into a wellbore, including as non-limiting examples casing, liner, coiled tubing, production tubing and rod strings. Accordingly, a rotating control head according to the present disclosure is not limited in scope to being used with a drill string.
- the structures 10 may be centralizers affixed to the exterior of the pipe 14 to provide force to urge the pipe 14 toward the center of the wellbore 12 when inserted therein.
- a possible advantage of the rotating control head 34 of the present disclosure when structures are used on the pipe 14 having a larger diameter than the nominal outer diameter of the pipe 14 will be further explained below.
- two independent bearing assemblies each having a sealing or stripper element associated therewith, may be assembled to a rotating control head housing in tandem and connected to each other in spaced apart relation by a housing such as a spacer spool.
- a first bearing assembly may be configured to support most of the operating load of wellbore operations.
- a second bearing assembly may enable continuing wellbore operations to a point where the ordinary sequence of wellbore operations would allow for a bearing assembly to be replaced without unduly interrupting wellbore operations.
- the bearing assemblies may be connected to each other and longitudinally spaced apart by a housing such as a "spacer spool" and clamping system.
- a first bearing assembly 118 may bolt to or otherwise be affixed to the bottom of the interior of a main rotating control head housing that is affixable to the wellbore pipe or surface casing (33 in FIG. 1), or, for example, to a drilling riser when the rotating control head is used in marine drilling operations.
- a second bearing assembly 110 may be affixed in place on the upper end of the housing or spacer spool using fasteners similar to those used in conventional rotating control heads, for example, band-type clamps or threaded rings.
- the entire dual bearing system may then clamp onto the main rotating control head housing using, for example, a single band type clamp or other type of fastener, e.g., mating flanges with an internal o-ring seal.
- the spacer spool may have an interior space between the bearing assemblies that is in fluid communication with a port in the spacer spool. Such port may be used, for example, for measurement of pressure and/or introduction of fluid into the interior space in the spacer spool.
- the first bearing assembly 118 as well as the second bearing assembly 110 may require additional seals within a bearing pack, sufficiently strong to control the intended maximum operating pressures (e.g., 3000 pounds per square inch static) in the wellbore (12 in FIG. 1).
- the bearing pack and associated seals will be explained below with reference to FIG. 3.
- the spacer spool 114 may allow the first and second bearing assemblies 118, 110 to operate independently. With suitably selected longitudinal spacing between the first and second bearing assemblies 118, 110, such as may be obtained by suitable selection of the length of the spacer spool 114, the housing or spacer spool 114 may enable a continuously engaged seal around at least part of a nominal outer diameter portion of the pipe (e.g., 14 in FIG.
- the example first and second bearing assemblies 118, 110 may be stabbed onto a pipe (e.g., the pipe 14 in FIG. 1), positioned within the rotating control head housing and the spacer spool 114, respectively, retained in place and the interior space in the spacer spool 114 between the two bearing assemblies 118, 110 may subsequently be filled with a fluid medium, e.g., lubricant, and pressurized to a predetermined pressure.
- a fluid medium e.g., lubricant
- Such pressure may be a equal to or above anticipated operating pressures in the wellbore (12 in FIG. 1) in some implementations.
- the wellbore operator may be able to detect pressure anomalies both within the spacer spool 114 and the bearing assemblies 118, 110.
- a measured pressure spike or loss within the spacer spool 114 may indicate first bearing assembly 118 leakage or proximate failure.
- the foregoing may enable the wellbore operator sufficient warning to allow determining a timeline of the anticipated life expectancy of the second bearing assembly 110, thus enabling the wellbore operator to plan a bearing assembly change at a point within the wellbore operations that minimizes disruption of the ordinary course of such operations.
- FIG. 2 A side view of an assembled dual bearing assembly rotating control head 34 according to the present disclosure is shown in FIG. 2.
- a second bearing assembly 110 may be retained in place within an upper end of a second housing, hereinafter referred to as a "spacer spool" 114 by a band clamp 112 or other retaining element known in the art.
- the spacer spool 114 may include one or more ports 114A, terminated with couplings such as flanges or other pressure tight coupling features.
- the one or more ports 114A may be in fluid communication with an interior space (114B in FIG. 3) in the spacer spool 114.
- the interior space 114B may enable fluid introduced therein to contact both bearing assemblies 118, 110 (explained further below).
- a lubricant e.g., lubricating oil
- a fluid pump 129 may be in fluid communication with the one or more ports 114A to enable such pumping.
- the pressure applied by the pump 129 may be maintained at any selected value by a pressure regulator 127 A coupled to either of the ports 114A.
