WO2015127345A2 - Eccentric stabilizer for synchronous rotary steerable system - Google Patents
Eccentric stabilizer for synchronous rotary steerable system Download PDFInfo
- Publication number
- WO2015127345A2 WO2015127345A2 PCT/US2015/017048 US2015017048W WO2015127345A2 WO 2015127345 A2 WO2015127345 A2 WO 2015127345A2 US 2015017048 W US2015017048 W US 2015017048W WO 2015127345 A2 WO2015127345 A2 WO 2015127345A2
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- WIPO (PCT)
- Prior art keywords
- assembly
- drilling
- actuator
- sleeve
- eccentric
- Prior art date
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Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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 DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
Definitions
- the complex trajectories and multi-target oil wells require the directed placement of a borehole's path and the ability to continually to control or "steer" the direction or path of the borehole during the drilling operation.
- the path can be rapidly controlled during the drilling operation at any depth and target as the borehole is advanced by the drilling operation.
- Directional drilling is complicated by the necessity to operate a drill bit steering device within harsh borehole conditions.
- the steering device is typically disposed near the drill bit, which terminates a lower or "downhole" end of a drillstring.
- Many types of devices known in the prior art have been used to control the direction of a drill bit. Some devices use stabilizers having ribs or extensions for engaging the wall of a borehole and controlling the direction of the drill bit as it bores through the ground.
- Other devices may use rotational valve systems for employing fluid to steering pads, may use magnetic switches to control directional changes, or may use non-rotatable sleeves for applying lateral force to a borehole to adjust drilling trajectories. Examples of some devices used to direct the trajectory of a drill bit can be found in U.S. Pat. Nos. 4,319,649; 6,840,336; and 7,503,408.
- a method and apparatus for steering a drilling assembly during drilling operations for oil and gas comprising a drill bit attached to a drill collar having an eccentric stabilizer disposed there upon.
- the eccentric stabilizer either in an engaged state whereupon rotating concentrically with the drill collar, or in a released state whereupon as the drill collar rotates the eccentric stabilizer is positioned eccentrically relative to the drill collar creating a lateral deflection in the borehole that may be used for changing the direction of the drilling assembly.
- FIG. 1A illustrates a drilling system having a drilling assembly disposed in a borehole according to the present disclosure.
- Fig. IB illustrates the drilling assembly in more detail.
- Fig. 2A illustrates a more detailed view of an eccentric stabilizer component of the drilling assembly in an engaged state.
- Fig.2B illustrates the stabilizer component of the drilling assembly in a released state.
- Fig.3A illustrates a perspective view of the disclosed drilling assembly having an eccentric section offset from a central rotational axis of the drilling assembly.
- Fig.3B illustrates a cross-sectional view of the drilling assembly in Fig.3A having the eccentric section offset from the central axis of the drilling assembly.
- Fig.4A illustrates the drilling assembly disposed in the borehole and having the stabilizer component disposed and released near the drill bit.
- Fig.4B illustrates the drilling assembly disposed in the borehole and having the stabilizer component disposed and released a distance away from the drill bit.
- Fig. 5 illustrates another drilling assembly having an eccentric stabilizer component according to the present disclosure.
- Figs. 6A-6C illustrate various views of the drilling assembly in different states of assembly.
- Fig. 6D illustrates a schematic end view of the downhole assembly showing the eccentricity of its components.
- Figs. 7A-7B illustrate a side view and an end view of the disclosed drilling assembly oriented for concentric drilling.
- Fig. 8 illustrates the disclosed drilling assembly during an initial stage of activation.
- Figs. 9A-9B illustrate a side view and an end view of the disclosed drilling assembly during eccentric activation.
- Figs. 10A-10B illustrate a side view and an end view of the disclosed drilling assembly oriented for eccentric drilling.
- Fig. 11 illustrates a side view of the disclosed drilling assembly during an initial stage of deactivation.
- Fig. 1A illustrates a drilling system 20 having a drilling assembly 200 suspended in a borehole 10 penetrating an earth formation.
- a derrick structure 22 supports the downhole assembly 200 on a drillstring 110 and has a crown block at the top.
