EP1977073B1 - Lenkbares bohrsystem - Google Patents

Lenkbares bohrsystem Download PDF

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Publication number
EP1977073B1
EP1977073B1 EP06765124A EP06765124A EP1977073B1 EP 1977073 B1 EP1977073 B1 EP 1977073B1 EP 06765124 A EP06765124 A EP 06765124A EP 06765124 A EP06765124 A EP 06765124A EP 1977073 B1 EP1977073 B1 EP 1977073B1
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EP
European Patent Office
Prior art keywords
bit
cutter
cutters
drill bit
movable
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.)
Active
Application number
EP06765124A
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English (en)
French (fr)
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EP1977073A1 (de
Inventor
Geoff Downton
Steven Hart
Joachim Sihler
Olivier Sindt
David White
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.)
Services Petroliers Schlumberger SA
Gemalto Terminals Ltd
Schlumberger Oilfield Assistance Ltd Great Britain
Prad Research and Development NV
Schlumberger Technology BV
Schlumberger Holdings Ltd
Original Assignee
Services Petroliers Schlumberger SA
Gemalto Terminals Ltd
Schlumberger Oilfield Assistance Ltd Great Britain
Prad Research and Development NV
Schlumberger Technology BV
Schlumberger Holdings Ltd
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.)
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Application filed by Services Petroliers Schlumberger SA, Gemalto Terminals Ltd, Schlumberger Oilfield Assistance Ltd Great Britain, Prad Research and Development NV, Schlumberger Technology BV, Schlumberger Holdings Ltd filed Critical Services Petroliers Schlumberger SA
Publication of EP1977073A1 publication Critical patent/EP1977073A1/de
Application granted granted Critical
Publication of EP1977073B1 publication Critical patent/EP1977073B1/de
Active 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
    • E21B7/00—Special methods or apparatus for drilling
    • E21B7/04—Directional drilling
    • E21B7/06—Deflecting the direction of boreholes
    • E21B7/064—Deflecting the direction of boreholes specially adapted drill bits therefor
    • 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
    • E21B10/00—Drill bits
    • E21B10/62—Drill bits characterised by parts, e.g. cutting elements, which are detachable or adjustable
    • 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
    • E21B17/1092—Gauge section of drill bits
    • 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
    • E21B7/068—Deflecting the direction of boreholes drilled by a down-hole drilling motor

