US20040060699A1 - Torque reducing tubing component - Google Patents

Torque reducing tubing component Download PDF

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Publication number
US20040060699A1
US20040060699A1 US10/451,197 US45119703A US2004060699A1 US 20040060699 A1 US20040060699 A1 US 20040060699A1 US 45119703 A US45119703 A US 45119703A US 2004060699 A1 US2004060699 A1 US 2004060699A1
Authority
US
United States
Prior art keywords
component
upsets
tubing
stand
torque reducing
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Abandoned
Application number
US10/451,197
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English (en)
Inventor
Gholam Rastegar
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Weatherford Lamb Inc
Original Assignee
Individual
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Priority claimed from GB0031010A external-priority patent/GB0031010D0/en
Application filed by Individual filed Critical Individual
Assigned to WEATHERFORD/LAMB, INC. reassignment WEATHERFORD/LAMB, INC. ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: RASTEGAR, GHOLAM
Publication of US20040060699A1 publication Critical patent/US20040060699A1/en
Abandoned legal-status Critical Current

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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
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/10—Wear protectors; Centralising devices, e.g. stabilisers
    • E21B17/1078—Stabilisers or centralisers for casing, tubing or drill pipes
    • 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
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/22—Rods or pipes with helical structure

Definitions

  • the present invention relates to a component for insertion in a tubing string to reduce torque when the tubing string is inserted in to a bore hole.
  • the component is for use within the oil, gas and mining industries especially, but not exclusively, for drilling of high angle, horizontal and extended reach wells.
  • a drill string is assembled by connecting lengths of drill pipe above a drill bit.
  • the drill string is used to transfer rotary motion from the surface equipment to the drill bit, thereby causing the drill bit to rotate and penetrate formation.
  • the torque required at surface to cause rotation of the drill bit is substantial due to the friction caused by contact between the drill string and the wall of the bore.
  • An inherent part of this drilling process also involves the pumping of drilling fluid (mud) down the bore through the inside diameter of the drill string. This process is carried out to improve the drilling performance of the bit, to assist with cooling and lubrication of the bit as well as to provide a means for the transfer of the drill cuttings to surface.
  • drilling fluid mud
  • the conveyance of the drill cuttings is a function of well depth, well profile, shape and size of drill cuttings, mechanical properties of the drilling fluid and the capacity of surface mud pumps.
  • Accumulation of drill cuttings in the well bore, resulting in the formation of a cuttings bed is a major obstacle in any drilling operation. Such an accumulation of cuttings results in an increased down hole torque and in some instances can lead to a drill string getting stuck in the bore hole. Therefore, an efficient drilling fluid circulation process for the removal of such cuttings is essential for an efficient drilling operation.
  • a further object of at least one embodiment of the present invention is to provide a tubing component which reduces the rotational friction surface area of the drill string, therefore reducing torque.
  • a yet further object of at least one embodiment of the present invention is to provide a robust, fail safe mechanical, stand-off within the drill string so as to minimise the rotational contact between the drill string and the bore wall.
  • a torque reducing tubing component for insertion in a tubing string, the component comprising a generally tubular body having an inner bore on a longitudinal axis therethrough, first and second ends for connecting the component in the tubing string, and an outer surface including one or more upsets, the one or more upsets being located longitudinally along the body and extending circumferentially around the body.
  • the upsets are integral with the tubular body.
  • the component may be of unitary construction.
  • the component is made of steel.
  • the component may be made of titanium, aluminium or the like.
  • the component is made of the same material as the tubing string to which it is attached.
  • the one or more upsets may be stand-off upsets.
  • the stand-off upsets Preferably have an outer diameter greater than those of the connections on the first and second ends. In this way the outer surface of the stand-off upsets are the only points of the tubing string in contact with the bore hole wall.