- the pump 129 may be used to pump fluid into the interior of the spacer spool, e.g., through one of the ports 114A so that the rotating control head (34 in FIG. 1) may be tested for any leakage.
- Such pressure testing may require insertion of a pipe (e.g., 14 in FIG. 1) through the first and second bearing assemblies (110 and 118, respectively, in FIG. 3) to close a passage (explained below) provided through the first and second bearing assemblies.
- the first bearing assembly (118 in FIG. 3) may be retained in place in a main rotating control head housing 124 using a flange-type bearing retainer 123.
- the flange type bearing retainer 123 may be affixed to a first housing, hereinafter referred to as the "main rotating control head housing” 124 using a band clamp 120 or any other coupling device.
- the flange type bearing retainer 123 may be coupled to a mating flange 121 on the spacer spool 114 using studs and nuts, shown generally at 125, such studs and nuts being of types known in the art for affixing mating flanges in a flange coupling together.
- the main rotating control head housing 124 may couple to the wellbore pipe or casing (33 in FIG. 1) using a fluid pressure tight connector of any type known in the art, for example a flange 34B as shown in FIG. 2.
- a fluid pressure tight connector of any type known in the art, for example a flange 34B as shown in FIG. 2.
- the example flange 34B shown in FIG. 2 is not intended to limit the scope of what may be used to couple the main rotating control head housing 124 to the wellbore pipe (33 in FIG. 1).
- band clamps as shown in FIG. 2 is not intended to limit the scope of means by which the main rotating control head housing 124 and the first bearing assembly (118 in FIG. 3) are respectively coupled.
- using a band type clamp 112 to couple the second bearing assembly 110 to the spacer spool 114 is only provided as an example and is not intended to limit the means by which the second bearing assembly 110 may be affixed to the spacer spool 114.
- FIG. 4 shows a view of the rotating control head shown in FIG. 2 rotated 90 degrees.
- the view of FIG. 4 more clearly shows the one or more ports 114A in the spacer spool.
- the main rotating control head housing 124 may include an additional fluid discharge port 34B, which is in hydraulic communication with the interior of the main rotating control head housing 124.
- FIG. 5 shows a cross-sectional view of the view shown in FIG. 4.
- the ports 114A are visible as being in fluid communication with the interior of the spacer spool 114.
- the two fluid discharge ports 34A, 34B in the main rotating control head housing 124 are also observable as being in fluid communication with the interior of the main rotating control head housing 124 below the first stripper element (122 in FIG. 3).
- Each of the first 118 and second bearing 110 and assemblies may include a respective stripper element 122, 116 to provide sealing engagement to a pipe or pipe string moved longitudinally through each bearing assembly 118, 110, respectively, e.g., the pipe 14 as shown in FIG. 1.
- such assembly may include a sleeve 110A for engaging and/or guiding the pipe (14 in FIG. 1) as it is moved longitudinally through the second bearing assembly 110.
- the stripper element 116 may be affixed to a lower end of the sleeve 11 OA so that pipe moved through the sleeve 110A has a pressure tight seal to substantially prevent escape of fluid from within the interior space 114B in the spacer spool 114.
- the sleeve 11 OA may include a shoulder 11 OF on an exterior thereof.
- the shoulder 110F may be in contact with an upper bearing 1 IOC and a lower bearing HOD each on one side of the shoulder 11 OF.
- the upper bearing HOC and the lower bearing HOD may rotatably transfer axial loading from the sleeve 11 OA to a bearing housing 110E.
- the bearing housing 110E may be the portion of the second bearing assembly that is coupled to the spacer spool 114.
- the upper bearing 1 IOC and the lower bearing HOD may each be sealed with respective seals 111 of any type known in the art to seal a rotating shaft passing through a bearing supporting such shaft rotatably in a fixed housing.
- the first bearing assembly 118 may be mounted in the main rotating control head housing 124 as explained above, and may have substantially the same components, including a sleeve and stripper element 122 as explained with reference to the second bearing assembly 110.
- An additional pressure sensor 127B may be disposed in a chamber therefor located above the upper seal 111. In the event any fluid leaks past the second bearing assembly 110, suck leakage may be detected by an increase in the pressure measured by the additional pressure sensor 127B. By using measurements of pressure from the pressure sensor (127 in FIG. 2) in communication with one of the ports (114A in FIG. 2) and the additional pressure sensor 127 A, it may be possible to identify which of the first and second bearing assemblies and associated stripper elements may be leaking.
