WO2002050397A1 - Composant de tubage reducteur de couple - Google Patents

Composant de tubage reducteur de couple Download PDF

Info

Publication number
WO2002050397A1
WO2002050397A1 PCT/GB2001/005280 GB0105280W WO0250397A1 WO 2002050397 A1 WO2002050397 A1 WO 2002050397A1 GB 0105280 W GB0105280 W GB 0105280W WO 0250397 A1 WO0250397 A1 WO 0250397A1
Authority
WO
WIPO (PCT)
Prior art keywords
component
upsets
stand
tubing string
upset
Prior art date
Application number
PCT/GB2001/005280
Other languages
English (en)
Inventor
Gholam Rastegar
Original Assignee
Weatherford/Lamb, Inc.
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 Weatherford/Lamb, Inc. filed Critical Weatherford/Lamb, Inc.
Priority to AU2002220848A priority Critical patent/AU2002220848A1/en
Priority to EP01271099A priority patent/EP1350004A1/fr
Priority to CA002428557A priority patent/CA2428557A1/fr
Priority to US10/451,197 priority patent/US20040060699A1/en
Publication of WO2002050397A1 publication Critical patent/WO2002050397A1/fr

Links

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.
  • 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 m imise 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 component may be of unitary construction.
  • 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.
  • the agitator upsets do not contact the wall of the bore hole when in use.
  • 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.
  • first and second ends comprise threaded pin and box connections respectively as are known in the art.
  • connections include joint standoff upsets.
  • the joint stand-off upsets may have a smaller outer diameter than the standoff 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.
  • a method of circulating fluid in a bore hole comprising the steps of: (a) inserting a tubing string into the bore hole, the tubing string including a torque reducing tubing component;
  • 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.
  • Figure 1 a side view of a torque reducing tubing component in accordance with a first embodiment of the present invention
  • Figures 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
  • Figure 3 a cross sectional view taken through section AA of the component of Figure 2;
  • FIG 4 a cross sectional view taken through section BB of the component of Figure 2.
  • 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).
  • 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 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. As shown in Figure 1, 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.
  • 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. Like parts to those of the embodiment of Figure 1 have been given the same reference numeral but are now suffixed "a".
  • 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 20a onto which is mounted a joint stand-off upset 22a tapers to the tubular body 12a.
  • the tubular body 12a between the box section 20a and an upset 24a is length of a drill pipe 42.
  • Upset 24a comprises from the upper side an agitator upset 36a, a stand-off upset 34a and a further agitator upset 38 a.
  • the outer diameter of the stand-off upset 34a is greater than both the outside diameter of agitator upsets 36a, 38a and the joint stand-off upset 22a. Therefore, when the drill pipe 40 component is installed on the drill string, only the outer surfaces of the stand-off upset 34a will be in contact with the bore hole wall for this section of the drill pipe component 40.
  • stand-off upset 34a includes on its outer surface 44 five longitudinally extending arc grooves 46.
  • the arc grooves 46 spiral around the tubular body 12a in a helical pattern.
  • the arc grooves 46 provide 360° coverage on the outer surface 44 of the stand-off upset 34a.
  • 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 34a at an edge angle 54, 56 respectively.
  • Figure 3 shows a section through Line A-A of Figure 2, which is a section through the stand-off upset 34a.
  • the tubular body 12a 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.
  • 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 34a is bounded by agitator upsets 36a, 38a.
  • Each agitator upset 36a, 38a has a smaller outer diameter than the stand-off upset 34a, and therefore the agitator upsets 36a, 38a do not contact the wall of the bore hole when in use.
  • a description of a single agitator upset, 36a 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 Figure 2.
  • Agitator upset 36a 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 12a to provide 360° coverage on the outer surface 60 of the agitator upset 36a.
  • 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 Figure 4).
  • each of the notch grooves 62 taper in width as they spiral upwards towards the second end 18a of the drill pipe component 40.
  • FIG. 4 illustrates a sectional view through Line B-B of Figure 2.
  • This cross sectional view of agitator upset 36a includes the inner bore 58 of the tubular body 12a 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°, while 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.
  • Joint stand-offs 22a, 30a 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 14a, 18a of the drill pipe component 40.
  • joint stand-offs 22a and 30a 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 14a, 18a.
  • 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)