- a traveling block is moveably connected to the crown block and serves to connect to the drillstring 110, which is raised and lowered into the borehole 10 by a cable connected to a drawworks 24.
- the drawworks 24 is used to release or retract cable, allowing the traveling block to be raised or lowered, which in turn raises or lowers the drillstring 110.
- a rotary table 26 may serve to control rotation of the drillstring 110.
- the drilling assembly 200 connected to the drillstring 110 is terminated by a drill bit 120.
- the rotary table 26 imparts rotation to the drill bit 120 by rotating the drillstring 110 and the drilling assembly 200.
- the drill bit 120 of the drilling assembly 200 may be a polycrystalline diamond compact (PDC] bit, a rotary drilling bit rotated by a mud motor and shaft, or any other suitable type of drill bit 120.
- PDC polycrystalline diamond compact
- the drilling assembly 200 can have one or more stabilizer components 220 that are used for both stabilizing the drilling assembly 200 within the borehole 10 during drilling operations and creating a lateral force in the borehole 10 for directing the drilling assembly 200 in a particular direction downhole.
- the drilling assembly 200 disposed on the drillstring 110 has a controller section 204, an actuator and sensor section 202, a stabilizer component 220, an eccentric section 210, an engagement mechanism 230, and the drill bit 120.
- the controller section 204 can have control circuitry, memory, battery power, telemetry components, and the like to control operation of the drilling assembly 200.
- the control section 204 can have sensors for determining near-bit inclination and azimuth for directional drilling.
- the actuator and sensor section 202 can house one or more actuators and position sensors that operate in conjunction with the control section 204 to control operation of the drilling assembly 200.
- the stabilizer component 220 can have the form of a sleeve or the like disposed on the eccentric section 210 of the drilling assembly 200.
- the eccentric section 210 is offset from the central rotational axis C of the assembly 200 to that the stabilizer component 220 is eccentrically located on the assembly 200.
- the engagement mechanism 230 is operated by the actuator and sensor section 114 to either engage or release the stabilizer component 220.
- the stabilizer component 220 rotates with the assembly 200 and the rotation imparted to it.
- the stabilizer component 220 can rotate relative to the assembly 200.
- synchronizing the engagement and release of the eccentric stabilizer component 220 on the drilling assembly 200 during rotation can be used to direct drilling of the borehole 10.
- the stabilizer component 220 disposed on the drilling assembly 200 is shown in an engaged state.
- the stabilizer component 220 is a sleeve disposed on the eccentric section 210.
- the stabilizer component 220 may be composed of high-strength steel or any other material suitable for use as a stabilizer for a downhole tool in a borehole.
- the stabilizer component 220 may also have coatings of even harder material for additional durability.
- the diameter of the stabilizer component 220 may vary depending on the application.
- the stabilizer component 220 can be the same diameter of the diameter of the drilling assembly 200; however, the diameter of the stabilizer component 220 may be larger or smaller than the diameter of the drilling assembly 200.
- the stabilizer component 220 is disposed on the eccentric section 210, which passes through the stabilizer component 220.
- the eccentric section 210 may be an extension of the drilling assembly 200, having been machined with an inner diameter different than the diameter of the drilling assembly 200, or may be otherwise designed, or even be removably connectable to the drilling assembly 200.
- One or more engagement mechanisms 230 may be disposed within the drilling assembly 200.
- the engagement mechanism 230 serves to release or lock the stabilizer component 220.
- the engagement mechanism 230 may either release or lock the stabilizer component 220 at revolution intervals needed to maintain the desired drill path.
- the control parameters can be modified by communication from the surface and/or autonomously by directives preloaded into the downhole electronics either at the surface using an engagement control communicating with the engagement mechanism 230 downhole, or by programing a controller downhole.
- the engagement mechanism 230 preferably takes a minimal amount of effort and uses as minimal electrical energy as possible to engage and re-engage the stabilizer component 220 with the drilling assembly 200.
- Some mechanisms that may be used include hydraulic systems with pistons and/or valves, a slip clutch mechanism, or any disposable object that can be used to lock the stabilizer component 220 to the drilling assembly 200.