- an increase in measured pressure in the spacer spool 114 may indicate the stripper element 122 in the first bearing assembly 118 is leaking.
- a reduction in pressure measured in the spacer spool 114 may indicate that the striper element 116 in the second bearing assembly 110 is leaking.
- measurements of pressure using the additional pressure sensor may indicate leakage of the seal and bearing pack associated with the second bearing assembly 110.
- One or more of such indications based on measured pressure may provide the wellbore operator an indication that the first bearing assembly requires removal and replacement.
- removal and replacement may be performed at a time during wellbore operations so as to minimize disruption of such operations.
- One specific example may be during a time in which the entire pipe is removed from the wellbore to change a drill bit.
- the stripper element 116 in the second bearing assembly 110 may prevent fluid from bypassing the rotating control head 34, thus providing the wellbore operator with a possible opportunity to continue wellbore operations uninterrupted until a convenient time is available for bearing assembly replacement.
- the foregoing continuation of wellbore operations may be based on an estimated remaining lifetime of the second bearing assembly and/or the stripper element associated therewith. Provided that the estimated remaining lifetime is at least or exceeds an expected time until the convenient time, wellbore operations may continue until the convenient time, whereupon the first and/or second bearing assemblies may be replaced.
- the spacer spool 114 may also enhance safety of wellbore operations by reducing the possibility of fluid leakage past the rotating control head 34 as a result of having redundant bearing assemblies.
- lubricant such as oil
- Another example may be to pump fluid, e.g., lubricant, into the interior of the spacer spool (114B in FIG. 3) to a pressure substantially equal to the expected operating pressure in the wellbore casing (33 in FIG. 1).
- fluid e.g., lubricant
- By pumping fluid into the interior space (114B in FIG. 3) to such pressure it may be possible to avoid sudden introduction of wellbore pressure to the second bearing assembly (110 in FIG. 3) and stripper element (116 in FIG. 3) in the event of failure of the first bearing assembly seals and/or the associated stripper element (118 in FIG. 3).
- the possibility of consequent failure of the second bearing assembly and/or the associated stripper element may be reduced.
- a rotating control head that includes two independent and sealed bearing assemblies and sealing elements may provide increased safety in wellbore operations and reduced risk of wellbore fluid leakage and consequent environmental hazard.
- an apparatus comprises a first bearing assembly, a second bearing assembly, a housing and a pipe.
- the first bearing assembly, the second bearing assembly and the housing define an interior space.
- the pipe extends through the first bearing assembly and the second bearing assembly and through the interior space.
- a method comprises pressurizing fluid to a predetermined value in an interior space defined by a housing, a first bearing assembly and a second bearing assembly. The method further comprises measuring a pressure of the interior space to determine a leak in at least one of the first bearing assembly and the second bearing assembly when the measured pressure differs from the predetermined by a predetermined amount.
- a method comprises pumping lubricant into an interior space of an apparatus defined by at least a first bearing assembly and a second bearing assembly.
- Each of the first bearing assembly and the second bearing assembly comprises a stripper element.
- the method further comprises inserting a pipe through the interior space so as to go through the first bearing assembly and the second bearing assembly.
Landscapes
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Life Sciences & Earth Sciences (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Fluid Mechanics (AREA)
- Environmental & Geological Engineering (AREA)
- Geochemistry & Mineralogy (AREA)
- Mechanical Engineering (AREA)
- Geophysics (AREA)
- Earth Drilling (AREA)
- Paper (AREA)
- Seats For Vehicles (AREA)
- Vehicle Body Suspensions (AREA)
- Machine Tool Units (AREA)
- Crushing And Grinding (AREA)
Abstract
Description
Claims
Priority Applications (3)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
