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WO2002036924A2 - Outil de forage rotatif orientable - Google Patents

Outil de forage rotatif orientable Download PDF

Info

Publication number
WO2002036924A2
WO2002036924A2 PCT/CA2001/001542 CA0101542W WO0236924A2 WO 2002036924 A2 WO2002036924 A2 WO 2002036924A2 CA 0101542 W CA0101542 W CA 0101542W WO 0236924 A2 WO0236924 A2 WO 0236924A2
Authority
WO
WIPO (PCT)
Prior art keywords
mandrel
housing
piston
drill string
offset
Prior art date
Application number
PCT/CA2001/001542
Other languages
English (en)
Other versions
WO2002036924A3 (fr
Inventor
Paul Noe
David P Kutinsky
Original Assignee
Canadian Downhole Drill Systems 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 CA2345560A external-priority patent/CA2345560C/fr
Application filed by Canadian Downhole Drill Systems Inc. filed Critical Canadian Downhole Drill Systems Inc.
Priority to AU2002213719A priority Critical patent/AU2002213719A1/en
Publication of WO2002036924A2 publication Critical patent/WO2002036924A2/fr
Publication of WO2002036924A3 publication Critical patent/WO2002036924A3/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
    • E21B17/1014—Flexible or expansible centering means, e.g. with pistons pressing against the wall of the well
    • 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
    • E21B7/00—Special methods or apparatus for drilling
    • E21B7/04—Directional drilling
    • E21B7/06—Deflecting the direction of boreholes
    • E21B7/062—Deflecting the direction of boreholes the tool shaft rotating inside a non-rotating guide travelling with the shaft
    • 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
    • E21B7/00—Special methods or apparatus for drilling
    • E21B7/04—Directional drilling
    • E21B7/06—Deflecting the direction of boreholes
    • E21B7/067—Deflecting the direction of boreholes with means for locking sections of a pipe or of a guide for a shaft in angular relation, e.g. adjustable bent sub