Definitions

  • This invention relates to a drilling system for use in the formation of boreholes, for example for the subsequent extraction of oil or natural gas.
  • the invention relates, in particular, to a system which is capable of being steered so as to allow the path followed, during formation of the borehole, to be controlled.
  • a number of steerable drilling systems are known.
  • One such system comprises a bias unit connected to a drill bit.
  • the bias unit includes a number of movable pads, the pads each being movable, in use, between a retracted position and an extended position. Each pad, when in its extended position, bears against the wall of the borehole, applying a laterally acting force to part of the bias unit and to the drill bit carried thereby.
  • EP 0 728 909 which is considered the closest prior art document, discloses such a system.
  • the pads are typically arranged to be moved by associated pistons to which fluid under pressure, typically drilling fluid or mud, is supplied through a control valve arrangement.
  • fluid under pressure typically drilling fluid or mud
  • the bias unit and drill bit are rotated, for example by a downhole motor or by rotation of the associated drill string.
  • the pads are moved from their retracted positions to their extended positions in turn in synchronism with the rotation of the bias unit, and this is achieved through appropriate control of the control valve.
  • Another system makes use of the weight-on-bit applied to the bit to achieve a degree of steering.
  • a stabiliser is located close to the bit.
  • a change in the applied weight-on-bit causes the bit to tilt about the stabiliser, causing a change in the inclination thereof.
  • a steerable drilling system for drilling a well in an earth formation, the system comprising a drill string having a drill bit secured to the end thereof, the drill bit comprising a bit body having a plurality of cutters attached thereto, characterized in that the bit body includes a control arrangement and a movable member, the control arrangement being arranged, in use, to adjust the position of the movable member in a phased relationship with the rotation of the drill bit with respect to the formation, the movable member being arranged to adjust the operation of at least one of the cutters and thereby control the drilling direction of the drill bit.
  • the movable member may form one of said cutters.
  • the movable member may comprise a gauge pad region of the drill bit, said gauge pad region being disposed adjacent said at least one cutter and movable by the control arrangement to contact the formation and thereby reduce the exposure of said at least one cutter to the formation.
  • the at least one cutter may be retractable, the control arrangement being arranged to move the retractable cutter between its retracted and unretracted states.
  • the movable member comprises a deflectable part of the bit body of reduced wall thickness adjacent said at least one cutter.
  • the movable member comprises an inflatable cutter cover forming part of the bit body, and the control arrangement is arranged to cause the inflatable cover to render said at least one cutter inactive.
  • control arrangement is arranged to adjust the operation of said at least one of the cutters by varying its exposure to the formation being drilled
  • Adjustment of the operation of said at least one cutter may result in an alteration in the depth of cut of the bit, or may after the symmetry of hole propagation.
  • the adjusting mechanism may comprise a snubber, operable to result in the depth of cut being non-uniform across the face of the bit.
  • the at least one cutter may movable to result in the depth of cut being non-uniform across the face of the bit.
  • the system preferably further comprises at least one sensor sensitive to the drilling direction, the adjusting mechanism comparing the sensed drilling direction with a desired drilling direction and using the result of the comparison in adjusting the phase of the adjustment of the position of the movable member
  • a method of drilling a well in an carth formation using a drill string having a drill bit secured to the end thereof, the drill bit comprising a bit body having a plurality of cutters attached thereto the method being characterized by providing the bit body with a control arrangement arranged, in use, to adjust the position of a movable member in a phased relationship with the rotation of the drill bit with respect to the formation so as to adjust the operation of at least one of the cutters and thereby control the drilling direction of the drill bit.
  • the steerable drilling system illustrated, in part, in Figure 1 comprises a drill bit 10 forming part of a bottom hole assembly arranged to be rotated from the drilling rig's top drive or rotary table.
  • the assembly 12 is carried by a drill string 14 incorporating a number of other downhole components, for example downhole stabilisers, sensors and the like.
  • the drill bit 10 comprises a bit body 16 from which a plurality of upstanding blades 18 extend.
  • Each blade 18 is provided with a series of cutting elements 20 arranged such that, in use, upon rotation of the drill bit whilst an axially directed load is applied thereto, the cutters 20 serve to gouge, abrade, or scrape material from the formation in which the borehole is being formed.
  • Drilling fluid is supplied to the drill bit 10 and discharged through nozzles (not shown) arranged to direct drilling fluid so as to flow over and around the cutting elements 20 for the purposes of cooling and cleaning the cutting elements 20.