- the engagement mechanism 230 may use a pin and spring mechanism for engaging the stabilizer component 220.
- the pin of the mechanism 230 can extend and retract relative to the stabilizer component 220 and may engage and disengaged from one or more slots 226, stops, locks or the like on the component 220.
- the engagement mechanism 230 may be a multi-plate clutch mechanism, a ball/release mechanism, or any other suitable feature to lock and release the stabilizer component 220 relative to the drilling assembly 200.
- the stabilizer component 220 When the engagement mechanism 230 is engaged [i.e., the engagement mechanism 230 has been configured to lock the stabilizer component 220 in an engaged state] the stabilizer component 220 will be disposed on the drilling assembly 200 being symmetrically aligned with the center of the drilling assembly 200 [i.e., in a concentric state]. In this configuration, the stabilizer component 220 is connected to the drilling assembly 200. When the drilling assembly 200 is rotated as a result of rotating the connected drillstring 110, the stabilizer component 220 will likewise rotate. In this state, the stabilizer component 220 may help stabilize the downhole assembly 200, but will significantly direct drilling.
- the stabilizer component 220 can engage the borehole (10] using both friction and drag. Friction acting on the stabilizer component 220 in a neutral position concentric on the assembly 110 may assist in persuading the stabilizer component 220 to cam out from the eccentric section 210 once the engagement mechanism 230 has been released.
- This camming action may be achieved by physical force (e.g., flow turbulence] upon the stabilizer 220, or by some mechanical, electrical, and/or magnetic inducement (e.g., using motors, or other such devices internal or external] to the drilling assembly 200.
- additional drag may act on the stabilizer component 220 causing the stabilizer component 220 to eventually reach maximum eccentricity.
- the stabilizer component 220 may contain other friction inducing surfaces or mechanisms to increase the ability of the stabilizer component 220 to engage the borehole (10 ⁇ once released.
- Fig. 2 B illustrates the stabilizer component 220 disposed on the drilling assembly 200 in a released state.
- the stabilizer component 220 is movably connected to the drilling assembly 200, and is only held in a concentric state with the drilling assembly 200 when locked by the engagement mechanism 230.
- the stabilizer component 220 when the stabilizer component 220 is activated (i.e., when the engagement mechanism 230 is in a released state], the stabilizer component 220 will engage the borehole 10, while the drilling assembly 200 is allowed to continue rotation in a right rotation direction, as shown by the right rotation arrow (R ⁇ .
- the above illustration assumes the drillstring 110 is rotating in the (R ⁇ direction (clockwise ⁇ . The stabilizer will apparently be rotating to the left (L ⁇ direction
- the external surface 222 of the stabilizer component 220 can include spiraling ribs, contours, or other features.
- the external surface 222 serves to contact the inside of the borehole (10 ⁇ when the stabilizer component 220 is in the released state.
- additional friction generating substances or mechanisms may be used to increase the ability of the stabilizer component 220 to engage the borehole (10 ⁇ when released.
- Figs. 3A and 3B better illustrate the drilling assembly 200 having the eccentric section 210 offset from the central axis C of the drilling assembly 200.
- the flow passage 205 through the drilling assembly 200 communicates with flow passage 215 through the eccentric section 210 so that drilling fluid can be communicated from the drillstring 110 to the drill bit 120.
- the stabilizer component (220 ⁇ is disposed on the eccentric section 210 with the eccentric section 210 having an offset from the central axis C of the drilling assembly 200, the stabilizer component 220 in a released state creates a lateral deflection within the borehole (10 ⁇ .
- the stabilizer component 220 is movably connected to the drilling assembly 200 by way of the eccentric section 210. Also, the eccentric section 210 is offset from the central axis C of the drilling assembly 200. When the stabilizer component 220 is in a released state and rotates relative to the eccentric section 210, the stabilizer component 220 will be in an eccentric position relative to the drilling assembly 200. As will be discussed further below, this eccentric state allows the stabilizer component 220 to be forced between the drilling assembly 200 and the borehole 10, thus inducing a lateral force on the drilling assembly 200.