  • each stand-off upset Preferably upon the outer surface of each stand-off upset are located a plurality of longitudinally extending arc grooves. More preferably the arc grooves spiral around the tubular body in a helical pattern. The arc grooves may provide 360 degree coverage on the outer surface of the stand-off upset.
  • each arc groove comprises, in the direction of rotation of the tubing string, a first leading edge, an arc or cylindrical bed of the groove and a first trailing edge, wherein each edge connects the cylindrical bed to the outer surface of the stand-off upset at an edge angle.
  • the first leading edge includes a positive leading edge angle.
  • the positive leading edge angle is greater than ninety degrees.
  • the first trailing edge includes a positive leading edge angle also.
  • the one or more upsets may be agitator upsets.
  • the agitator upsets have an outer diameter smaller than the outer diameter of the stand-off upsets. Thus the agitator upsets do not contact the wall of the bore hole when in use.
  • each agitator upset Preferably upon the outer surface of each agitator upset are located a plurality of longitudinally extending notch grooves. More preferably the notch grooves spiral around the tubular body in a helical pattern. The notch grooves may provide 360 degree coverage on the outer surface of the agitator upset.
  • each notch groove comprises, in the direction of rotation of the tubing string, a second leading edge, a notch or ‘V’ bed of the groove and a second trailing edge, wherein each edge connects the notch to the outer surface of the agitator upset at an edge angle.
  • the second leading edge includes a negative leading edge angle.
  • the negative leading edge angle is less than or equal to ninety degrees.
  • the second trailing edge includes a positive leading edge angle.
  • the one or more upsets are a combination of stand-off upsets and agitator upsets.
  • each stand-off upset is bounded longitudinally by one or more agitator upsets.
  • the first and second ends comprise threaded pin and box connections respectively as are known in the art.
  • the connections include joint stand-off upsets.
  • the joint stand-off upsets may have a smaller outer diameter than the stand-off upsets.
  • the joint stand-off upsets are integral with the component.
  • the joint stand-off upsets are made of chromium carbide or tungsten carbide in mild steel or equivalent matrix or like material.
  • the combination upsets comprise a stand-off upset and two agitator upsets, one positioned on either side of the stand-off upset.
  • the component may be a short collar, a short drill pipe and/or a short sub.
  • the component may be a casing or liner.
  • the component is a drill pipe, having a length approximately equal to the length of a single joint of drill pipe as is known in the art.
  • the torque reducing tubing component is according to the first aspect.
  • the tubing string is a drill string
  • the fluid is drilling mud
  • the portion of fluid returned to the surface includes drill cuttings.
  • the tubing string is a casing and the fluid is cement as would occur when cementing a casing.
  • the tubing string may be reciprocated within the bore when run.
  • the tubing string is rotated in the bore when run.
  • FIG. 1 a side view of a torque reducing tubing component in accordance with a first embodiment of the present invention
  • FIGS. 2 ( a ), ( b ) and ( c ) are consecutive longitudinal side views of a torque reducing tubing component according to a preferred embodiment of the present invention
  • FIG. 3 a cross sectional view taken through section AA of the component of FIG. 2;
  • FIG. 4 a cross sectional view taken through section BB of the component of FIG. 2.
  • FIG. 1 there is illustrated a torque reducing tubing component, generally indicated by reference numeral 10 , according to a first embodiment of the present invention.
  • the component 10 comprises a generally tubular or cylindrical body 12 having an inner bore (not shown) on a longitudinal axis extending through the length of the component 10 .
  • a conical threaded pin 16 as is known in the art.
  • a box section 20 as is known in the art. Pin 16 and box section 20 are used to attach the component 10 to adjacent sections of a tubing string (not shown).
  • FIG. 1 Also shown in FIG. 1 are raised portions or upsets 22 - 30 .
  • the upsets 22 - 30 are located on the outer surface 32 of the component 10 .
  • Each upset 22 - 30 is located longitudinally on the tubular body 12 and each upset 22 - 30 is arranged circumferentially around the body 12 .
  • the component 10 is of unitary construction being machined from a single piece of steel, as is known in the art for tubing.
  • upsets 22 , 30 are joint stand-off upsets.