  • the drilling fluid is supplied to the drill bit 10 under pressure, and after serving to clean and cool the cutters 20, the fluid returns to the surface, or to another location, carrying the removed formation material with it.
  • the bit body 10 is provided with at least one radially movable member in the form of a movable blade 22, the movable blade 22 being movable between a radially retracted position as indicated by the full lines in Figure 2 and a radially extended position as illustrated by the dotted line in Figure 2 .
  • the movable blade 22 is movable between these positions by means of a piston 24 movable within a cylinder 26. Drilling fluid under pressure is supplied, in use, to the cylinder 26 through supply lines 28 and a control valve 30, the control valve 30 controlling the timing of such supply.
  • a restricted flow passage (not shown) is provided to allow fluid to escape from the cylinder 26, and thereby allow the blade 22 to return to its retracted position.
  • control valve 30 In use, when it is desired to effect a change in direction in which drilling is occurring, the control valve 30 is operated, repeatedly, so as to supply drilling fluid under pressure to the cylinder 26 and thereby urge the blade 22 to its radially extended position, and allow the fluid to escape allowing the blade 22 to return to its retracted position, in synchronism with the rotation of the drill bit 10 such that the blade 22 always occupies its extended position when the drill bit 10 is in the same angular position relative to the surrounding formation and occupies its retracted position at other times.
  • the blade 22 may be devoid, at its outer radial part, of cutters, or alternatively cutters may be provided at the outer radial part thereof. Where the outer radial part of the blade 22 is provided with cutters; then the borehole being formed will partially propagate in the direction in which the blade 22 is displaced. Where the outer radial part of the blade 22 is not provided with cutters and is essentially blunt, then the movement of the blade 22 will serve to urge the remainder of the bit, and the direction of propagation of the borehole, in the opposite direction.
  • sensors 34 are associated with the bit, or are located elsewhere, which are sensitive to the direction in which the borehole is propagating.
  • the output of the sensors 34 may be used by a control unit 36 which serves to control the operation of the control valve arrangement 30.
  • the control unit 36 can vary the phase at which the control valve arrangement 30 causes movement of the blade 22 to steer the bit, and hence the direction of propagation, in the desired direction. This can be achieved without full apriori knowledge of the complex motion of the bit described above.
  • the control valve arrangement 30 could take a range of forms. For example, it could comprise a rotary valve, a control shaft of which is connected to a suitable roll stabilised platform or component or to the output of a suitably controlled motor. Another possibility is to use an appropriate bi-stable actuator/valve arrangement. For example, a low-power, electrically operated actuator could be used to control a suitable mud-valve which, in turn, controls the supply of fluid under pressure to the cylinder 26 and associated piston 24.
  • the actuator and/or the valve may be designed to be of bistable form. However, a range of other arrangements are possible.
  • FIG. 2 only illustrates the provision of a single movable blade 22, it will be appreciated that a plurality of such blades may be provided, each movable blade being independently movable between its retracted and extended position under the control of, for example, the control valve 30.
  • Alternative techniques for moving the movable blade may be employed, including bi-stable arrangements, for example as outlined above, designed so that, once the blade is moved to its extended position it will remain in that position, without requiring the continued application of energy thereto, until it is desired to retract the blade.
  • Other possibilities include using shape memory alloys, piezzo electric devices and magneto restrictive or rheological materials to cause the blade to move and/or to hold the blade against movement in both its extended and retracted positions.
  • the techniques used to move the moveable members may be bi-stable in operation, but this need not always be the case.
  • FIGS 11 a and 11 b illustrate an arrangement in which the movable blade 22 is pivotally mounted upon the bit body 10, the blade. 22 being pivotally movable about an axis 22 a to move the blade between a retracted position (illustrated in the full lines in Figure 11 a ) and an extended position (denoted by the broken line in Figure 11 a ).
  • the axis 22a lies substantially parallel to the axis of the bit body 10.
  • the blade 22 is moved using a piston 24 slidable within a cylinder 26, fluid under pressure being supplied to the cylinder 26, in use, through a suitable valve arrangement, allowing the operation of the bit to be controlled in a manner similar to that described hereinbefore.
  • Figure 12 illustrates another, similar, possibility in which the blade 22 in pivotally mounted to the bit body 10, the pivot axis 22 a being substantially perpendicular to the axis of the bit body 10, in this arrangement.