- the eccentric section 210 is not aligned in the center axis C of the drilling assembly 200. Instead, the eccentric section 210 is offset from the central axis C by some amount. Again, this offset allows the stabilizer component 220 to be in an eccentric position with respect to the drilling assembly 200. Also, the eccentricity of the stabilizer component 220 when released relative to the drilling assembly 200 may depend on the amount the eccentric section 210 is offset from the central axis C of the drilling assembly 200. Further, as shown in Figs. 3A and 3B, the engagement mechanism 230 may also be offset from the central axis C of the drilling assembly 200.
- releasing the stabilizer component 220 while rotating the drilling assembly 200 creates a lateral deflection in the borehole 10, which in turn can be used to direct the trajectory of the drilling assembly 200.
- the displacement of the one or more stabilizer components 220 from the drill bit 120 may cause the drilling assembly 200 trajectory to vary.
- Fig. 4A illustrates one example of the drilling assembly 200 disposed in the borehole 10.
- the assembly 200 has the stabilizer component 220 disposed and released near the drill bit 120 by a distance Di.
- the stabilizer component 220 may preferably be released at the low side of the borehole 10 but may be released at any disposition in the borehole 10 for creating lateral deflection in any direction of the borehole 10.
- the engagement mechanism 230 is released as shown, then the friction of the external surface 222 of the stabilizer component 220 against the borehole 10 will begin stalling the stabilizer component 220 relative to the position of the rotating drilling assembly 200. This stalling creates additional friction on the stabilizer component 220 because of the camming effect discussed above.
- the stabilizer component 220 will be at maximum friction when it reaches maximum eccentricity [i.e., when the stabilizer component 220 rotates substantially near 180 degrees from its original concentric position ⁇ . While approaching maximum eccentricity, the stabilizer component 220 is forced in the transverse direction ( ) creating an opposite force or deflection in the opposite direction (B ⁇ . In one embodiment, creating a force in the direction (B] due to the deflection created by the stabilizer component's eccentricity may preferentially direct the drill bit 120 of the drilling assembly 200 to drill on that side of the borehole 10 in that direction.
- Fig.4B illustrates another example of the drilling assembly 200 disposed in the borehole 10.
- the assembly 200 has the stabilizer component 220 disposed and release a greater distance D2 away from the drill bit 120.
- releasing the stabilizer component 220 while rotating the drilling assembly 200 creates a lateral deflection in the borehole 10, which in turn can be used to direct the trajectory of the drilling assembly 200.
- the lateral deflection created by the eccentricity of the stabilizer component 220 may actually be used to bend the drill collar of the drilling assembly 200.
- This bend in the drill collar may cause the drill bit 120 to be forced in a similar direction (T' ⁇ as the initial force in direction ( ) created by the eccentricity of the stabilizer component 220.
- T' ⁇ the initial force in direction ( ) created by the eccentricity of the stabilizer component 220.
- the engagement mechanism 230 may be activated every other rotation of the drilling assembly 200 so that the stabilizer component 220 is recaptured after each rotation to remain concentric. Recapture of the stabilizer component 220 may be necessary because, based on a plethora of mechanical and environmental variables downhole, the stabilizer component 220 may not necessarily remain synchronous with the rotation of the drilling assembly 200.
- the drilling assembly 200 preferably operates the steering remotely from the surface of the earth. Furthermore, the steering can be operated to maintain the desired path and direction while being deployed at possibly a great depth within the borehole and while maintaining practical drilling speeds. Finally, the steering can reliably operate under exceptional heat, pressure, and vibration conditions that can be encountered during the drilling operation.
- Another control technique can release the engagement mechanism 230 when the desired "heading" of the drilling assembly 200 is directed to a calculated target.
- control circuitry and sensors may monitor and record the toolface position when the sleeve of the stabilizer component 220 has reached maximum eccentricity.
- the sensing can be performed using a Hall Effect sensor or using torsional measurement.
- locking the engagement mechanism 230 may be skipped so that the drilling may continue in the direction of the desired trajectory. Skipping activation of the mechanism 230 can be done for one revolution, which in reality may be only a partial revolution due to lag from the first activation. This re-synchronizes the stabilizer component 220 to the drilling assembly 200. This process is then repeated multiple times for a time cycle [e.g., 60 times if drilling at 120 rpm equating to one minute ⁇ .