  • the joint stand-off upsets 22 , 30 provide a contact bearing surface at each end 14 , 18 of the component 10 . Such a contact surface provides a support at the joint between the end 14 , 18 of the component 10 and adjacent tubing components in the tubing string.
  • Each of the upsets 24 , 26 , 28 are equivalent.
  • Each upset 24 , 26 , 28 comprises a stand-off upset 34 centrally located the stand-off upset 34 being bounded on each side by an agitator upset 36 , 38 .
  • the stand-off upset 34 has an outside diameter which is greater than any other diameter on the component 10 .
  • the stand-off upsets 34 located on each of the upsets 24 , 26 , 28 will provide the only contact points between the tubing string and bore wall.
  • the reduced contact surface area between the tubing string and the bore wall reduces the friction between the tubing string and the bore wall, and consequently reduced torque is required to rotate the tubing string or to reciprocate the tubing string within the bore.
  • Agitator upsets 36 , 38 bounding the stand-off upset 34 provide a profile on the component 10 which assists in directing fluid around the outside surface 32 of the component 10 .
  • the stand-off upsets 34 and agitator upsets 36 , 38 comprise a smooth outer surface which is parallel to the longitudinal axis of the component 10 and taper to the diameter of the component 10 , thus there are no significant ledges within the tubing component to increase friction between the tubing string and the bore hole wall.
  • FIGS. 2 ( a ), ( b ) and ( c ) of the drawings in which is shown a preferred embodiment of the present invention.
  • the tubing component in the preferred invention is based on a length of drill pipe, this drill pipe component being generally indicated by reference numeral 40 .
  • the drill pipe 40 comprises a tubular body 42 onto which is mounted a number of upsets.
  • FIG. 2( a ) shows an upper section of the drill pipe component 40 .
  • a box section 20 a onto which is mounted a joint stand-off upset 22 a , as described hereinbefore with reference to FIG. 1.
  • the joint stand-off upset 22 a tapers to the tubular body 12 a .
  • the tubular body 12 a between the box section 20 a and an upset 24 a is length of a drill pipe 42 .
  • Upset 24 a comprises from the upper side an agitator upset 36 a , a stand-off upset 34 a and a further agitator upset 38 a .
  • the outer diameter of the stand-off upset 34 a is greater than both the outside diameter of agitator upsets 36 a , 38 a and the joint stand-off upset 22 a Therefore, when the drill pipe 40 component is installed on the drill string, only the outer surfaces of the stand-off upset 34 a will be in contact with the bore hole wall for this section of the drill pipe component 40 .
  • stand-off upset 34 a includes on its outer surface 44 five longitudinally extending arc grooves 46 .
  • the arc grooves 46 spiral around the tubular body 12 a in a helical pattern.
  • the arc grooves 46 provide 360° coverage on the outer surface 44 of the stand-off upset 34 a.
  • Each arc groove 46 comprises a first leading edge 48 , an arc or cylindrical bed 50 and a first trailing edge 52 .
  • Each edge 48 , 52 connects the cylindrical bed 50 to the outer surface 44 of the stand-off upset 34 a at an edge angle 54 , 56 respectively. This is shown more clearly in FIG. 3, which shows a section through Line A-A of FIG. 2, which is a section through the stand-off upset 34 a.
  • FIG. 3 there is seen the tubular body 12 a , outer surface 44 and a central inner bore 58 .
  • On the outer surface 44 are five arc grooves 46 .
  • Each arc groove comprises a cylindrical bed 50 with a first leading edge 48 and first trailing edge 52 , bounding the bed 50 and connecting the bed 50 to the outer surface 44 .
  • Also illustrated are edge angles 54 , 56 .
  • edge angles 54 , 56 are positive edge angles, being acute. That is edge angles 54 , 56 are both less than 90°.
  • the depth, shape and angle of the arc grooves 46 on the outer surface 44 of the stand-off upset 34 relative to the longitudinal axis direct the flow of the drilling fluid around the stand-off upset 34 at a relatively high velocity in such a way so as to create a film of fluid between the stand-off upset 34 and the bore wall.
  • This has the effect of creating a marine bearing film between the two surfaces, resulting in the reduction of torque and drag co-efficient friction, as well as reduction in wear on the bore wall, when the bore wall is cased.
  • the stand-off upset 34 a is bounded by agitator upsets 36 a , 38 a .
  • Each agitator upset 36 a , 38 a has a smaller outer diameter than the stand-off upset 34 a , and therefore the agitator upsets 36 a , 38 a do not contact the wall of the bore hole when in use.
  • a description of a single agitator upset, 36 a say will now be given, although it will be appreciated that this description is relevant to all agitator upsets within the preferred embodiment shown in FIG. 2.