  • Figure 3 illustrates an alternative embodiment in which rather than provide the bit 10 with one or more movable blades 22, the bit 10 is provided with one or more movable members in the form of movable gauge pads .32 movable between radially retracted and radially extended positions in a manner similar to the manner in which the movement of the blades 22 is triggered. Control over the steering direction achievable using such a bit is achieved in a manner very similar to that described hereinbefore and with reference to Figures 1 and 2 . It will be appreciated that any of the techniques outlined hereinbefore may be employed to move the movable gauge pads.
  • the cutters When using a drill bit having no moving parts, the cutters are typically arranged on the bit in an asymmetric pattern, and thus the bit is out-of-balance.
  • the result of this is that, when drilling straight ahead, the overall motion of the bit is straight ahead but with a small scale helical motion superimposed on to the straight ahead movement. If the symmetry of the bit can be changed, in use; imphased relation to the rotation of the bit, then the out-of-balance forces can be used to urge the bit in a constant, chosen direction and thereby to achieve steering thereof.
  • FIG. 4 illustrates a drill bit designed to operate in this manner and comprising a bit body 42 having a plurality of blades 44 provided thereon. Each blade 44 carries a series of cutting elements 46. One or more of the blades 44 includes a movable member in the form of a movable component 48 upon which some of the cutting elements 46 are mounted.
  • the movable component 48 is movable by means of a piston arrangement to which drilling fluid under pressure can be supplied by a suitable control valve arrangement, but could alternatively be moved using any of the other techniques outlined hereinbefore.
  • the design of the drill bit is such that when the movable component 48 occupies its extended position, and so the cutters mounted thereon engage the formation in which the borehole is being formed, the out-of-balance forces are different to when the movable component 48 occupies its retracted position.
  • the bit may be substantially balanced when the movable component 48 occupies its extended position, and out-of-balance when the movable component is retracted. When out-of-balance, a laterally acting force is applied to the bit, in use.
  • the design of the bit could be such that retraction of the component 48 results in the bit becoming more, rather than less, balanced.
  • Figure 4 only illustrates the provision of one movable component, more such components may be provided.
  • the position(s) need not be as illustrated, and may be chosen to suit the bit design.
  • the manner in which the component is moved need also not be as illustrated, and systems other than hydraulically powered systems may be used.
  • the number of cutters on the movable components could be changed, and even whole blades or sets of blades could be moved, if desired. Where two or more blades are movable, movement thereof could be controlled independently to allow very good control over the out-of-balance forces.
  • FIGs 5 to 7 illustrate a drill bit in accordance with another embodiment of the invention.
  • a drill bit is provided which includes a plurality of fixed blades 50 on which cutters 52 are mounted.
  • the bit further includes, on the blades 50, a series of gauge pad regions 54.
  • At least one movable member is provided in the form of a movable gauge pad region 54a which is radially movable between a retracted position as shown in Figure 6 and an extended position as shown in Figure 7 .
  • the cutters 52 provided on the blades 50 adjacent the gauge pad region 54a are exposed to the formation being drilled, these cutters 52 becoming obscured upon movement of the gauge pad 54 a to its extended position.
  • the gauge pad region 54 a can be moved in synchronism with the rotation of the bit such that the out-of-balance force is varied in synchronism with the rotation of the bit, thereby enabling control over the drilling direction.
  • the movable gauge pad region 54 a may be adapted to bear against the formation being drilled and thereby apply a sideway acting load to the bit, the gauge pad region 54 a again being moved in synchronism with the rotation of the drill bit.
  • one or more of the blades 50 may be movable to control the exposure of at least some of the cutters 52 to control out-of-balance forces and consequently drilling direction.
  • the movable gauge pad or blade (or part thereof) need not be in the position or location illustrated, for example a part of a blade located at the face of the bit may be movable.
  • the movable gauge pad or blade may be designed to be replaceable and/or disposable whilst other parts of the bit are re-used. They could be constructed using superhard materials such as PDC, TSP, tungsten carbide or provided with a diamond coating.
  • Figure 8 Another possibility is illustrated in Figure 8 .
  • the bit is provided with a cavity 60 supplied, in use, with drilling fluid or mud.
  • the pressure at which the drilling fluid or mud is supplied can be controlled by controlling, for example, the operation of the pumps used to deliver the fluid or using, for example, appropriately located and controlled valves.
  • the bit wall thickness is non-uniform around the cavity 60, the bit including regions 62 of relatively great wall thickness and at least one region 64 of relatively low wall thickness.
  • the wall thicknesses are chosen such that the regions 62 deflect or deform very little when the pressure within the cavity 60 varies, such pressure variations causing relatively large deflections to occur in the region or regions 64.
