US20110240369A1 - Downhole Steerable Hammer Element - Google Patents
Downhole Steerable Hammer Element Download PDFInfo
- Publication number
- US20110240369A1 US20110240369A1 US12/752,323 US75232310A US2011240369A1 US 20110240369 A1 US20110240369 A1 US 20110240369A1 US 75232310 A US75232310 A US 75232310A US 2011240369 A1 US2011240369 A1 US 2011240369A1
- Authority
- US
- United States
- Prior art keywords
- tool string
- string component
- shaft
- piston
- disposed
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Abandoned
Links
- 238000005553 drilling Methods 0.000 claims description 20
- 239000012530 fluid Substances 0.000 claims description 18
- 238000010586 diagram Methods 0.000 description 23
- 230000015572 biosynthetic process Effects 0.000 description 18
- 238000005755 formation reaction Methods 0.000 description 18
- 239000000463 material Substances 0.000 description 8
- 230000005540 biological transmission Effects 0.000 description 1
- 230000015556 catabolic process Effects 0.000 description 1
- 238000006731 degradation reaction Methods 0.000 description 1
- 230000000593 degrading effect Effects 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 230000035515 penetration Effects 0.000 description 1
- 238000009527 percussion Methods 0.000 description 1
- 230000000737 periodic effect Effects 0.000 description 1
- 230000001902 propagating effect Effects 0.000 description 1
Images
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
- E21B4/00—Drives for drilling, used in the borehole
- E21B4/06—Down-hole impacting means, e.g. hammers
-
- 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
- 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 DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B4/00—Drives for drilling, used in the borehole
- E21B4/02—Fluid rotary type drives
-
- 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
- E21B47/00—Survey of boreholes or wells
- E21B47/02—Determining slope or direction
- E21B47/024—Determining slope or direction of devices in the borehole
-
- 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
- E21B47/00—Survey of boreholes or wells
- E21B47/12—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
Definitions
- This invention relates to the field of subterranean drilling.
- downhole hammers are used to affect periodic mechanical impacts upon a drill bit. Through this percussion, the drill string is able to more effectively apply drilling power to the formation, thus aiding penetration into the formation.
- a drill bit has an axis of rotation and drill bit body intermediate a threaded end and a working face.
- the drill bit body houses a jack element protruding from the drill bit body and the jack element has a plurality of inserts disposed on the indenting end.
- the plurality of inserts may be disposed primarily on one half of the indenting end.
- the plurality of inserts may be evenly distributed across the indenting end.
- the plurality of inserts may be attached to the jack element through a braze.
- the plurality of inserts may be attached to the jack element through a press fit.
- the plurality of inserts may comprise a flat ground portion, the flat ground portion disposed collinearly with an outer circumference of the jack element.
- the jack element may be substantially aligned along the axis of rotation.
- the jack element may comprise a connection with a shaft disposed intermediate the indenting end and a gearbox.
- the gearbox may be in mechanical communication with a generator such that the generator powers the gearbox.
- the connection may be a rotating spline such that the shaft may oscillate axially within the jack element.
- the shaft may be in mechanical communication with a piston, the piston circumferentially disposed around the shaft and slidably connected to the shaft.
- a first piston end and a second piston end may be selectively in fluid communication with a drilling mud flow such that the piston is actuated axially along the shaft according to which end of the piston is in fluid communication with the drilling mud flow.
- the jack element may also be rotated to a desired position within the drill bit through the connection.
- the piston may comprise a first contact surface, the first contact surface comprising a super hard material.
- the jack element may comprise a second contact surface, the second contact surface comprising a super hard material.
- the drill bit may comprise a valve which selectively allows a drilling mud flow to contact the piston.
- the shaft may be substantially collinear with the axis of rotation.
- the plurality of inserts on the indenting end may be evenly spaced along an insert cutting profile.
- the insert cutting profile may comprise a pattern, the pattern comprising overlapping cutting inserts.
- the plurality of inserts may comprise an axis, the axis being at most 25 degrees away from parallel with the axis of rotation.
- a tool string component has an axis of rotation and a drill bit body intermediate a threaded end and a working face.
- the drill bit body houses a jack element protruding from the working face.
- a shaft is rotationally connected and intermediate the jack element and a torque generating device.
- a torque generating device is connected to a porting assembly that causes a piston to move the jack element along a central axis of the shaft and independently of the drill bit body.
- the piston may comprise a friction resistant surface disposed on an inner diameter.
- the piston may be disposed within a substantially pressure-sealed cylinder.
- the pressure-sealed cylinder may comprise a first and second exhaust port such that a fluid within the pressure-sealed cylinder may be evacuated.
- the pressure-sealed cylinder may comprise a friction resistant surface.
- the shaft may comprise a friction resistant surface disposed on at least a portion of an outer diameter.
- the porting assembly may comprise a first and a second rotatable disk comprising a plurality of holes which when rotated, may allow a drilling fluid to pass through the plurality of holes.
- the porting assembly may comprise a multi-way valve which regulates the flow of a drilling fluid.
- the porting assembly may be in mechanical communication with the shaft such that the porting assembly may be rotated by the shaft.
- the torque generating device may be a generator.
- the generator may comprise a signal sent to an electronic processing device disposed within the component.
- a position feedback sensor may be disposed within the component and in electrical connection with the electronic processing device.
- the torque generating device may be a turbine.
- the piston may be disposed circumferentially around the shaft such that the shaft and piston share a slidable connection.