Definitions

  • the invention relates to rotary drilling, and more particularly, to steered directional drilling with a rotary drilling tool.
  • This invention is directed towards a tool that permits steered directional drilling with a rotary drilling tool.
  • the device contemplated provides a method for positioning the drill bit in a drilling operation to achieve small changes in hole angle or azimuth as drilling proceeds.
  • Two different positions are available to the operator. The first is a straight ahead position where the tool essentially becomes a packed hole stabilizer assembly. The second position tilts the bit across a rotating fulcrum to give a calculated offset at the bit-formation interface.
  • the direction that the bit offset is applied in relation to current hole direction is controlled by positioning the orienting pistons prior to each drilling cycle, through the use of current measurement-while-drilling (MWD) technology.
  • MWD current measurement-while-drilling
  • components of the tool comprise a MWD housing, upper steering and drive mandrel, non-rotating position housing, lower drive mandrel splined with the upper mandrel, rotating fulcrum stabilizer and drill bit.
  • the rig pumps are activated.
  • the pressure differential created by the bit jets below the tool will cause pistons to open from the ED of the tool into the tool chamber.
  • the pistons open they will contact wings that come out into the path of travel of the upper mandrel as it comes down a spline, and bottoms out on the lower drive mandrel. This occurs as the drill string is being lowered to bottom.
  • the extra length provided by the open wings moves a sliding sleeve centered over, but not attached to the upper mandrel, to a new position that in turn forces the orienting pistons to extend out into the borehole annulus.
  • the tool will be picked up off bottom, and as the upper mandrel moves upward on the spline in the lower mandrel, a spring pushes the sliding sleeve back into its normal position, the orienting pistons retract into the outer housing, and the centering pistons come back out into the borehole annulus, thus returning the tool to its normal stabilized position. This cycle may be repeated until the desired result is achieved.
  • the following procedure may be implemented to drill straight ahead. After making a connection and surveying, slowly lower the drill string to bottom and set a small amount of weight on the bit. Then engage the rig pumps. This time, when the activation pistons from the ID attempt to open the wings, they will be behind the sliding sleeve assembly, and the sliding sleeve will remain in its normal or centered position throughout the following drilling cycle.
  • Skillful alternating of the two above drilling positions will yield a borehole of minimum tortuosity, when compared to conventional steerable methods.
  • FIGURE 1 is a side view of a drill string with rotary steerable tool according to the invention
  • FIGURES 2A-2D are lengthwise connected sections (with some overlap) through a rotary steerable tool according to the invention showing the tool in pulled back position ready to extend the wings used to move the pistons into the offset drilling position;
  • FIGURE 3 is a cross section along section line 3-3 in FIGURE 2C;
  • FIGURE 4 is a cross section along section line 4-4 in FIGURES 2C and 8C
  • FIGURE 5 is a cross section along section line 5-5 in FIGURES 2C and 8C
  • FIGURE 6 is a cross section along section line 6-6 in FIGURES 2C and 8C
  • FIGURE 7 is a cross section along section line 7-7 in FIGURES 2B and 8B
  • FIGURES 8A-8D are lengthwise connected sections (with some overlap) through a rotary steerable tool according to the invention showing the tool in straight ahead drilling position
  • FIGURE 9 is a cross section along section line 9-9 in FIGURE 8C;
  • FIGURE 10 is a lengthwise section through a rotary steerable tool according to the invention showing the tool in offset drilling position;
  • FIGURE 11 is a cross section along section line 11-11 in FIGURE 10
  • FIGURE 12 is a cross section along section line 12-12 in FIGURE 10
  • FIGURE 13 is a cross section along section line 13-13 in FIGURE 10
  • FIGURE 14 is a cross section along section line 14-14 in FIGURE 10
  • FIGURE 15 is a perspective view of a rotary steerable tool according to the invention showing wings in the extended position with the housing partly broken away to show the mandrel
  • FIGURE 16 is a perspective view of a rotary steerable tool according to the invention with the housing broken away to show wings in the retracted position;
  • FIGURE 17 is a close-up view of mating dog clutch faces for use in orienting the rotary steerable tool according to the invention.
  • FIGURE 18 is an end view of a rotary steerable tool according to the invention showing pistons set in the offset drilling position
  • FIGURE 19 is an end view of a rotary steerable tool according to the invention showing pistons set in the straight ahead drilling position.
  • a rotary steerable drilling tool 10 is shown located on a conventional drill string 12 between a conventional MWD tool 14 and a conventional drill bit 16.
  • rotary steerable drilling tool 10 includes a mandrel 20 having a conventional box connection 22 at an uphole end for connection into drill string 12 and a conventional box connection 24 at a downhole end for connection to a pin connection 26 of a drilling sub 28.
  • Sub 28 is configured as a rotating stabilizer 17 provided on the drill string between rotary steerable drilling tool 10 and drill bit 16, and operates as a fulcrum for rotary steerable drilling tool 10 and drill bit 16 to pivot around.