BR112015019224A BR112015019224A2 (en) | 2013-02-11 | 2014-02-11 | apparatus, and method |
US14/766,576 US20150376972A1 (en) | 2013-02-11 | 2014-02-11 | Dual bearing rotating control head and method |
NO20151042A NO20151042A1 (en) | 2013-02-11 | 2015-08-13 | Dual bearing rotating control head and method |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US201361762989P | 2013-02-11 | 2013-02-11 | |
US61/762,989 | 2013-02-11 |
Publications (2)
Publication Number | Publication Date |
---|---|
WO2014124419A2 true WO2014124419A2 (en) | 2014-08-14 |
WO2014124419A3 WO2014124419A3 (en) | 2015-01-15 |
Family
ID=51300280
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/US2014/015709 WO2014124419A2 (en) | 2013-02-11 | 2014-02-11 | Dual bearing rotating control head and method |
Country Status (4)
Country | Link |
---|---|
US (1) | US20150376972A1 (en) |
BR (1) | BR112015019224A2 (en) |
NO (1) | NO20151042A1 (en) |
WO (1) | WO2014124419A2 (en) |
Cited By (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
CN105625976A (en) * | 2014-10-31 | 2016-06-01 | 中国石油天然气股份有限公司 | Flow controlling and pollution preventing cover for oil tube |
WO2016073752A3 (en) * | 2014-11-06 | 2016-06-30 | Schlumberger Technology Corporation | Cooling of rotating control device |
Families Citing this family (10)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US10113378B2 (en) * | 2012-12-28 | 2018-10-30 | Halliburton Energy Services, Inc. | System and method for managing pressure when drilling |
US11993997B1 (en) * | 2013-03-15 | 2024-05-28 | Pruitt Tool & Supply Co. | Sealed lubricating head and top drive guide |
WO2015112629A1 (en) * | 2014-01-22 | 2015-07-30 | Cameron Rig Solutions, Inc. | Hydraulically deactivated clamp |
CN105072400B (en) * | 2015-08-07 | 2019-01-25 | 北京爱国小男孩科技有限公司 | Control of stamping system and method |
MX2019002245A (en) * | 2016-08-26 | 2019-06-20 | Hydril Usa Distrib Llc | Transducer assembly for offshore drilling riser. |
BR112020011247B1 (en) | 2017-12-12 | 2023-11-14 | Ameriforge Group Inc | METHOD FOR MONITORING SEAL CONDITION FOR AN ANNULAR SEALING SYSTEM |
EP3867490B1 (en) | 2018-10-19 | 2024-01-24 | Grant Prideco, Inc. | Annular sealing system and integrated managed pressure drilling riser joint |
BR112021007976A2 (en) * | 2018-11-02 | 2021-07-27 | Ameriforge Group Inc. | integrated mpd riser connection for harsh environment |
GB201818114D0 (en) * | 2018-11-06 | 2018-12-19 | Oil States Ind Uk Ltd | Apparatus and method relating to managed pressure drilling |
US11808111B2 (en) | 2022-02-11 | 2023-11-07 | Weatherford Technology Holdings, Llc | Rotating control device with integrated cooling for sealed bearings |
Citations (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US5647444A (en) * | 1992-09-18 | 1997-07-15 | Williams; John R. | Rotating blowout preventor |
US20110024195A1 (en) * | 2009-07-31 | 2011-02-03 | Weatherford/Lamb, Inc. | Drilling with a high pressure rotating control device |
US20120177313A1 (en) * | 2007-12-21 | 2012-07-12 | Optimal Pressure Drilling Services Inc. | Seal cleaning and lubricating bearing assembly for a rotating flow diverter |
US8245772B1 (en) * | 2008-02-29 | 2012-08-21 | Pruitt Tool & Supply Co. | Extended wear ball lock for rotating head |
US20120217022A1 (en) * | 2009-06-19 | 2012-08-30 | George James Michaud | Universal rotating flow head having a modular lubricated bearing pack |
Family Cites Families (11)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US6230824B1 (en) * | 1998-03-27 | 2001-05-15 | Hydril Company | Rotating subsea diverter |
US7717170B2 (en) * | 2007-08-27 | 2010-05-18 | Williams John R | Stripper rubber pot mounting structure and well drilling equipment comprising same |
US7717169B2 (en) * | 2007-08-27 | 2010-05-18 | Theresa J. Williams, legal representative | Bearing assembly system with integral lubricant distribution and well drilling equipment comprising same |
US7762320B2 (en) * | 2007-08-27 | 2010-07-27 | Williams John R | Heat exchanger system and method of use thereof and well drilling equipment comprising same |
US7798250B2 (en) * | 2007-08-27 | 2010-09-21 | Theresa J. Williams, legal representative | Bearing assembly inner barrel and well drilling equipment comprising same |
US7789172B2 (en) * | 2007-08-27 | 2010-09-07 | Williams John R | Tapered bearing assembly cover plate and well drilling equipment comprising same |
US7635034B2 (en) * | 2007-08-27 | 2009-12-22 | Theresa J. Williams, legal representative | Spring load seal assembly and well drilling equipment comprising same |