  • the solid lines show the bit when the cavity 60 is at low pressure, the broken lines illustrating the bit when the cavity 60 is at an increased pressure. For clarity, the deflection is exaggerated in Figure 8 .
  • the bit carries cutters 66. It will be appreciated that some of the cutters 66 are moved upon deflection of the region 64, varying the out-of-balance forces on the bit and thereby enabling control over steering, or cutting into the formation at varying depths to achieve steering of the bit, the deflection being controlled to occur in synchronism with the rotation of the bit.
  • deflection of the region 64 is used to move some of the cutters 66, it could alternatively be used to move a gauge pad region to vary the exposure of nearby cutters.
  • Figures 9 a and 9 b illustrate an alternative, way of varying the exposure of cutters, comprising providing a bit with an inflatable cutter cover 68.
  • Figure 9 a illustrates the cover 68 in a deflated condition in which the adjacent cutters 70 are exposed
  • Figure 9 b illustrating the cover 68 in an inflated condition in which the adjacent cutters 70 are rendered inactive thereby avoiding cutting by those cutters.
  • Figures 10 a , 10 b and 10 c illustrate arrangements in which individual cutters 72 are movable between extended and retracted positions, the cutters 72 being mounted in bores or sockets 74 formed in a rigid bit body. Drilling fluid is applied to an inner end of each cutter 72 urging the cutter towards its extended position.
  • Figure 10b illustrates the use of springs 76 urging the cutters 72 towards their retracted positions, the cutters 72 moving to their extended positions when the fluid pressure exceeds a predetermined level. When extended, the cutters cut more deeply into the formation, and by moving the cutters in time with the rotation of the bit, steering control over the hole being formed can be achieved.
  • Figure 10 c illustrates an arrangement in which, when the pressure drops below a predetermined threshold, the cutters 72 retract to a position in which they are not exposed.
  • a range of other steering techniques may be used with drill bits having components movable in a phased relationship with the rotation of the drill bit.
  • the cutting structure could be controlled, in use, so as to produce a drill bit having a phased controlled asymmetry of hole propagation.
  • One way in which this may be achieved is to provide the bit with one or more movable components in the form of snubbers, movable to limit the depth of cut of the bit.
  • Another way is to move the cutters instead of, or in conjunction, with the moveable snubbers.
  • the movable components are movable, as with the other embodiments, in a phased relationship with the rotation of the drill bit so as to vary the depth of cut across the face of the bit in phase with the rotation of the drill bit causing the bit to be laterally disturbed due to the imbalance of rock removal and imbalance forces.
  • the control system is arranged to determine the relationship of hole propagation to the phase of cutter/snubber variation and to adjust the phase accordingly to achieve the desired steering objectives. As a result, a preferred off axis drilling direction can be achieved Other techniques of controlling the direction of hole propagation by phase control of aspects of rock or formation removal by the bit are also possible within the scope of the invention.
  • Another possibility is to use a bit with a fixed cutting structure and arrange for it to be dynamically pointed about a pivot point set within the bit in a phase controlled relationship to the formation.
  • the pivot point is a 2 degree of freedom universal joint allowing the bit axis to be tilted (typically less than 10 degrees) with respect to the local drill string central axis and capable of transmitting the drilling load and torques to the bit.
  • This is different from conventional point the bit directional drilling systems in that the centre point of the bit experiences negligible lateral offset from the drill string central axis as the bit drilling axis is tilted.
  • An alternative to using a complex system of this type is to control a bit, for example bits of the general type illustrated in Figures 3 and 4 , in such a way that a change in the fluid pressure drop across the bit causes movement of adjustment of at least part of the cutting structure of the bit, causing a change in the bits profile , and as a result changing the bit's walk angle.
  • the bit is connected to a downhole stabiliser arranged such that a change in the weight-on-bit applied to the system causes the bottom hole assembly, or at least part thereof, to pivot or tilt about the stabiliser and thereby changes the inclination of the bit.
  • the bit or cutting structure is only changed when a new walk angle is required, rather than being modified in phase with the rotation of the bit, thus it can be used with a much simpler control system.
  • the description hereinbefore describes one way of achieving movement of the movable components of the drill bits described, it will be appreciated that a range of other techniques for causing movement of the movable components may be used without departing from the scope of the invention.
  • the bit is rotated for example using power derived from the drilling rig's top drive or rotary table, it could alternatively be connected to the output of a downhole motor, for example a fluid driven motor, turbine, electrical motor or the like.