  • Drill bit 16 will conventionally have jets in the bit for egress of fluid from the drill string.
  • a conventional rig will include conventional pumps (not shown) for pumping fluid down drill string 12 to drill bit 16 and out the jets in the drill bit.
  • FIGURES 2A-2D show the tool in the pulled back off-bottom position, ready to set the tool into either a straight ahead drilling position or an offset drilling position.
  • FIGURES 3-7 are sections corresponding to the section lines on FIGURES 2A-2D.
  • FIGURES 15-19 provide perspective views of the tool broken away to show the internal workings.
  • FIGURES 3-7 are sections corresponding to the section lines on FIGURES 2A-2D.
  • FIGURES 8A-8D show rotary steerable drilling tool 10 in a straight ahead on-bottom drilling position.
  • FIGURE 9 is a section corresponding to the section line 9-9 on FIGURE 8C.
  • FIGURE 8A-8D correspond to FIGURES 4-7 as well, since the sections do not change in those positions.
  • FIGURE 10 shows rotary steerable drilling tool 10 in position for offset drilling, insofar as it is different from the position shown in FIGURES 8A-8D.
  • FIGURES 11-14 are sections corresponding to the section lines on FIGURE 10. Referring to FIGURES 2A-2D, 3-7, 8A-8D, and 15-19, and particularly to
  • a bore 30 is provided within mandrel 20 for communication of fluid from surface to drill bit 16.
  • a housing 32 is mounted on mandrel 20 for rotation in relation to mandrel 20. During drilling, housing 32 is held against rotation by frictional engagement with the wellbore and the mandrel rotates, typically at about 120 rpm. Housing 32 ' is provided with an adjustable offset mechanism that can be adjusted from the surface so that rotary steerable drilling tool 10 can be operated in and changed between a straight ahead drilling position and an offset drilling position. In the straight ahead drilling position, asymmetry of housing 32, namely thickening 33 of housing 32 on one side, in combination with pistons on the other side of housing 32 yields a tool that is centered in the hole.
  • pistons on the thickened side of housing 32 drive tool 10 to one side of the wellbore, and thus provide a stationary fulcrum in which mandrel 20 rotates to force the drill bit in a chosen direction.
  • Three hole grippers 15 are provided on the exterior surface of housing 32 downhole of thickened section 33. One of hole grippers 15 is on the opposite side of the thickened section, and the other two are at about 90 degrees to thickened section 33. Hole grippers 15 are oriented such that when rotary steerable tool 10 is offset in the hole by 1/2 degree by operation of the adjustable offset mechanism described below, hole grippers 15 will lie parallel to the hole wall, so that hole grippers 15 make maximum contact with the hole wall.
  • Hole grippers 15 grip the wall of the hole and prevent housing 32 from rotating, as well as preventing premature wear of housing 32 against the wellbore.
  • Housing 32 has threaded on its uphole end an end cap 34 holding a piston 36, and on its downhole end another end cap 40 holding a floating piston seal 42 within chamber 44.
  • Floating piston 42 accommodates pressure changes caused by movement of the housing on mandrel 20.
  • Housing 32 rotates on mandrel 20 on seven bearings 46.
  • Mandrel 20 is formed from an upper mandrel 50 and lower mandrel 52 connected by splines 54.
  • a sleeve 55 is held in the bore of lower mandrel 52, and in the downhole end of upper mandrel 50, by a pin on sub 28.
  • Appropriate seals are provided as shown to prevent fluid from the mandrel bore from entering between the upper mandrel 50 and lower mandrel 52 at 57. Downhole movement of upper mandrel 50 in lower mandrel 52 is limited by respective shoulders 59 and 61. Housing 32 is supported on lower mandrel 52 by thrust bearings 56 on either side of a shoulder 58 on lower mandrel 52.
  • the adjustable offset mechanism may for example be formed using plural pistons 60, 62 and 64 radially mounted in openings in housing 32.
  • Pistons 60 and 62 are mounted in openings on thickened side 33 of the sleeve, while pistons 64 are mounted on the opposed side. Thickened side 33 has a larger radius than the opposed side, and pistons 64 are extendable outward to that radius.
  • Pistons 62 are at 120 degrees on either side of piston 60 and extend outward at their maximum extension less than the extension of piston 60 when measured from the center of mandrel 50. Pistons 60 and 62 extend outward to a radius of a circle that is centered on a point offset from the center of mandrel 50, as shown in FIGURE 18.
  • hole grippers 65 are also embedded on either side of housing 32 at 90 degrees to piston 60.
  • Hole grippers 65 are about 5 inches long, and are oriented, as with hole grippers 15, so that one edge lies furthest outward.
  • hole grippers 65 assist in preventing housing 32 from rotating by engaging the hole wall with their outermost edge.
  • Hole grippers 15 and 65 should be made of a suitably hard material, and may, for example, be power tong dies since these are readily available and may be easily removed for replacement.
  • Pistons 60, 62 and 64 should also be made of a similar hard material.
  • Pistons 60, 62 and 64 are radially adjustable by actuation of mandrel 20 as follows.
  • Dog clutch 66 is pinned by pins 68 to mandrel 32 to form a chamber 70 between housing 32 and upper mandrel 50.
  • Dog clutch 66 has a dog face 67 that bears against dog face 69 on end cap 34 when upper mandrel 50 is raised in the hole.
  • Wings 72 secured on pins 76 in the upper mandrel 50 are operable by fluid pressure in bore 30 of upper mandrel 50 through opening 74. Fluid pressure in bore 30 urges pistons 71 radially outward and causes wings 72 to swing outward on pins 76 into chamber 70.