US7726416B2 (en) * | 2007-08-27 | 2010-06-01 | Theresa J. Williams, legal representative | Bearing assembly retaining apparatus and well drilling equipment comprising same |
US8573294B2 (en) * | 2009-07-31 | 2013-11-05 | Schlumberger Technology Corporation | Cable bypass and method for controlled entry of a tubing string and a cable adjacent thereto |
US9175542B2 (en) * | 2010-06-28 | 2015-11-03 | Weatherford/Lamb, Inc. | Lubricating seal for use with a tubular |
BR112014031257B1 (en) * | 2012-06-12 | 2021-08-24 | Weatherford Technology Holdings, Llc | ROTARY FLOW CONTROL DERACTION APPLIANCE |
-
2014
- 2014-02-11 WO PCT/US2014/015709 patent/WO2014124419A2/en active Application Filing
- 2014-02-11 US US14/766,576 patent/US20150376972A1/en not_active Abandoned
- 2014-02-11 BR BR112015019224A patent/BR112015019224A2/en not_active Application Discontinuation
-
2015
- 2015-08-13 NO NO20151042A patent/NO20151042A1/en not_active Application Discontinuation
Patent Citations (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US5647444A (en) * | 1992-09-18 | 1997-07-15 | Williams; John R. | Rotating blowout preventor |
US20120177313A1 (en) * | 2007-12-21 | 2012-07-12 | Optimal Pressure Drilling Services Inc. | Seal cleaning and lubricating bearing assembly for a rotating flow diverter |
US8245772B1 (en) * | 2008-02-29 | 2012-08-21 | Pruitt Tool & Supply Co. | Extended wear ball lock for rotating head |
US20120217022A1 (en) * | 2009-06-19 | 2012-08-30 | George James Michaud | Universal rotating flow head having a modular lubricated bearing pack |
US20110024195A1 (en) * | 2009-07-31 | 2011-02-03 | Weatherford/Lamb, Inc. | Drilling with a high pressure rotating control device |
Cited By (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
CN105625976A (en) * | 2014-10-31 | 2016-06-01 | 中国石油天然气股份有限公司 | Flow controlling and pollution preventing cover for oil tube |
CN105625976B (en) * | 2014-10-31 | 2017-12-01 | 中国石油天然气股份有限公司 | A kind of oil pipe flow control dirtproof cover |
WO2016073752A3 (en) * | 2014-11-06 | 2016-06-30 | Schlumberger Technology Corporation | Cooling of rotating control device |
GB2547365A (en) * | 2014-11-06 | 2017-08-16 | Schlumberger Technology Bv | Cooling of rotating control device |
US10156117B2 (en) | 2014-11-06 | 2018-12-18 | Schlumberger Technology Corporation | Cooling of rotating control device |
Also Published As
Publication number | Publication date |
---|---|
BR112015019224A2 (en) | 2017-07-18 |
NO20151042A1 (en) | 2015-08-13 |
US20150376972A1 (en) | 2015-12-31 |
WO2014124419A3 (en) | 2015-01-15 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
US20150376972A1 (en) | Dual bearing rotating control head and method | |
US9845653B2 (en) | Fluid supply to sealed tubulars | |
US9951600B2 (en) | Managed pressure cementing | |
US8820747B2 (en) | Multiple sealing element assembly | |
EP2518261B1 (en) | Automated well control method and apparatus | |
US20190093445A1 (en) | Systems and methods for controlling flow from a wellbore annulus | |
US10260307B2 (en) | Drill tool insert removal | |
EP3128120B1 (en) | Marine diverter system | |
EP2703599A2 (en) | Fluid seal with swellable material packing | |
US10590730B2 (en) | Packer box and method for installation or withdrawal of a packer element in, respectively from a packer box for use in petroleum drilling | |
US20200056441A1 (en) | Continuous Circulation System for Rotational Drilling | |
EP2582906B1 (en) | Grinding arrangement for tool joints on a drill string | |
US11434714B2 (en) | Adjustable seal for sealing a fluid flow at a wellhead | |
US20140262326A1 (en) | Purging fluid circuits in wellbore control devices | |
WO2017058026A1 (en) | Packer box and method for installation or withdrawal of a packer element in, respectively from a packer box for use in petroleum drilling |
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: 14749560 Country of ref document: EP Kind code of ref document: A2 |
|
WWE | Wipo information: entry into national phase |
Ref document number: 14766576 Country of ref document: US |
|
122 | Ep: pct application non-entry in european phase |
Ref document number: 14749560 Country of ref document: EP Kind code of ref document: A2 |
|
REG | Reference to national code |
Ref country code: BR Ref legal event code: B01A Ref document number: 112015019224 Country of ref document: BR |
|
ENP | Entry into the national phase |
Ref document number: 112015019224 Country of ref document: BR Kind code of ref document: A2 Effective date: 20150811 |