  • Agitator upset 36 a has an outer surface 60 upon which is located five longitudinally extending arc grooves 62 .
  • Each of the arc grooves 62 spiral around the tubular body 12 a to provide 360° coverage on the outer surface 60 of the agitator upset 36 a .
  • Each arc groove 62 comprises, in the direction of rotation of the drill string, a second leading edge 64 , a notch 66 which is a v-bed of the groove 62 and a second trailing edge 68 .
  • Each edge 64 , 68 connects the notch 66 to the outer surface 60 of the agitator upset 36 at an edge angle 70 , 72 respectively (as will be described hereinafter with reference to FIG. 4).
  • each of the notch grooves 62 taper in width as they spiral upwards towards the second end 18 a of the drill pipe component 40 .
  • FIG. 4 illustrates a sectional view through Line B-B of FIG. 2.
  • This cross sectional view of agitator upset 36 a includes the inner bore 58 of the tubular body 12 a with the outer surface 60 .
  • Each notch groove 62 has a second leading edge 64 and a second trailing edge 68 .
  • Between the edges 64 , 68 is located a notch or v-groove 66 .
  • the v-groove 66 is created by the edge angles 70 , 72 .
  • Edge angle 70 is a positive or acute angle, being less than 90°
  • edge angle 72 is an obtuse angle, being greater than or equal to 90°.
  • the relationship between the leading edge 64 and the trailing edge 68 of the notch grooves 62 of the agitator upsets 36 causes the creation of differential pressure zones. These differential pressure zones serve to attract drill cuttings away from the well bore wall and into the mainstream flow of the drilling fluid, therefore resulting in a more effective conveyance of the drill cuttings to the surface. This is achieved as the drill pipe component 40 is rotated within a well bore, in conjunction with the drill string, it forms a hydra-mechanical agitation means to move fluid within the well bore.
  • FIGS. 2 ( b ) and 2 ( c ) are substantially identical to the upset 24 a shown in FIG. 2( a ) and described hereinbefore.
  • FIG. 2( c ) it is seen that at the lower or first end 14 a of the drill pipe component 40 there is a conical threaded pin 16 a for connecting the drill pipe component 40 to adjacent drill pipe lengths within the drill string.
  • a joint stand-off upset 30 a Located at the end 14 a of the drill pipe component 40 is a joint stand-off upset 30 a, which is similar in description to the joint stand-off 22 a , discussed previously.
  • Joint stand-offs 22 a , 30 a are manufactured by machining small spiral grooves around the outer surface, so as, in use, they reduce interference with the annulus flow cross sectional area at the ends 14 a , 18 a of the drill pipe component 40 .
  • joint stand-offs 22 a and 30 a are formed integrally with the drill pipe component 40 .
  • they could be made of chromium carbide or the like laid over the outer circumference of the ends 14 a , 18 a.
  • the drill pipe component 40 of the preferred embodiment has a length approximately equal to the length of a single joint of drill pipe.
  • the present invention differs from conventional arrangements of upset tubular designs in so far as it incorporates hydra-mechanical spirally profiled agitator zones on both ends of each stand-off upset, therefore resulting in a longer agitator zone(s) compared with conventional arrangements, yet ensuring zero contact between the agitator zones and the well bore wall.
  • This unique feature makes the present invention a very effective tool for cuttings bed agitation at low circulation pressure drilling environment, whether in rotary or sliding (reciprocating) drilling modes.
  • a principal advantage of the present invention is therefore that it provides a tubing component which provides a hydra-mechanical means of agitating the cuttings bed in a well bore, and so inherently has the effect of improving the drilling fluid circulation when drilling a bore hole.
  • a further advantage of the present invention is that it reduces the rotational friction surface area of a tubing string, therefore reducing the torque required to rotate the tubing string.
  • the present invention also has the advantage that it is a robust, fail safe, mechanical, stand-off element that forms part of a tubing string, thereby minimising the rotational contact between the tubing string and the bore wall, such a stand-off reduces the downhole torque and drag and also prevents damage or wear to a drill string and a cased section of a well bore if in place.
  • tubing component may equally be formed from a section of casing, thus the stand-off upsets would reduce friction as the casing is run into the bore hole, while the agitator upsets would provide efficient mixing and agitation of the cement during cementing of the casing.
  • the features of the tubing component could be adapted onto a short collar, a short drill pipe and/or a short sub.