- the shaft may be rotationally connected to the jack element through a spline connection.
- the jack element may comprise an angled portion disposed on an indenting end of the jack element.
- the shaft may be substantially collinear with the axis of rotation.
- the porting assembly may divert a fluid flow to a first piston end or a second piston end.
- the electronic processing device may be in electrical communication with a direction and inclination tool.
- the electronic processing device may be part of a downhole telemetry network.
- FIG. 1 is a cross-sectional diagram of an embodiment of a tool string suspended in a borehole.
- FIG. 2 is a cross-sectional diagram of an embodiment of a tool string component.
- FIG. 3 is a perspective diagram of an embodiment of a portion of a tool string component.
- FIG. 4 a - b are cross-sectional diagrams of embodiments of a portion of a tool string component.
- FIG. 5 a - b are perspective diagrams of embodiments of a porting assembly.
- FIG. 6 is a perspective diagram of an embodiment of a spline connection on a shaft.
- FIG. 7 a - c are perspective diagrams of embodiments of an indenting end of a jack element.
- FIG. 8 is a cross-sectional diagram of an embodiment of a cutter profile.
- FIG. 9 is a cross-sectional diagram of an embodiment of a downhole tool string component.
- FIG. 10 is a cross-sectional diagram of an embodiment of a downhole telemetry network.
- FIG. 11 is a cross-sectional diagram of an embodiment of a piston in a downhole tool string component.
- FIG. 12 is a cross-sectional diagram of another embodiment of a downhole tool string component.
- FIG. 1 is a perspective diagram of an embodiment of a downhole tool string 100 suspended by a derrick 108 in a bore hole 102 .
- a drilling assembly 103 is located at the bottom of the bore hole 102 and comprises a drill bit 104 . As the drill bit 104 rotates downhole the downhole tool string 100 advances farther into the earth.
- the downhole tool string 100 may penetrate soft or hard subterranean formations 105 .
- the drilling assembly 103 and/or downhole components may comprise data acquisition devices which may gather data.
- the data may be sent to the surface via a transmission system to a data swivel 106 .
- the data swivel 106 may send the data to the surface equipment.
- the surface equipment may send data and/or power to downhole tools, the drill bit 104 and/or the drilling assembly 103 .
- the downhole tool string 100 may comprise a downhole tool.
- the downhole tool may be selected from the group consisting of drill pipe, drill collars, production pipe, and reamers.
- the downhole tool string 100 may be subjected to downhole drilling stresses as at least a portion of the weight of the drill string 100 is placed on the drill bit 104 . Those drilling stresses may be compressive stresses, tensile stresses, and/or torque stresses propagating through portions of the drill string 100 .
- FIG. 2 is a cross-sectional diagram of an embodiment of a tool string component 200 .
- the tool string component 200 may comprise a drill bit 104 comprising a jack element 202 with an indenting end 203 .
- the indenting end 203 may comprise a plurality of inserts 204 disposed in a pattern.
- the jack element 202 may be in mechanical communication with a shaft 205 .
- the jack element 202 and shaft 205 may be substantially collinear with an axis of rotation 206 of the tool string component 200 .
- the shaft 205 may rotate the jack element 202 .
- the shaft 205 may be disposed intermediate a gearbox 207 and the jack element 202 .
- the gearbox 207 may be in mechanical communication with a torque generating device 208 .
- the torque generating device 208 may be an electric motor or fluid driven turbine.
- the torque generating device 208 may rotate the shaft 205 .
- the shaft 205 may be rotated in a clockwise or counter clockwise direction and at a specific rotational velocity while the tool string component 200 is rotated in the opposite direction and the same rotational velocity as the shaft 205 .
- This rotation configuration may leave the shaft 205 and jack element 202 rotationally stationary with respect to the formation.
- the shaft 205 and the tool string component 200 may rotate in the same direction. In this case, the shaft 205 and jack 202 may rotate with respect to the formation.
- the shaft 205 may also be in mechanical communication with a piston 210 , the piston 210 circumferentially disposed around the shaft 205 and slidably connected to the shaft 205 .
- the piston 210 may be disposed intermediate the jack element 202 and the gear box 207 .
- FIG. 3 is a perspective diagram of an embodiment of a drill bit 104 .
- the jack element 202 can be seen in substantially the center of the drill bit 104 and comprising a plurality of inserts 204 .
- the jack element 202 may comprise an angled portion adapted to bias the tool string 100 in a desired direction.
- FIG. 4 a - b are cross-sectional diagrams of embodiments of a portion of a downhole tool string component 200 .
- the piston 210 can be seen proximate the jack element 202 .
- the piston 210 may comprise a first piston end 400 and a second piston end 401 .
- the piston 210 may be disposed within a pressure-sealed cylinder 300 .
- the pressure-sealed cylinder 300 may comprise at least one exhaust port 301 such that drilling fluid entering the pressure-sealed cylinder 300 may be exhausted into a borehole when needed.
- the pressure-sealed cylinder 300 may comprise a drilling mud under pressure such that as the drilling mud contacts the first or second end of the piston 400 / 401 , the piston 210 may be biased.
- FIG. 4 a shows the piston 210 in an extended position while FIG. 4 b shows the piston 210 in a retracted position.
- the shaft 205 within the tool component 200 may be in mechanical communication with the jack element 202 through a connection.
- the connection may be a rotary spline.
- the jack element 202 may slide axially along the shaft 205 .