  • the piston actuation mechanism includes thrust bearing 86 held between collars 84 and 88, cam sleeve 90 and spring 92, all mounted in that order on mandrel 32.
  • Cam sleeve 90 is mounted over a brass bearing sleeve 91 that provides a bearing surface for cam sleeve 90.
  • Spring 92 provides a sufficient force, for example 1200 lbs, to force cam sleeve 90 uphole to its uphole limit determined by the length of sleeve 78, yet not so great that downhole pressure on upper mandrel 50 cannot overcome spring 92.
  • Spring 92 may be held in place by screws in holes 93 after spring 92 is compressed into position during manufacture, and then the screws can be removed and holes 93 sealed, after the remaining parts are in place.
  • Cam sleeve 90 is provided with an annular ramped depression in its central portion 94 and thickens uphole to cam surface 96 and downhole to cam surface 98, with greater thickening uphole.
  • Piston 60 is offset uphole from pistons 64 by an amount L, for example 3-1/2 inches.
  • Cam surface 96 is long enough and spaced from the center of depression 94 sufficiently, that when cam sleeve 90 moves a distance L downward to the position shown in FIGURE 10, piston 60 rides on cam surface 96, while pistons 64 ride in the center of depression 94.
  • Cam surface 98 is long enough and spaced from the center of depression 94 sufficiently, that when cam sleeve 90 is urged uphole by spring 92 to the position shown in FIGURE 2C or 8C, pistons 64 ride on cam surface 98, while piston 60 rides in the center of depression 94.
  • cam sleeve 90 is forced downhole in relation to housing 32, pistons 60 ride on uphole cam surface 96, and are pressed outward into the well bore beyond the outer diameter of housing 32, while pistons 64 may retract into annular depression 94.
  • pistons 60 are in annular depression 94, while pistons 64 ride on downhole cam surface 98.
  • Pistons 62 will also ride on cam sleeve 90, but are slightly offset downhole from piston 60 and so do not extend as far outward. Since cam surface 98 has a smaller diameter than cam surface 96, the tool may move more readily in the hole when pistons 64 are extended for the straight ahead drilling position, and piston 64 and housing 32 act as a stabilizer.
  • the stabilizer position or straight ahead drilling position of the pistons is shown in the end view FIGURE 19 and the cross sections of FIGURES 5 and 6.
  • the offset drilling position of the pistons is shown in the end view of FIGURE 18 and the cross sections of FIGURES 12-14.
  • An orientation system is also provided on rotary steerable drilling tool 10.
  • a sensor 102 for example a magnetic switch, is set in an opening in upper mandrel 50.
  • a trigger 104 for example a magnet, is set in end cap 34 at a location where trigger 104 will trip sensor 102 when mandrel 20 rotates in an on-bottom drilling position (either offset or straight). Snap ring 105 should be non-magnetic.
  • a further sensor 106 is set in upper mandrel 50 at a distance below sensor 102 about equal to the amount upper mandrel 50 is pulled back as shown in FIGURES 2A-2D, which will be slightly greater than the distance L, for example 4 inches when L is 3 1/2 inches.
  • Trigger 104 will therefore trip sensor 106 when mandrel 20 is pulled back and jaw clutch faces 67, 69 are engaged. This position allows the tool to be oriented with the MWD tool face.
  • Sensors 104 and 106 communicate through a communication link, e.g. a conductor, in channel 105 with a MWD package in MWD tool 14.
  • Sensors 102 and 106 are thus sensitive to the rotary orientation of housing 32 in relation to mandrel 20, and when trigger 104 trips one of sensors 102, 106, sends a signal to the MWD tool 14 that is indicative of the rotary orientation of housing 32 on mandrel 20.
  • rotary steerable drilling tool 10 For drilling in the offset position, rotary steerable drilling tool 10 is altered in position as shown in FIGURES 10-14. Upper mandrel 50 is lifted off lower mandrel 52 until dog face 67 engages dog face 69, and rotated at least 360 degrees to ensure engagement of faces 67 and 69. The orientation of housing 32 in the hole can then be determined by MWD tool 14 if the engaging position of dog faces 67, 69 is programmed in the MWD package. Housing 32 may then be rotated from surface using mandrel 20 into the desired direction of drilling in the offset drilling position.
  • the drilling direction will conveniently coincide with the direction that piston 60 points.
  • dog faces 67, 69 engaged fluid pressure is applied from surface to bore 30 of mandrel 20 to force wings 72 into a radially extended position.
  • Mandrel 20 or more specifically upper mandrel 50, since lower mandrel 52 does not move in this operation, is then moved downward.
  • wings 72 drive cam sleeve 90 downward and lift piston 60 onto cam surface 96, thus extending piston 60 outward, while piston 64 moves into annular depression 94.
  • the action of piston 60 bearing against the wellbore places rotary steerable tool 10 in an offset drilling position using rotary stabilizer 17 as a rotating fulcrum.
  • the ratio of the offset caused by pistons 60, 62 to the offset at drill bit 16 is equal to the ratio of the distance of pistons 60, 62 from rotary stabilizer 17 to the distance of drill bit 16 from rotary stabilizer 17.
  • the location of housing 32 may also be determined by rotating mandrel 20 in housing 32 and taking readings from sensors 106.
  • the timing of the readings from sensor 106 may be used by the MWD package to indicate the location of housing 32.