- the activation toolface of the mechanism 230 is evaluated relative to the recorded position of the stabilizer component 220 at its peak eccentricity to determine any "slippage correction."
- the stabilizer component 220 may be reengaged or locked to adjust the heading while the mechanism 230 is activated to compensate for the measured slippage during the previous time cycle.
- the entire process may be repeated many times, or modified to obtain the required trajectory.
- the stabilizer component 220 may be locked continuously within the borehole 10 if building an angle or changing direction of the drilling assembly 200 is not wanted.
- the drill bit 120 has an active "cutting" face that remains the same.
- the cutting face is determined by the random position of the bit 120 when it is put onto the assembly 200 and is the side of the bit 120 positioned opposite where the eccentric sleeve 220 reaches its maximum eccentricity. During operations, the active cutting face will take the brunt of the wear.
- FIG. 5 another drilling assembly 300 has an eccentric stabilizer component 340 according to the present disclosure disposed thereon.
- this drilling assembly 300 can allow the drill bit 120 to experience more distributed wear during operations. Also, the drill path created with this assembly 300 may follow a more uniform trajectory with less lobe shapes produced during directional changes.
- this drilling assembly 300 includes a drill body or collar 310 with a drill bit 320 on its distal end.
- the drill collar 310 is coupled to an actuator assembly 330, which has a linear actuator 332, a torque clutch 334, and position sensors 336.
- the position sensors 336 in the assembly 330 determine the position of an actuator 350 so it can be coordinated to the toolface of the drilling assembly 300 and the eccentric offset that can be achieved with the stabilizer component 340.
- the actuator assembly 330 is coupled to a control assembly 338 that houses control circuitry 339a and sensors 339b, such as near-bit inclination and azimuth sensors.
- the entire drilling assembly 300 extends from the drillstring 110, which imparts rotation to the assembly 300.
- the eccentric stabilizer component 340 includes the actuator 350 disposed on the drill collar 310.
- the actuator 350 is operatively coupled to the actuator assembly 330, which can move the actuator 350 axially with the linear actuator 332 and can turn or torque the actuator 350 about the axis of the drill collar 310 with the clutch 334.
- the stabilizer component 340 includes an inner eccentric sleeve 360 disposed on the drill collar 310, an outer eccentric sleeve 370 disposed on the inner sleeve 360, and a stabilizer body 380 disposed on the outer sleeve 370.
- the actuator 350 is engaged with the inner sleeve 360 and is selectively engageable in first and second conditions with the outer sleeve 370.
- the actuator 350 moved to the first condition can selectively engage with the outer sleeve 370 and can orient the combined eccentricity E of the inner and outer sleeves 360, 370 concentrically on the drill collar 310.
- the stabilizer component 340 is concentric to the central rotational axis C of the drill collar 310.
- the actuator 350 moved to the second condition can selectively engage with the outer sleeve 370 and can orient the combined eccentricity E of the inner and outer sleeves 360, 370 eccentrically on the drill collar 310. Controlling these states can achieve directional drilling.
- Figs. 6A-6C show the stabilizer component 340 in more detail in the partial disassembled views.
- the eccentric stabilizer component 340 includes the inner eccentric sleeve 360 disposed on the drill collar 310, which passes through an eccentric passage 361 of the inner sleeve 360.
- the actuator 350 includes an axial member or slide bar 352 disposed in a longitudinal slot 362 of the inner sleeve 360 so that the actuator 350 and the inner sleeve 360 can rotate together depending on how the actuator assembly 330 with its clutch (334 ⁇ operates the actuator 350.
- the clutch (334 ⁇ of the assembly 330 allows the actuator 350 to be driven by the rotation of the drill collar 310 with an amount of torque. In other situations during operation, the clutch (334 ⁇ of the assembly 330 is operated so that there is less torque on the actuator 350. The assembly 330 can therefore use the clutch (334 ⁇ to selectively control the extent that the actuator 350 is driven by the drill collar 310.