- the shaft 205 may rotate the jack element 202 such that as the tool string component 200 rotates, the shaft 205 and jack element 202 rotate in an opposite direction, leaving the jack element 202 stationary in relation to the formation.
- An angled portion of the jack element 202 may guide the drill bit 104 along a direction within the formation.
- FIG. 5 a - b are perspective diagrams of embodiments of a porting assembly 550 .
- the porting assembly 550 may comprise a first and a second disc 298 / 299 .
- the first disc and the second disc 298 / 299 may be placed one on top of the other and adapted to rotate.
- the first and second disc 298 / 299 may also comprise a plurality of holes 292 such that as the porting assembly 550 is rotated, the plurality of holes 292 align and misalign.
- the porting assembly may be in fluid communication with a fluid flow within the tool string 100 . As the plurality of holes align and misalign, the fluid flow may be diverted to one or another channel leading to an end of the piston chamber. As the flow reaches an end of the chamber, the piston may be forced to move.
- FIG. 6 is a perspective diagram of an embodiment of a rotary spline connection 422 on a shaft 205 .
- the rotary spline 422 may be adapted to mechanically connect with a jack 202 .
- the jack 202 may move along the rotary spline 422 while continuing to rotate from the force of the shaft 205 on the rotary spline 422 . In this way, the jack 202 may move axially to impact the formation while simultaneously rotating axially.
- FIG. 7 a - c are perspective diagrams of embodiments of an indenting end of a jack element 202 that disclose possible cutter insert arrangements.
- the cutter inserts may be brazed or press-fit into the indenting end of the jack element 202 .
- the degrading end may comprise an angled portion adapted to bias the jack element 202 in a specific direction.
- the cutting inserts are disposed primarily on one side of the indenting end whereas in FIG. 7 c , the cutting inserts are disposed substantially evenly on the indenting end.
- the plurality of inserts may include a central insert disposed substantially in the center of the indenting end and inserts surrounding the central insert.
- FIG. 7 c shows a plurality of inserts on an indenting end.
- as least one of the circumferentially spaced inserts comprises a portion 625 ground with a radius that may substantially match a radius of the jack element 202 and be disposed collinearly with an outer circumference of the jack element 202 .
- the central axis of the circumferentially spaced inserts may be non-collinear with the central axis of the jack element 202 . Tilting the central axis of the inserts may expand a cutting diameter determined by the distance from the center of the jack element to the point of a cutting insert. As the cutting insert is tilted, the distance between the center of the jack element and the point of the cutting insert may increase.
- FIG. 7 b shows a plurality of cutting inserts disposed on the outer circumference of the indenting end of the jack element.
- One of the plurality of cutting inserts may be disposed on an angled surface of the jack element. As the jack element 202 is forced into the formation, the angle on the jack element 202 may bias the direction of travel of the jack element 202 within the formation. Mounting an insert on the angled portion of the jack element 202 may increase the life of the indenting end and aid in the degradation of the formation.
- FIG. 8 is a cross-sectional diagram of an embodiment of a cutter profile 444 on a jack 202 .
- the jack 202 may comprise a plurality of inserts 204 .
- the inserts 204 may be attached to the jack 202 through a braze.
- the inserts 204 may also be attached to the jack 202 through a press fit.
- the inserts 204 may be substantially evenly spaced such that as the jack 204 contacts the formation, the formation may evenly be degraded and/or an equal portion of the formation may be contacted.
- the cutter profile 444 may include inserts 204 which overlap. Thus, the space between inserts 204 may vary leading to more closely spaced or more distantly spaced inserts 204 .
- the inserts 204 may be placed on the jack 202 such that their central axis 488 is as much as 25 degrees away from vertical with reference to the axis of rotation 206 of the jack 202 .
- FIG. 9 is a cross-sectional diagram on an embodiment of a portion of a downhole tool string 100 .
- the downhole tool string 100 may comprise a Direction and Inclination package which will be herein referred to as D & I.
- the D & I may be in electrical communication with an electronic processing device 330 disposed on the tool string 100 .
- the D & I may evaluate the orientation of the tool string 100 in relation to the Earth or other standard.
- the electronic processing device 330 may also be in electrical communication with a position sensor 331 disposed on or adjacent to the shaft 205 .
- the position sensor 331 may send the electronic processing device 330 signals relating to the position of the shaft 205 , and thus, the position of the jack 202 .
- Electrical line 384 displays a connection between the position sensor 331 and electronic processing device 330 .
- a generator 385 may be electrically connected to the electronic processing device 331 such that all incoming signals may be processed for use by a drilling operator or for other purposes.
- FIG. 10 discloses a downhole network 717 that may be used to transmit information along a tool string 100 .
- the network 717 may include multiple nodes 718 a - e spaced up and down a tool string 100 .
- the nodes 718 a - e may be intelligent computing devices 718 a - e , or may be less intelligent connection devices, such as hubs or switches located along the length of the network 717 .
- Each of the nodes 718 may or may not be addressed on the network 717 .
- a node 718 e may be located to interface with a bottom hole assembly 103 located at the end of the tool string 100 .
- a bottom hole assembly 103 may include a drill bit, drill collar, and other downhole tools and sensors designed to gather data and perform various tasks.
- the downhole network 717 may be in electrical communication with an uphole computing device 728 .
- the electronic processing device 331 and D&I may be in electrical communication with the downhole network 717 .