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  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (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)
  • Mechanical Engineering (AREA)
  • Earth Drilling (AREA)

Abstract

La présente invention concerne un dispositif permettant de positionner le trépan lors d'une opération de forage de manière à réaliser des petites modifications de l'angle d'un trou ou azimut au fur et à mesure du forage. L'opérateur peut choisir entre deux différentes positions. La première position consiste en une position toute droite dans laquelle l'outil se transforme sensiblement en un train de tiges de forage. La seconde position permet l'inclinaison du trépan d'un côté à l'autre d'un point d'appui pivotant de manière à obtenir une déviation calculée à l'interface entre le trépan et la formation. Le sens de la déviation appliqué au trépan par rapport au sens du trou en cours est commandée par positionnement des pistons d'orientation avant chaque cycle de forage selon la technique courante de mesure de fond pendant le forage (technique MWD). Les éléments constitutifs de l'outil susmentionné sont: un logement MWD, un mandrin supérieur d'entraînement orientable, un logement de positionnement non-rotatif, un mandrin inférieur d'entraînement cannelé avec le mandrin supérieur, un stabilisateur de point d'appui rotatif et un trépan.
PCT/CA2001/001542 2000-11-03 2001-10-31 Outil de forage rotatif orientable WO2002036924A2 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
AU2002213719A AU2002213719A1 (en) 2000-11-03 2001-10-31 Rotary steerable drilling tool and method for directional drilling

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
US24518800P 2000-11-03 2000-11-03
US60/245,188 2000-11-03
CA2345560A CA2345560C (fr) 2000-11-03 2001-04-27 Foreuse rotative orientable
CA2,345,560 2001-04-27

Publications (2)

Publication Number Publication Date
WO2002036924A2 true WO2002036924A2 (fr) 2002-05-10
WO2002036924A3 WO2002036924A3 (fr) 2002-09-26

Family

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Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/CA2001/001542 WO2002036924A2 (fr) 2000-11-03 2001-10-31 Outil de forage rotatif orientable

Country Status (2)

Country Link
AU (1) AU2002213719A1 (fr)
WO (1) WO2002036924A2 (fr)

Cited By (12)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP1514995A1 (fr) * 2003-09-15 2005-03-16 Compagnie Du Sol Installation de forage à tête rotative
WO2009022115A1 (fr) * 2007-08-15 2009-02-19 Schlumberger Technology B.V. Système et procédé pour commander un système de forage pour forer un puits de forage dans une formation géologique
WO2010092314A1 (fr) * 2009-02-13 2010-08-19 Schlumberger Technology B.V. Systèmes et procédé de commande pour l'inhibition temporaire de coupe latérale
US7845430B2 (en) 2007-08-15 2010-12-07 Schlumberger Technology Corporation Compliantly coupled cutting system
US8066085B2 (en) 2007-08-15 2011-11-29 Schlumberger Technology Corporation Stochastic bit noise control
CN102852512A (zh) * 2012-09-11 2013-01-02 西南石油大学 基于随钻测量的钻头粘滑振动监测装置及方法
US8534380B2 (en) 2007-08-15 2013-09-17 Schlumberger Technology Corporation System and method for directional drilling a borehole with a rotary drilling system
CN103703207A (zh) * 2011-05-12 2014-04-02 2Td钻孔有限公司 用于定向钻的装置和方法
US8720604B2 (en) 2007-08-15 2014-05-13 Schlumberger Technology Corporation Method and system for steering a directional drilling system
US8727036B2 (en) 2007-08-15 2014-05-20 Schlumberger Technology Corporation System and method for drilling
US8757294B2 (en) 2007-08-15 2014-06-24 Schlumberger Technology Corporation System and method for controlling a drilling system for drilling a borehole in an earth formation
US8763726B2 (en) 2007-08-15 2014-07-01 Schlumberger Technology Corporation Drill bit gauge pad control