- the clutch (334 ⁇ as disclosed herein may use static friction element(s ⁇ that will encourage the camming action of the external sleeve 370.
- the actuator's slide bar 352 is travelling with the eccentric sleeves 360, 370, and the slide bar 352 can be activated in any relationship to the drill collar 310.
- camming out the outer sleeve 370 can use a stalling force on the inner sleeve 360 relative to the drill collar 310 and can also use a stalling force on the outer sleeve 370 relative to the borehole to cause the sleeves 360, 370 to move differentially to each other.
- the outer sleeve 370 may have a spring- loaded wear pad to provide additional friction, even in an over-gauged borehole.
- the inner sleeve 360 can be magnetically coupled to the drill collar 310 to produce constant drag, while still allowing the two pieces to constantly rotate.
- the magnetic drag can be produced in the ring portion of the actuator 350, which is coupled with the inner sleeve 360.
- the actuator 350 is slid by the linear actuator (332 ⁇ , magnetic elements between the ring of the actuator 350 and the drill collar 310 can overlap and create the desired drag between the actuator 350 (coupled to the inner sleeve 360 ⁇ and the drill collar 310.
- the actuator 350 may only need to be actuated linearly (and possibly use a spring return ⁇ for the required clutching to occur. All of the other needed forces can be generated by that one action. As will be appreciated, too much differential loading between the outer sleeve 370 and the inner sleeve 360 can make it more difficult for the actuator 350 to operate.
- the eccentric stabilizer component 340 further includes the outer eccentric sleeve 370 disposed on the inner sleeve 360, which passes through an eccentric passage 371 of the outer sleeve 370.
- the outer sleeve 370 does not include a longitudinal slot.
- a concentric stop 376 on the outer sleeve 370 is capable of engaging a distal stop 356 on the slide bar 352 of the actuator 350.
- outer sleeve 370 includes an eccentric stop 374 capable of engaging a proximal stop 354 on the actuator 350.
- stops 354, 356 can selectively engage the outer sleeve's stops 374, 376.
- the stops 374, 376 on the sleeve 370 can include tabs or the like extending from opposite ends of the sleeve 370.
- the slide bar's stops 354, 356 can be tabs extending upward from the surface of the bar 352. Other features for the stops 354, 356, 374, and 376 can be used.
- a stabilizer body 380 is disposed external to the outer sleeve 370.
- the stabilizer component 340 is intended to be non-rotating in the borehole so the stabilizer body 380 can include conventional features for non- rotation as found in non-rotating rotary steerable systems, such as disclosed in US Pat. Pub. 2014/0262507, which is incorporated herein by reference.
- the views of the stabilizer component 340 do not show many of the components required for the stabilizer component 340 to operated downhole during drilling operations. In other words, protective bodies, seals, bearings, etc. are not depicted for simplicity. With the benefit of the present disclosure, however, one skill in the art will recognize the use and necessity of these and other such features.
- the drill collar 310, the inner sleeve 360, the outer sleeve 370, and the stabilizer body 380 can be oriented concentrically and eccentrically depending on operation of the actuator 350 by the actuator assembly 330, as described in more detail below.
- the concentric arrangement of these components is schematically illustrated in Fig. 6D.
- the inner sleeve 360 is oriented in the inner passage 371 of the outer sleeve 370 so that the two eccentric sleeves 360, 370 when combined cancel each other.
- the stabilizer body 380 is oriented concentric to the rotational axis C of the drill collar 310.
- the inner sleeve 360 can move (rotate] relative to the drill collar 310, and the outer sleeve 370 can move (rotate] relative to the inner sleeve 360.
- the stabilizer body 380 can be part of or connected to the outer sleeve 370 so that they move together, or the stabilizer body 380 can move (rotate] relative to the outer sleeve 370. Friction and torque may allow the various components to move (rotate] relative to one another, and various features, such as bearings, bushings, etc. found on rotary steerable system can allow for the relative rotation.
- Figs. 7A-7B the disclosed drilling assembly 300 is illustrated in a side view and an end view oriented for concentric drilling.
- the stabilizer component 340 is oriented with the two sleeves 360, 370 concentrically arranged on the drill collar 310 so that the drill bit 320 rotate with the rotational axis C of the assembly 300. Rotation of the drill collar 310 and bit 320 is illustrated in direction RA.