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  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Mechanical Engineering (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Earth Drilling (AREA)
US10/451,197 2000-12-19 2001-11-29 Torque reducing tubing component Abandoned US20040060699A1 (en)

Applications Claiming Priority (5)

Application Number Priority Date Filing Date Title
GB0031010A GB0031010D0 (en) 2000-12-19 2000-12-19 Torque reducing drillpipe
GB0031010.2 2000-12-19
GB0110504A GB2370297A (en) 2000-12-19 2001-04-30 Tubing component
GB0110504.8 2001-04-30
PCT/GB2001/005280 WO2002050397A1 (fr) 2000-12-19 2001-11-29 Composant de tubage reducteur de couple

Publications (1)

Publication Number Publication Date
US20040060699A1 true US20040060699A1 (en) 2004-04-01

Family

ID=26245449

Family Applications (1)

Application Number Title Priority Date Filing Date
US10/451,197 Abandoned US20040060699A1 (en) 2000-12-19 2001-11-29 Torque reducing tubing component

Country Status (5)

Country Link
US (1) US20040060699A1 (fr)
EP (1) EP1350004A1 (fr)
AU (1) AU2002220848A1 (fr)
CA (1) CA2428557A1 (fr)
WO (1) WO2002050397A1 (fr)

Cited By (9)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20050045386A1 (en) * 2002-02-20 2005-03-03 Appleton Robert Patrick Drill string member
FR2927936A1 (fr) * 2008-02-21 2009-08-28 Vam Drilling France Soc Par Ac Element de garniture de forage, tige de forage et train de tiges de forage correspondant
US20130126244A1 (en) * 2011-11-21 2013-05-23 Sheldon Hansen Ball and socket roller reamer and keyseat wiper
US20130199858A1 (en) * 2011-11-21 2013-08-08 Sheldon Hansen Keyseat Wiper
US8955621B1 (en) * 2011-08-09 2015-02-17 Turboflex, Inc. Grooved drill string components and drilling methods
US9297410B2 (en) 2012-12-31 2016-03-29 Smith International, Inc. Bearing assembly for a drilling tool
US20160237764A1 (en) * 2013-10-25 2016-08-18 National Oilwell Varco, L.P. Downhole hole cleaning joints and method of using same
US20160290067A1 (en) * 2015-04-01 2016-10-06 Nov Downhole Eurasia Limited Component of bottom hole assembly having upwardly-directed fluid cleaning flow and methods of using same
WO2017091241A1 (fr) * 2015-11-23 2017-06-01 COT Acquisition, LLC Aléseur à rouleau

Families Citing this family (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
FR2835014B1 (fr) * 2002-01-18 2004-07-16 Smf Internat Element profile pour un equipement de forage rotatif et tige de forage comportant au moins un element profile
GB2522077A (en) * 2014-01-14 2015-07-15 Paradigm Drilling Services Ltd Casing torque reduction

Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4715454A (en) * 1986-06-03 1987-12-29 Teng Chuan C Mechanical directional drilling jar with swivel means
US5148876A (en) * 1991-06-10 1992-09-22 Prideco, Inc. Lightweight drill pipe
US6227291B1 (en) * 1998-02-24 2001-05-08 Specialised Petroleum Services Limited Compact well clean up tool with multifunction cleaning apparatus
US6666267B1 (en) * 1997-11-15 2003-12-23 Brunel Oilfield Services (Uk) Limited Downhole tools