- Transmitting the jack element's orientation signal to the surface may allow drillers to make real time decisions and correct drill string trajectories that are off of the desired path before trajectory correction.
- the signal may be transmitted wirelessly to off site locations once the signal is at the surface. Such an embodiment would allow drilling experts to position themselves in a central location and monitor multiple wells at once.
- FIG. 11 displays a cross-sectional diagram of an embodiment of a portion of a tool string component 100 .
- the shaft 205 within the tool string component 100 may comprise a super hard material 230 disposed on an outer diameter of the shaft 205 may provide an increase in wear resistance.
- the piston 210 may also comprise a super hard material 239 .
- the piston 210 may comprise a super hard material 800 disposed on a contact end of the piston 210 adjacent to the jack 202 and the jack 202 may comprise a super hard material 801 adjacent the piston 210 such that as the piston 210 contacts the jack 202 , the super hard material from the piston 210 contacts the super hard material from the jack 202 contact each other.
- FIG. 12 discloses a cross-sectional diagram of another embodiment of a portion of a tool string 100 .
- the tool string 100 may comprise a shaft 205 comprising tabs 269 .
- the tabs 269 rotate as well, contacting a multi-way valve 293 .
- the first time the multi-way valve 293 is contacted it may be actuated to allow a fluid flow into a channel leading to a first piston end 400 .
- the multi-way valve is actuated again, it may allow the fluid flow into a different channel leading to the second piston end 401 .
Abstract
In one aspect of the present invention, a drill bit has an axis of rotation and drill bit body intermediate a threaded end and a working face. The drill bit body houses a jack element protruding from the drill bit body and the jack element has a plurality of inserts disposed on the indenting end.
Description
- This invention relates to the field of subterranean drilling. Typically, downhole hammers are used to affect periodic mechanical impacts upon a drill bit. Through this percussion, the drill string is able to more effectively apply drilling power to the formation, thus aiding penetration into the formation.
- In one aspect of the present invention, a drill bit has an axis of rotation and drill bit body intermediate a threaded end and a working face. The drill bit body houses a jack element protruding from the drill bit body and the jack element has a plurality of inserts disposed on the indenting end.
- The plurality of inserts may be disposed primarily on one half of the indenting end. The plurality of inserts may be evenly distributed across the indenting end. The plurality of inserts may be attached to the jack element through a braze. The plurality of inserts may be attached to the jack element through a press fit. The plurality of inserts may comprise a flat ground portion, the flat ground portion disposed collinearly with an outer circumference of the jack element.
- The jack element may be substantially aligned along the axis of rotation. The jack element may comprise a connection with a shaft disposed intermediate the indenting end and a gearbox. The gearbox may be in mechanical communication with a generator such that the generator powers the gearbox. The connection may be a rotating spline such that the shaft may oscillate axially within the jack element.
- The shaft may be in mechanical communication with a piston, the piston circumferentially disposed around the shaft and slidably connected to the shaft. A first piston end and a second piston end may be selectively in fluid communication with a drilling mud flow such that the piston is actuated axially along the shaft according to which end of the piston is in fluid communication with the drilling mud flow. As the shaft is rotated, the jack element may also be rotated to a desired position within the drill bit through the connection. The piston may comprise a first contact surface, the first contact surface comprising a super hard material. The jack element may comprise a second contact surface, the second contact surface comprising a super hard material.
- The drill bit may comprise a valve which selectively allows a drilling mud flow to contact the piston. The shaft may be substantially collinear with the axis of rotation. The plurality of inserts on the indenting end may be evenly spaced along an insert cutting profile. The insert cutting profile may comprise a pattern, the pattern comprising overlapping cutting inserts. The plurality of inserts may comprise an axis, the axis being at most 25 degrees away from parallel with the axis of rotation.
- In another aspect of the present invention, a tool string component has an axis of rotation and a drill bit body intermediate a threaded end and a working face. The drill bit body houses a jack element protruding from the working face. A shaft is rotationally connected and intermediate the jack element and a torque generating device. A torque generating device is connected to a porting assembly that causes a piston to move the jack element along a central axis of the shaft and independently of the drill bit body.
- The piston may comprise a friction resistant surface disposed on an inner diameter. The piston may be disposed within a substantially pressure-sealed cylinder. The pressure-sealed cylinder may comprise a first and second exhaust port such that a fluid within the pressure-sealed cylinder may be evacuated. The pressure-sealed cylinder may comprise a friction resistant surface. The shaft may comprise a friction resistant surface disposed on at least a portion of an outer diameter.
- The porting assembly may comprise a first and a second rotatable disk comprising a plurality of holes which when rotated, may allow a drilling fluid to pass through the plurality of holes. The porting assembly may comprise a multi-way valve which regulates the flow of a drilling fluid. The porting assembly may be in mechanical communication with the shaft such that the porting assembly may be rotated by the shaft. The torque generating device may be a generator. The generator may comprise a signal sent to an electronic processing device disposed within the component. A position feedback sensor may be disposed within the component and in electrical connection with the electronic processing device. The torque generating device may be a turbine.
- The piston may be disposed circumferentially around the shaft such that the shaft and piston share a slidable connection. The shaft may be rotationally connected to the jack element through a spline connection. The jack element may comprise an angled portion disposed on an indenting end of the jack element. The shaft may be substantially collinear with the axis of rotation. The porting assembly may divert a fluid flow to a first piston end or a second piston end. The electronic processing device may be in electrical communication with a direction and inclination tool. The electronic processing device may be part of a downhole telemetry network.