- the actuator 350 is retracted so that its distal stop 356 on the slide bar 352 engages the concentric stop 376 on the outer sleeve 370.
- the outer sleeve 370 along with the stabilizer body 380 is coupled for rotation with the actuator 350.
- the inner sleeve 360 with the slide bar 352 passing there through is also coupled for rotation with the actuator 350.
- the stabilizer component 340 can move (rotate] relative to the drill collar 310, the component 340 may remain rotationally stationary in the advancing borehole.
- the component 340 may be allowed to rotate relative to the drill collar 310.
- relative movement either positive or stationary for the component 340 is depicted as opposite rotation RB for illustrative purposes. In other words, if the component 340 is to be non- rotating in the borehole during concentric drilling, it remains stationary while the drill collar 310 rotates.
- the concentric drilling arrangement in Figs. 7A-7B allow the drilling assembly 300 to advance a borehole following along the central rotational axis C of the assembly 300.
- the positive rotation RA can be imparted to the drill collar 310 and the drill bit 320 via drillstring rotation.
- the drill collar 310 and the drill bit 320 can be imparted to the drill collar 310 and the drill bit 320 via drillstring rotation.
- the positive rotation RA can be imparted to the drill collar 310 and/or the drill bit 320 via a mud motor (not shown].
- the actuator 350 is activated by operation of the actuator assembly 330.
- the linear actuator (332 ⁇ of the actuator assembly 330 moves the actuator 350 along the drill collar 310 as depicted in direction SA.
- the distal stop 356 on the slide bar 352 comes free of the concentric stop 376 on the outer sleeve 370.
- the inner sleeve 360 is still configured to move (rotate] with the actuator 350, but the outer sleeve 370 is free to move (rotate] relative to the inner sleeve 360.
- Torque applied by the clutch (334] of the actuator assembly 330 allows the actuator 350 and the inner sleeve 360 to rotate in direction Rc with the assembly's rotation RA [i.e., the clutch (334] allows part of the collar's rotation RA to be imparted to the actuator 350 and inner sleeve 360]. Meanwhile, the outer sleeve 370 and the stabilizer body 380 can remain "non-rotating" by maintaining its relative counter rotational direction RB.
- Fig. 9A illustrate a side view of the disclosed drilling assembly 300 rotated about 180-degrees from the other depictions so the engagement of the proximal stop 354 with the eccentric stop 374 can be viewed.
- This eccentric activation orients the component 340 eccentric to the rotation axis C of the drilling assembly 300 so that the drill bit 320 as shown in Fig. 9B is offset in a displacement direction D.
- the offset direction D can be oriented in the borehole so that the drill bit 320 advances toward a desired trajectory.
- the actuator assembly 330 can be controlled to orient the offset direction D as needed.
- the clutch (334] of the actuator assembly 330 can apply torque to the actuator 350 to orient the offset direction D relative to the toolface TF.
- torque applied in rotational direction RD can orient the offset direction to the desired toolface TF, essentially by dragging the stabilizer component 340 around in the borehole. Drilling can then continue with the offset direction D oriented as desired. Changes to the trajectory can be made with the actuator 350 operated by the actuator assembly 330 adjusting the toolface TF of the offset direction D.
- FIG. 11 illustrates a side view of the disclosed drilling assembly 300 during an initial stage of deactivation.
- the linear actuator (332 ⁇ of the actuator assembly 330 retracts the actuator 350 so that its proximal stop 354 disengages from the eccentric stop 374 on the outer sleeve 370.
- relative movement of the inner and outer sleeves 360, 370 can then orient the concentric stop 376 to engage the distal stop 356 of the actuator 350 so that the component 340 is arranged concentrically on the drill collar 310.
- the disclosed eccentric stabilizer components 200 and 340 can be used with any other directional drilling tool used on the drilling assembly 200 and 300.
- the components 200 and 340 can be used with each other and/or with a directional drilling tool, such as a mud motor with a bent sub, a rotary steerable system, a point-the-bit system, a push-the-bit system, a targeted bit speed (TBS] tool, etc.