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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)
  • Drilling And Boring (AREA)

Claims (17)

  1. Richtbohrsystem für das Bohren eines Brunnens in einer Erdformation, wobei das System einen Bohrschaft (14) mit einer an dessen Ende befestigten Bohrkrone (10) umfasst, wobei die Bohrkrone einen Bohrkörper (16) mit einer Mehrzahl von daran befestigten Schneiden (18, 20) umfasst, dadurch gekennzeichnet, dass der Bohrkörper (16) eine Steueranordnung (24, 26) und ein mobiles Glied (22, 48, 54a, 64 oder 68) einschließt, wobei die Steueranordnung bei der Verwendung so angeordnet ist, dass die Position des mobilen Glieds in einer phasenweisen Beziehung mit der Drehung der Bohrkrone (10) in Bezug auf die Formation eingestellt wird, wobei das mobile Glied so angeordnet ist, dass der Betrieb von zumindest einer der Schneiden eingestellt und somit die Bohrrichtung der Bohrkrone gesteuert wird.
  2. System nach Anspruch 1, dadurch gekennzeichnet, dass das mobile Glied (22) eine der besagten Schneiden bildet.
  3. System nach Anspruch 1, dadurch gekennzeichnet, dass das mobile Glied einen Kaliberschutzbereich (54a) der Bohrkrone umfasst, wobei der besagte Kaliberschutzbereich anschließend an der besagten mindestens einen Schneide (50, 52) angeordnet ist und durch die Steueranordnung bewegt werden kann, um mit der Formation in Kontakt zu treten und daher die Berührung der besagten mindestens einen Schneide mit der Formation zu reduzieren.
  4. System nach Anspruch 2, dadurch gekennzeichnet, dass die besagte eine Schneide (Fig. 10) einziehbar ist und die Steueranordnung so gestaltet ist, dass sie das einziehbare Schneidenelement (72) zwischen seinem eingezogenen und seinem nicht eingezogenen Zustand bewegt.
  5. System nach Anspruch 1, dadurch gekennzeichnet, dass das mobile Glied einen ablenkbaren Teil (64) des Bohrkörpers (Fig. 8) mit reduzierter Wandstärke anschließend an der besagten mindestens einen Schneide (66) umfasst.
  6. System nach Anspruch 1, dadurch gekennzeichnet, dass das mobile Glied eine aufblasbare Schneidenabdeckung (68) umfasst, die einen Teil des Bohrkörpers (Fig. 9) bildet, und dass die Steueranordnung so gestaltet ist, dass die aufblasbare Abdeckung die besagte mindestens eine Schneide inaktiv macht.
  7. System nach Anspruch 1, dadurch gekennzeichnet, dass die Steueranordnung so gestaltet ist, dass sie den Betrieb der mindestens einen der Schneiden einstellt, indem sie ihre Berührung mit der gerade gebohrten Formation variiert.
  8. System nach einem beliebigen der vorstehenden Ansprüche 1 bis 7, dadurch gekennzeichnet, dass die Einstellung des Betriebs der besagten mindestens einen Schneide zu einer Veränderung der Schneidtiefe der Bohrkrone führt.
  9. System nach einem beliebigen der vorstehenden Ansprüche 1 bis 7, dadurch gekennzeichnet, dass die Einstellung des Betriebs der besagten mindestens einen Schneide die Symmetrie der Lochausbreitung verändert.
  10. System nach Anspruch 9, dadurch gekennzeichnet, dass die Steueranordnung einen Dämpfer umfasst, der so betrieben werden kann, dass dies dazu führt, dass die Schneidtiefe über die Fläche der Bohrkrone hinweg nicht gleichmäßig ist.