-
FIG. 1 is a cross-sectional diagram of an embodiment of a tool string suspended in a borehole. -
FIG. 2 is a cross-sectional diagram of an embodiment of a tool string component. -
FIG. 3 is a perspective diagram of an embodiment of a portion of a tool string component. -
FIG. 4 a-b are cross-sectional diagrams of embodiments of a portion of a tool string component. -
FIG. 5 a-b are perspective diagrams of embodiments of a porting assembly. -
FIG. 6 is a perspective diagram of an embodiment of a spline connection on a shaft.FIG. 7 a-c are perspective diagrams of embodiments of an indenting end of a jack element. -
FIG. 8 is a cross-sectional diagram of an embodiment of a cutter profile. -
FIG. 9 is a cross-sectional diagram of an embodiment of a downhole tool string component. -
FIG. 10 is a cross-sectional diagram of an embodiment of a downhole telemetry network. -
FIG. 11 is a cross-sectional diagram of an embodiment of a piston in a downhole tool string component. -
FIG. 12 is a cross-sectional diagram of another embodiment of a downhole tool string component. -
FIG. 1 is a perspective diagram of an embodiment of adownhole tool string 100 suspended by aderrick 108 in abore hole 102. Adrilling assembly 103 is located at the bottom of thebore hole 102 and comprises adrill bit 104. As thedrill bit 104 rotates downhole thedownhole tool string 100 advances farther into the earth. Thedownhole tool string 100 may penetrate soft or hardsubterranean formations 105. Thedrilling assembly 103 and/or downhole components may comprise data acquisition devices which may gather data. The data may be sent to the surface via a transmission system to adata swivel 106. The data swivel 106 may send the data to the surface equipment. Further, the surface equipment may send data and/or power to downhole tools, thedrill bit 104 and/or thedrilling assembly 103. Thedownhole tool string 100 may comprise a downhole tool. The downhole tool may be selected from the group consisting of drill pipe, drill collars, production pipe, and reamers. Thedownhole tool string 100 may be subjected to downhole drilling stresses as at least a portion of the weight of thedrill string 100 is placed on thedrill bit 104. Those drilling stresses may be compressive stresses, tensile stresses, and/or torque stresses propagating through portions of thedrill string 100. -
FIG. 2 is a cross-sectional diagram of an embodiment of atool string component 200. Thetool string component 200 may comprise adrill bit 104 comprising ajack element 202 with an indentingend 203. The indentingend 203 may comprise a plurality ofinserts 204 disposed in a pattern. Thejack element 202 may be in mechanical communication with ashaft 205. Thejack element 202 andshaft 205 may be substantially collinear with an axis ofrotation 206 of thetool string component 200. Theshaft 205 may rotate thejack element 202. Theshaft 205 may be disposed intermediate agearbox 207 and thejack element 202. Thegearbox 207 may be in mechanical communication with atorque generating device 208. Thetorque generating device 208 may be an electric motor or fluid driven turbine. Thetorque generating device 208 may rotate theshaft 205. Theshaft 205 may be rotated in a clockwise or counter clockwise direction and at a specific rotational velocity while thetool string component 200 is rotated in the opposite direction and the same rotational velocity as theshaft 205. This rotation configuration may leave theshaft 205 andjack element 202 rotationally stationary with respect to the formation. In some instances, theshaft 205 and thetool string component 200 may rotate in the same direction. In this case, theshaft 205 andjack 202 may rotate with respect to the formation. Theshaft 205 may also be in mechanical communication with apiston 210, thepiston 210 circumferentially disposed around theshaft 205 and slidably connected to theshaft 205. Thepiston 210 may be disposed intermediate thejack element 202 and thegear box 207. -
FIG. 3 is a perspective diagram of an embodiment of adrill bit 104. Thejack element 202 can be seen in substantially the center of thedrill bit 104 and comprising a plurality ofinserts 204. Thejack element 202 may comprise an angled portion adapted to bias thetool string 100 in a desired direction. -
FIG. 4 a-b are cross-sectional diagrams of embodiments of a portion of a downholetool string component 200. Thepiston 210 can be seen proximate thejack element 202. Thepiston 210 may comprise afirst piston end 400 and asecond piston end 401. Thepiston 210 may be disposed within a pressure-sealedcylinder 300. The pressure-sealedcylinder 300 may comprise at least oneexhaust port 301 such that drilling fluid entering the pressure-sealedcylinder 300 may be exhausted into a borehole when needed. The pressure-sealedcylinder 300 may comprise a drilling mud under pressure such that as the drilling mud contacts the first or second end of thepiston 400/401, thepiston 210 may be biased. As thepiston 210 is biased, thepiston 210 may contact thejack element 202. Thejack element 202 may then contact a formation. The drilling fluid may then be rerouted to the opposite end of thepiston 202 so as to bias thepiston 202 in the opposite direction. As thejack element 202 contacts the formation and retracts back into thedrill bit 104, the formation may be impacted.FIG. 4 a shows thepiston 210 in an extended position whileFIG. 4 b shows thepiston 210 in a retracted position. - The
shaft 205 within thetool component 200 may be in mechanical communication with thejack element 202 through a connection. The connection may be a rotary spline. Thejack element 202 may slide axially along theshaft 205. Theshaft 205 may rotate thejack element 202 such that as thetool string component 200 rotates, theshaft 205 andjack element 202 rotate in an opposite direction, leaving thejack element 202 stationary in relation to the formation. An angled portion of thejack element 202 may guide thedrill bit 104 along a direction within the formation. -