Family Cites Families (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB9617819D0 (en) * 1996-08-27 1996-10-09 Aitken William R S A drill pipe
FR2760783B1 (fr) * 1997-03-17 1999-07-30 Smf Int Element d'un train de tiges de forage rotatif
FR2789438B1 (fr) * 1999-02-05 2001-05-04 Smf Internat Element profile pour un equipement de forage rotatif et tige de forage comportant au moins un troncon profile

Patent Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4715454A (en) * 1986-06-03 1987-12-29 Teng Chuan C Mechanical directional drilling jar with swivel means
US5148876A (en) * 1991-06-10 1992-09-22 Prideco, Inc. Lightweight drill pipe
US6666267B1 (en) * 1997-11-15 2003-12-23 Brunel Oilfield Services (Uk) Limited Downhole tools
US6227291B1 (en) * 1998-02-24 2001-05-08 Specialised Petroleum Services Limited Compact well clean up tool with multifunction cleaning apparatus

Cited By (18)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US7174958B2 (en) * 2002-02-20 2007-02-13 Robert Patrick Appleton Drill string member
US20050045386A1 (en) * 2002-02-20 2005-03-03 Appleton Robert Patrick Drill string member
EA018849B1 (ru) * 2008-02-21 2013-11-29 Вам Дриллинг Франс Элемент бурового снаряда, бурильная труба и соответствующая колонна бурильных труб
FR2927936A1 (fr) * 2008-02-21 2009-08-28 Vam Drilling France Soc Par Ac Element de garniture de forage, tige de forage et train de tiges de forage correspondant
FR2927937A1 (fr) * 2008-02-21 2009-08-28 Vam Drilling France Soc Par Ac Element de garniture de forage, tige de forage et train de tiges de forage correspondant
WO2009115687A1 (fr) * 2008-02-21 2009-09-24 Vam Drilling France Element de garniture de forage, tige de forage et train de tiges de forage correspondant
US20100326738A1 (en) * 2008-02-21 2010-12-30 Vam Drilling France Drill packer member, drill pipe, and corresponding drill pipe string
CN101946056A (zh) * 2008-02-21 2011-01-12 瓦姆钻杆钻具法国公司 钻具构件、钻杆和相应的钻杆列组
US8434570B2 (en) 2008-02-21 2013-05-07 Vam Drilling France Drill packer member, drill pipe, and corresponding drill pipe string
US8955621B1 (en) * 2011-08-09 2015-02-17 Turboflex, Inc. Grooved drill string components and drilling methods
US20130126244A1 (en) * 2011-11-21 2013-05-23 Sheldon Hansen Ball and socket roller reamer and keyseat wiper
US20130199858A1 (en) * 2011-11-21 2013-08-08 Sheldon Hansen Keyseat Wiper
US9297208B2 (en) * 2011-11-21 2016-03-29 Utah Valley University Ball and socket roller reamer and keyseat wiper
US9297410B2 (en) 2012-12-31 2016-03-29 Smith International, Inc. Bearing assembly for a drilling tool
US20160237764A1 (en) * 2013-10-25 2016-08-18 National Oilwell Varco, L.P. Downhole hole cleaning joints and method of using same
US11047180B2 (en) * 2013-10-25 2021-06-29 National Oilwell Varco, L.P. Downhole hole cleaning joints and method of using same
US20160290067A1 (en) * 2015-04-01 2016-10-06 Nov Downhole Eurasia Limited Component of bottom hole assembly having upwardly-directed fluid cleaning flow and methods of using same
WO2017091241A1 (fr) * 2015-11-23 2017-06-01 COT Acquisition, LLC Aléseur à rouleau

Also Published As

Publication number Publication date
EP1350004A1 (fr) 2003-10-08
AU2002220848A1 (en) 2002-07-01
CA2428557A1 (fr) 2002-06-27
WO2002050397A1 (fr) 2002-06-27

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AS Assignment

Owner name: WEATHERFORD/LAMB, INC., TEXAS

Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNOR:RASTEGAR, GHOLAM;REEL/FRAME:014642/0996

Effective date: 20030513

STCB Information on status: application discontinuation

Free format text: ABANDONED -- FAILURE TO RESPOND TO AN OFFICE ACTION