  11. System nach Anspruch 9 oder nach Anspruch 10, dadurch gekennzeichnet, dass die besagte mindestens eine Schneide so bewegbar ist, dass dies dazu führt, dass die Schneidtiefe über die Fläche der Bohrkrone hinweg nicht gleichmäßig ist.
  12. System nach einem beliebigen der vorstehenden Ansprüche, dadurch gekennzeichnet, dass es zumindest einen Sensor umfasst, der auf die Bohrrichtung reagiert, wobei der Einstellmechanismus die gefühlte Bohrrichtung mit einer gewünschten Bohrrichtung vergleicht und das Ergebnis des Vergleichs beim Einstellen der Phase der Einstellung der Position des mobilen Glieds benutzt.
  13. System nach einem beliebigen der vorstehenden Ansprüche, dadurch gekennzeichnet, dass für den Betrieb des Einstellmechanismus eine unter Druck stehende Flüssigkeit eingesetzt wird.
  14. System nach Anspruch 13, dadurch gekennzeichnet, dass die Versorgung der Bohrkrone mit unter Druck stehender Flüssigkeit von einem Drehschieber (30) gesteuert wird.
  15. System nach Anspruch 13, dadurch gekennzeichnet, dass die Versorgung mit unter Druck stehender Flüssigkeit unter Einsatz eines bistabilen Schiebers oder Magnetventil (30) gesteuert wird.
  16. System nach einem beliebigen der vorstehenden Ansprüche 13 bis 15, dadurch gekennzeichnet, dass die Flüssigkeit Öl, Schlamm, magnetorheologische Flüssigkeit, Gas oder ähnliche enthält.
  17. Methode für das Bohren eines Brunnens in einer Erdformation unter Einsatz eines Bohrschafts (14) mit einer an dessen Ende befestigten Bohrkrone (10), wobei die Bohrkrone einen Bohrkörper (16) mit einer Mehrzahl von daran befestigten Schneiden (18, 20) umfasst, wobei die Methode dadurch gekennzeichnet ist, dass der Bohrkörper (16) mit einer Steueranordnung (24, 26) versehen ist, die im Betrieb so angeordnet ist, dass sie die Position eines mobilen Glieds (22, 48, 54a, 64 oder 68) in einer phasenweisen Beziehung mit der Drehung der Bohrkrone (10) in Bezug auf die Formation einstellt, so dass der Betrieb von mindestens einer der Schneiden eingestellt und somit die Bohrrichtung der Bohrkrone gesteuert wird.
EP06765124A 2005-07-27 2006-07-26 Lenkbares bohrsystem Active EP1977073B1 (de)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
GBGB0515394.5A GB0515394D0 (en) 2005-07-27 2005-07-27 Steerable drilling system
PCT/GB2006/002803 WO2007012858A1 (en) 2005-07-27 2006-07-26 Steerable drilling system

Publications (2)

Publication Number Publication Date
EP1977073A1 EP1977073A1 (de) 2008-10-08
EP1977073B1 true EP1977073B1 (de) 2011-06-22

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EP06765124A Active EP1977073B1 (de) 2005-07-27 2006-07-26 Lenkbares bohrsystem

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EP (1) EP1977073B1 (de)
CN (1) CN101268246B (de)
AT (1) ATE513977T1 (de)
GB (2) GB0515394D0 (de)
WO (1) WO2007012858A1 (de)

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Also Published As

Publication number Publication date
CN101268246A (zh) 2008-09-17
WO2007012858A1 (en) 2007-02-01
GB0515394D0 (en) 2005-08-31
EP1977073A1 (de) 2008-10-08
CN101268246B (zh) 2014-04-09
GB0614641D0 (en) 2006-08-30
ATE513977T1 (de) 2011-07-15
GB2428713A (en) 2007-02-07

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