FIG. 5 a-b are perspective diagrams of embodiments of a portingassembly 550. The portingassembly 550 may comprise a first and asecond disc 298/299. During operation, the first disc and thesecond disc 298/299 may be placed one on top of the other and adapted to rotate. The first andsecond disc 298/299 may also comprise a plurality ofholes 292 such that as the portingassembly 550 is rotated, the plurality ofholes 292 align and misalign. The porting assembly may be in fluid communication with a fluid flow within thetool string 100. As the plurality of holes align and misalign, the fluid flow may be diverted to one or another channel leading to an end of the piston chamber. As the flow reaches an end of the chamber, the piston may be forced to move. -
FIG. 6 is a perspective diagram of an embodiment of arotary spline connection 422 on ashaft 205. Therotary spline 422 may be adapted to mechanically connect with ajack 202. As thejack 202 is forced towards the formation by the piston 210 (shown inFIG. 4 a) thejack 202 may move along therotary spline 422 while continuing to rotate from the force of theshaft 205 on therotary spline 422. In this way, thejack 202 may move axially to impact the formation while simultaneously rotating axially. -
FIG. 7 a-c are perspective diagrams of embodiments of an indenting end of ajack element 202 that disclose possible cutter insert arrangements. Generally, the cutter inserts may be brazed or press-fit into the indenting end of thejack element 202. The degrading end may comprise an angled portion adapted to bias thejack element 202 in a specific direction. In the case ofFIG. 7 a, the cutting inserts are disposed primarily on one side of the indenting end whereas inFIG. 7 c, the cutting inserts are disposed substantially evenly on the indenting end. The plurality of inserts may include a central insert disposed substantially in the center of the indenting end and inserts surrounding the central insert.FIG. 7 c shows a plurality of inserts on an indenting end. In this embodiment, as least one of the circumferentially spaced inserts comprises aportion 625 ground with a radius that may substantially match a radius of thejack element 202 and be disposed collinearly with an outer circumference of thejack element 202. The central axis of the circumferentially spaced inserts may be non-collinear with the central axis of thejack element 202. Tilting the central axis of the inserts may expand a cutting diameter determined by the distance from the center of the jack element to the point of a cutting insert. As the cutting insert is tilted, the distance between the center of the jack element and the point of the cutting insert may increase.FIG. 7 b shows a plurality of cutting inserts disposed on the outer circumference of the indenting end of the jack element. One of the plurality of cutting inserts may be disposed on an angled surface of the jack element. As thejack element 202 is forced into the formation, the angle on thejack element 202 may bias the direction of travel of thejack element 202 within the formation. Mounting an insert on the angled portion of thejack element 202 may increase the life of the indenting end and aid in the degradation of the formation. -
FIG. 8 is a cross-sectional diagram of an embodiment of acutter profile 444 on ajack 202. Thejack 202 may comprise a plurality ofinserts 204. Theinserts 204 may be attached to thejack 202 through a braze. Theinserts 204 may also be attached to thejack 202 through a press fit. Theinserts 204 may be substantially evenly spaced such that as thejack 204 contacts the formation, the formation may evenly be degraded and/or an equal portion of the formation may be contacted. As can be seen, thecutter profile 444 may includeinserts 204 which overlap. Thus, the space betweeninserts 204 may vary leading to more closely spaced or more distantly spaced inserts 204. Theinserts 204 may be placed on thejack 202 such that theircentral axis 488 is as much as 25 degrees away from vertical with reference to the axis ofrotation 206 of thejack 202. -
FIG. 9 is a cross-sectional diagram on an embodiment of a portion of adownhole tool string 100. Thedownhole tool string 100 may comprise a Direction and Inclination package which will be herein referred to as D & I. The D & I may be in electrical communication with anelectronic processing device 330 disposed on thetool string 100. The D & I may evaluate the orientation of thetool string 100 in relation to the Earth or other standard. Theelectronic processing device 330 may also be in electrical communication with aposition sensor 331 disposed on or adjacent to theshaft 205. Theposition sensor 331 may send theelectronic processing device 330 signals relating to the position of theshaft 205, and thus, the position of thejack 202.Electrical line 384 displays a connection between theposition sensor 331 andelectronic processing device 330. Also, agenerator 385 may be electrically connected to theelectronic processing device 331 such that all incoming signals may be processed for use by a drilling operator or for other purposes. -
FIG. 10 discloses adownhole network 717 that may be used to transmit information along atool string 100. Thenetwork 717 may include multiple nodes 718 a-e spaced up and down atool string 100. The nodes 718 a-e may be intelligent computing devices 718 a-e, or may be less intelligent connection devices, such as hubs or switches located along the length of thenetwork 717. Each of the nodes 718 may or may not be addressed on thenetwork 717. Anode 718 e may be located to interface with abottom hole assembly 103 located at the end of thetool string 100. Abottom hole assembly 103 may include a drill bit, drill collar, and other downhole tools and sensors designed to gather data and perform various tasks. - As signals from downhole tools are obtained, they may be transmitted uphole or downhole using the
downhole network 717. This may assist downhole tools in communicating with each other. Thedownhole network 717 may be in electrical communication with anuphole computing device 728. Theelectronic processing device 331 and D&I may be in electrical communication with thedownhole network 717. - Transmitting the jack element's orientation signal to the surface may allow drillers to make real time decisions and correct drill string trajectories that are off of the desired path before trajectory correction. In some embodiments, the signal may be transmitted wirelessly to off site locations once the signal is at the surface. Such an embodiment would allow drilling experts to position themselves in a central location and monitor multiple wells at once.