- a directional drilling tool such as a mud motor with a bent sub, a rotary steerable system, a point-the-bit system, a push-the-bit system, a targeted bit speed (TBS] tool, etc.
- TBS targeted bit speed
Abstract
Description
Claims
Priority Applications (2)
Application Number | Priority Date | Filing Date | Title |
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CA2940627A CA2940627A1 (en) | 2014-02-24 | 2015-02-23 | Eccentric stabilizer for synchronous rotary steerable system |
US15/120,719 US20170058617A1 (en) | 2014-02-24 | 2015-02-23 | Eccentric Stabilizer for Use in a Synchronous Rotary Steerable System |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
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US201461943770P | 2014-02-24 | 2014-02-24 | |
US61/943,770 | 2014-02-24 |
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WO2015127345A2 true WO2015127345A2 (en) | 2015-08-27 |
WO2015127345A3 WO2015127345A3 (en) | 2016-03-10 |
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PCT/US2015/017048 WO2015127345A2 (en) | 2014-02-24 | 2015-02-23 | Eccentric stabilizer for synchronous rotary steerable system |
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US (1) | US20170058617A1 (en) |
CA (1) | CA2940627A1 (en) |
WO (1) | WO2015127345A2 (en) |
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US10415363B2 (en) | 2016-09-30 | 2019-09-17 | Weatherford Technology Holdings, Llc | Control for rotary steerable system |
US10641077B2 (en) | 2017-04-13 | 2020-05-05 | Weatherford Technology Holdings, Llc | Determining angular offset between geomagnetic and gravitational fields while drilling wellbore |
US11021912B2 (en) | 2018-07-02 | 2021-06-01 | Schlumberger Technology Corporation | Rotary steering systems and methods |
US11118406B2 (en) | 2018-07-02 | 2021-09-14 | Schlumberger Technology Corporation | Drilling systems and methods |
US11434696B2 (en) | 2018-07-02 | 2022-09-06 | Schlumberger Technology Corporation | Directional drilling systems and methods |
CN115822451A (en) * | 2022-06-28 | 2023-03-21 | 中国石油天然气集团有限公司 | Detachable directional drilling tool combined structure and directional drilling method |
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US11804679B2 (en) * | 2018-09-07 | 2023-10-31 | Cilag Gmbh International | Flexible hand-switch circuit |
CN110118080B (en) * | 2019-05-17 | 2023-12-19 | 中国地质大学(武汉) | Test device for simulating eccentric rotation of horizontal drilling drill rod |
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US4319649A (en) * | 1973-06-18 | 1982-03-16 | Jeter John D | Stabilizer |
US3856096A (en) * | 1973-11-09 | 1974-12-24 | E Williams | Drill string and drill collar therefor |
GB2121453A (en) * | 1982-05-18 | 1983-12-21 | Shell Int Research | Stabilizer/housing assembly and method for the directional drilling of boreholes |
-
2015
- 2015-02-23 US US15/120,719 patent/US20170058617A1/en not_active Abandoned
- 2015-02-23 WO PCT/US2015/017048 patent/WO2015127345A2/en active Application Filing
- 2015-02-23 CA CA2940627A patent/CA2940627A1/en not_active Abandoned
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US10641077B2 (en) | 2017-04-13 | 2020-05-05 | Weatherford Technology Holdings, Llc | Determining angular offset between geomagnetic and gravitational fields while drilling wellbore |
US11021912B2 (en) | 2018-07-02 | 2021-06-01 | Schlumberger Technology Corporation | Rotary steering systems and methods |
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US11434696B2 (en) | 2018-07-02 | 2022-09-06 | Schlumberger Technology Corporation | Directional drilling systems and methods |
CN115822451A (en) * | 2022-06-28 | 2023-03-21 | 中国石油天然气集团有限公司 | Detachable directional drilling tool combined structure and directional drilling method |
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Also Published As
Publication number | Publication date |
---|---|
US20170058617A1 (en) | 2017-03-02 |
CA2940627A1 (en) | 2015-08-27 |
WO2015127345A3 (en) | 2016-03-10 |
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