Abstract

L'invention concerne un composant de tubage réducteur de couple destiné à être inséré dans une colonne de production utilisée dans un trou de forage. Des refoulements (22, 24, 26, 28, 30) sont disposés sur la surface extérieure dudit composant et permettent de limiter le contact entre la colonne de production et la paroi du trou de forage, d'où une réduction du frottement entre la colonne de production et la paroi du trou de forage. Des rainures (46) ménagées sur les refoulements agissent de façon à canaliser le fluide autour des refoulements, ce qui permet de former un palier fluide pelliculaire entre les points de contact de la colonne de production et de la paroi du trou de forage. Un différentiel de pression créé autour des refoulements attire le fluide dans le sens opposé à la paroi du trou de forage, d'où une amélioration de la circulation de fluide vers la surface. L'invention se rapporte notamment à un composant de tubage réducteur de couple utilisé dans un train de tiges de forage et facilitant l'extraction des déblais de forage.
PCT/GB2001/005280 2000-12-19 2001-11-29 Composant de tubage reducteur de couple WO2002050397A1 (fr)

Priority Applications (4)

Application Number Priority Date Filing Date Title
AU2002220848A AU2002220848A1 (en) 2000-12-19 2001-11-29 Torque reducing tubing component
EP01271099A EP1350004A1 (fr) 2000-12-19 2001-11-29 Composant de tubage reducteur de couple
CA002428557A CA2428557A1 (fr) 2000-12-19 2001-11-29 Composant de tubage reducteur de couple
US10/451,197 US20040060699A1 (en) 2000-12-19 2001-11-29 Torque reducing tubing component

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
GB0031010.2 2000-12-19
GB0031010A GB0031010D0 (en) 2000-12-19 2000-12-19 Torque reducing drillpipe
GB0110504.8 2001-04-30
GB0110504A GB2370297A (en) 2000-12-19 2001-04-30 Tubing component

Publications (1)

Publication Number Publication Date
WO2002050397A1 true WO2002050397A1 (fr) 2002-06-27

Family

ID=26245449

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/GB2001/005280 WO2002050397A1 (fr) 2000-12-19 2001-11-29 Composant de tubage reducteur de couple

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 (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP1329586A1 (fr) * 2002-01-18 2003-07-23 S.M.F. International Elément profilé pour un équipement de forage rotatif
GB2522077A (en) * 2014-01-14 2015-07-15 Paradigm Drilling Services Ltd Casing torque reduction

Families Citing this family (9)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB0203956D0 (en) * 2002-02-20 2002-04-03 Appleton Robert P Drill string member
FR2927936B1 (fr) * 2008-02-21 2010-03-26 Vam Drilling France Element de garniture de forage, tige de forage et train de tiges de forage correspondant
US8955621B1 (en) * 2011-08-09 2015-02-17 Turboflex, Inc. Grooved drill string components and drilling methods
US9297208B2 (en) * 2011-11-21 2016-03-29 Utah Valley University Ball and socket roller reamer and keyseat wiper
US20130199858A1 (en) * 2011-11-21 2013-08-08 Sheldon Hansen Keyseat Wiper
US9297410B2 (en) 2012-12-31 2016-03-29 Smith International, Inc. Bearing assembly for a drilling tool
CA2928535C (fr) * 2013-10-25 2020-11-24 National Oilwell Varco, L.P. Raccords de nettoyage de trou pour fond de trou et leurs procedes d'utilisation
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

Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO1998009046A1 (fr) * 1996-08-27 1998-03-05 Schoeller Bleckmann Oilfield Equipment Limited Tige de sondage
US6056073A (en) * 1997-03-17 2000-05-02 S.M.F. International Element of a rotating drill pipe string
EP1026364A1 (fr) * 1999-02-05 2000-08-09 S.M.F. International Elément profilé pour un équipement de forage rotatif et tige de forage comportant au moins un tronçon profilé

Family Cites Families (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
GB9724194D0 (en) * 1997-11-15 1998-01-14 Brunel Oilfield Serv Uk Ltd Improvements in or relating to downhole tools
GB9803824D0 (en) * 1998-02-24 1998-04-22 Specialised Petroleum Serv Ltd Compact well clean-up tool with multi-functional cleaning apparatus

Patent Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO1998009046A1 (fr) * 1996-08-27 1998-03-05 Schoeller Bleckmann Oilfield Equipment Limited Tige de sondage
US6056073A (en) * 1997-03-17 2000-05-02 S.M.F. International Element of a rotating drill pipe string
EP1026364A1 (fr) * 1999-02-05 2000-08-09 S.M.F. International Elément profilé pour un équipement de forage rotatif et tige de forage comportant au moins un tronçon profilé

Cited By (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP1329586A1 (fr) * 2002-01-18 2003-07-23 S.M.F. International Elément profilé pour un équipement de forage rotatif
FR2835014A1 (fr) * 2002-01-18 2003-07-25 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

Also Published As

Publication number Publication date
AU2002220848A1 (en) 2002-07-01
EP1350004A1 (fr) 2003-10-08
CA2428557A1 (fr) 2002-06-27
US20040060699A1 (en) 2004-04-01

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