-
FIG. 11 displays a cross-sectional diagram of an embodiment of a portion of atool string component 100. Theshaft 205 within thetool string component 100 may comprise a superhard material 230 disposed on an outer diameter of theshaft 205 may provide an increase in wear resistance. Thepiston 210 may also comprise a superhard material 239. Additionally, thepiston 210 may comprise a superhard material 800 disposed on a contact end of thepiston 210 adjacent to thejack 202 and thejack 202 may comprise a superhard material 801 adjacent thepiston 210 such that as thepiston 210 contacts thejack 202, the super hard material from thepiston 210 contacts the super hard material from thejack 202 contact each other. -
FIG. 12 discloses a cross-sectional diagram of another embodiment of a portion of atool string 100. Thetool string 100 may comprise ashaft 205 comprisingtabs 269. As theshaft 205 rotates, thetabs 269 rotate as well, contacting amulti-way valve 293. The first time themulti-way valve 293 is contacted, it may be actuated to allow a fluid flow into a channel leading to afirst piston end 400. As the multi-way valve is actuated again, it may allow the fluid flow into a different channel leading to thesecond piston end 401. - Whereas the present invention has been described in particular relation to the drawings attached hereto, it should be understood that other and further modifications apart from those shown or suggested herein, may be made within the scope and spirit of the present invention.
Claims (20)
1. A tool string component, comprising:
an axis of rotation and a drill bit body intermediate a threaded end and a working face;
the drill bit body housing a jack element protruding from the working face;
a shaft rotationally connected and intermediate the jack element and a torque generating device; and
a torque generating device connected to a porting assembly that causes a piston disposed around the shaft to move the jack element along a central axis of the shaft and independently of the drill bit body.
2. The tool string component of claim 1 , wherein the piston comprises a friction resistant surface disposed on an inner diameter.
3. The tool string component of claim 1 , wherein the piston is disposed within a substantially pressure-sealed cylinder.
4. The tool string component of claim 3 , wherein the pressure-sealed cylinder comprises a first and second exhaust port such that a fluid within the pressure-sealed cylinder may be evacuated.
5. The tool string component of claim 3 , wherein the pressure-sealed cylinder comprises a friction resistant surface.
6. The tool string component of claim 1 , wherein the shaft comprises a friction resistant surface disposed on at least a portion of an outer diameter.
7. The tool string component of claim 1 , wherein the porting assembly comprises a first and a second rotatable disk comprising a plurality of holes which when rotated, may allow a drilling fluid to pass through the plurality of holes.
8. The tool string component of claim 1 , wherein the porting assembly comprises a multi-way valve which regulates the flow of a drilling fluid.
9. The tool string component of claim 1 , wherein the porting assembly is in mechanical communication with the shaft such that the porting assembly may be rotated by the shaft.
10. The tool string component of claim 1 , wherein the torque generating device is a generator.
11. The tool string component of claim 10 , wherein the generator comprises a signal sent to an electronic processing device disposed within the component.
12. The tool string component of claim 11 , wherein a position feedback sensor is disposed within the component and in electrical connection with the electronic processing device.
13. The tool string component of claim 1 , wherein the torque generating device is a turbine.
14. The tool string component of claim 1 , wherein the piston is disposed circumferentially around the shaft such that the shaft and piston share a slidable connection.
15. The tool string component of claim 1 , wherein the shaft is rotationally connected to the jack element through a spline connection.
16. The tool string component of claim 1 , wherein the jack element comprises an angled portion disposed on an indenting end of the jack element.
17. The tool string component of claim 1 , wherein the shaft is substantially collinear with the axis of rotation.
18. The tool string component of claim 1 , wherein the porting assembly diverts a fluid flow to a first piston end or a second piston end.
19. The tool string component of claim 18 , wherein the electronic processing device is in electrical communication with a direction and inclination tool.
20. The tool string component of claim 1 , wherein the electronic processing device is part of a downhole telemetry network.