Family Cites Families (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2891769A (en) * 1955-05-02 1959-06-23 Directional Engineering Compan Directional drilling tool
US3298449A (en) * 1963-10-24 1967-01-17 Drilco Oil Tools Inc Well bore apparatus
US3370657A (en) * 1965-10-24 1968-02-27 Trudril Inc Stabilizer and deflecting tool
US5941323A (en) * 1996-09-26 1999-08-24 Bp Amoco Corporation Steerable directional drilling tool
FR2780753B1 (fr) * 1998-07-03 2000-08-25 Inst Francais Du Petrole Dispositif et methode de controle de la trajectoire d'un forage

Cited By (18)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP1514995A1 (fr) * 2003-09-15 2005-03-16 Compagnie Du Sol Installation de forage à tête rotative
FR2859751A1 (fr) * 2003-09-15 2005-03-18 Cie Du Sol Installation de forage a tete rotative
US8534380B2 (en) 2007-08-15 2013-09-17 Schlumberger Technology Corporation System and method for directional drilling a borehole with a rotary drilling system
US8550185B2 (en) 2007-08-15 2013-10-08 Schlumberger Technology Corporation Stochastic bit noise
US7845430B2 (en) 2007-08-15 2010-12-07 Schlumberger Technology Corporation Compliantly coupled cutting system
US7971661B2 (en) 2007-08-15 2011-07-05 Schlumberger Technology Corporation Motor bit system
US8066085B2 (en) 2007-08-15 2011-11-29 Schlumberger Technology Corporation Stochastic bit noise control
US8899352B2 (en) 2007-08-15 2014-12-02 Schlumberger Technology Corporation System and method for drilling
WO2009022115A1 (fr) * 2007-08-15 2009-02-19 Schlumberger Technology B.V. Système et procédé pour commander un système de forage pour forer un puits de forage dans une formation géologique
US8763726B2 (en) 2007-08-15 2014-07-01 Schlumberger Technology Corporation Drill bit gauge pad control
EA019369B1 (ru) * 2007-08-15 2014-03-31 Шлюмбергер Текнолоджи Б.В. Система и способ управления буровой системой для бурения ствола скважины в геологическом пласте
US8757294B2 (en) 2007-08-15 2014-06-24 Schlumberger Technology Corporation System and method for controlling a drilling system for drilling a borehole in an earth formation
US8720605B2 (en) 2007-08-15 2014-05-13 Schlumberger Technology Corporation System for directionally drilling a borehole with a rotary drilling system
US8720604B2 (en) 2007-08-15 2014-05-13 Schlumberger Technology Corporation Method and system for steering a directional drilling system
US8727036B2 (en) 2007-08-15 2014-05-20 Schlumberger Technology Corporation System and method for drilling
WO2010092314A1 (fr) * 2009-02-13 2010-08-19 Schlumberger Technology B.V. Systèmes et procédé de commande pour l'inhibition temporaire de coupe latérale
CN103703207A (zh) * 2011-05-12 2014-04-02 2Td钻孔有限公司 用于定向钻的装置和方法
CN102852512A (zh) * 2012-09-11 2013-01-02 西南石油大学 基于随钻测量的钻头粘滑振动监测装置及方法

Also Published As

Publication number Publication date
WO2002036924A3 (fr) 2002-09-26
AU2002213719A1 (en) 2002-05-15

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