Priority Applications (6)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US12/752,349 US20110240377A1 (en) | 2010-04-01 | 2010-04-01 | Drill Bit Jack Element with a Plurality of Inserts |
US12/752,323 US20110240369A1 (en) | 2010-04-01 | 2010-04-01 | Downhole Steerable Hammer Element |
US12/894,371 US8550190B2 (en) | 2010-04-01 | 2010-09-30 | Inner bit disposed within an outer bit |
US29/376,990 USD678368S1 (en) | 2007-02-12 | 2010-10-15 | Drill bit with a pointed cutting element |
US29/376,995 USD674422S1 (en) | 2007-02-12 | 2010-10-15 | Drill bit with a pointed cutting element and a shearing cutting element |
US12/957,012 US20110240378A1 (en) | 2010-04-01 | 2010-11-30 | Tapered Blade Profile on an Outer Bit |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US12/752,323 US20110240369A1 (en) | 2010-04-01 | 2010-04-01 | Downhole Steerable Hammer Element |
Related Parent Applications (3)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US12/619,305 Continuation-In-Part US8567532B2 (en) | 2006-08-11 | 2009-11-16 | Cutting element attached to downhole fixed bladed bit at a positive rake angle |
US12/755,534 Continuation-In-Part US20110247882A1 (en) | 2010-04-01 | 2010-04-07 | Exhaust Port in a Protruding Element of a Downhole Drill Bit |
US29/376,990 Continuation-In-Part USD678368S1 (en) | 2007-02-12 | 2010-10-15 | Drill bit with a pointed cutting element |
Related Child Applications (3)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US12/752,349 Continuation US20110240377A1 (en) | 2010-04-01 | 2010-04-01 | Drill Bit Jack Element with a Plurality of Inserts |
US12/766,555 Continuation-In-Part US8839888B2 (en) | 2007-02-12 | 2010-04-23 | Tracking shearing cutters on a fixed bladed drill bit with pointed cutting elements |
US12/894,371 Continuation-In-Part US8550190B2 (en) | 2010-04-01 | 2010-09-30 | Inner bit disposed within an outer bit |
Publications (1)
Publication Number | Publication Date |
---|---|
US20110240369A1 true US20110240369A1 (en) | 2011-10-06 |
Family
ID=44708309
Family Applications (2)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US12/752,323 Abandoned US20110240369A1 (en) | 2007-02-12 | 2010-04-01 | Downhole Steerable Hammer Element |
US12/752,349 Abandoned US20110240377A1 (en) | 2010-04-01 | 2010-04-01 | Drill Bit Jack Element with a Plurality of Inserts |
Family Applications After (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US12/752,349 Abandoned US20110240377A1 (en) | 2010-04-01 | 2010-04-01 | Drill Bit Jack Element with a Plurality of Inserts |
Country Status (1)
Country | Link |
---|---|
US (2) | US20110240369A1 (en) |
Cited By (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US8869916B2 (en) | 2010-09-09 | 2014-10-28 | National Oilwell Varco, L.P. | Rotary steerable push-the-bit drilling apparatus with self-cleaning fluid filter |
US9016400B2 (en) | 2010-09-09 | 2015-04-28 | National Oilwell Varco, L.P. | Downhole rotary drilling apparatus with formation-interfacing members and control system |
US10590710B2 (en) | 2016-12-09 | 2020-03-17 | Baker Hughes, A Ge Company, Llc | Cutting elements, earth-boring tools including the cutting elements, and methods of forming the cutting elements |
Citations (7)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3387673A (en) * | 1966-03-15 | 1968-06-11 | Ingersoll Rand Co | Rotary percussion gang drill |
US3682258A (en) * | 1970-06-22 | 1972-08-08 | Hughes Tool Co | Rotary-percussion gang drill with circumferentially floating offset bits |
US6488103B1 (en) * | 2001-01-03 | 2002-12-03 | Gas Research Institute | Drilling tool and method of using same |
US7198119B1 (en) * | 2005-11-21 | 2007-04-03 | Hall David R | Hydraulic drill bit assembly |
US7207398B2 (en) * | 2001-07-16 | 2007-04-24 | Shell Oil Company | Steerable rotary drill bit assembly with pilot bit |
US7461706B2 (en) * | 2001-06-05 | 2008-12-09 | Andergauge Limited | Drilling apparatus with percussive action cutter |
US20090057016A1 (en) * | 2005-11-21 | 2009-03-05 | Hall David R | Downhole Turbine |
Family Cites Families (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
DE1198765B (en) * | 1963-12-30 | 1965-08-19 | Gewerk Eisenhuette Westfalia | Extraction or jacking machine with cutting or hitting rotating tools |
DE4114457C1 (en) * | 1991-05-03 | 1992-06-25 | Ing. Guenter Klemm Bohrtechnik Gmbh, 5962 Drolshagen, De |
-
2010
- 2010-04-01 US US12/752,323 patent/US20110240369A1/en not_active Abandoned
- 2010-04-01 US US12/752,349 patent/US20110240377A1/en not_active Abandoned
Patent Citations (7)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3387673A (en) * | 1966-03-15 | 1968-06-11 | Ingersoll Rand Co | Rotary percussion gang drill |
US3682258A (en) * | 1970-06-22 | 1972-08-08 | Hughes Tool Co | Rotary-percussion gang drill with circumferentially floating offset bits |
US6488103B1 (en) * | 2001-01-03 | 2002-12-03 | Gas Research Institute | Drilling tool and method of using same |
US7461706B2 (en) * | 2001-06-05 | 2008-12-09 | Andergauge Limited | Drilling apparatus with percussive action cutter |
US7207398B2 (en) * | 2001-07-16 | 2007-04-24 | Shell Oil Company | Steerable rotary drill bit assembly with pilot bit |
US7198119B1 (en) * | 2005-11-21 | 2007-04-03 | Hall David R | Hydraulic drill bit assembly |
US20090057016A1 (en) * | 2005-11-21 | 2009-03-05 | Hall David R | Downhole Turbine |
Cited By (4)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US8869916B2 (en) | 2010-09-09 | 2014-10-28 | National Oilwell Varco, L.P. | Rotary steerable push-the-bit drilling apparatus with self-cleaning fluid filter |
US9016400B2 (en) | 2010-09-09 | 2015-04-28 | National Oilwell Varco, L.P. | Downhole rotary drilling apparatus with formation-interfacing members and control system |
US9476263B2 (en) | 2010-09-09 | 2016-10-25 | National Oilwell Varco, L.P. | Rotary steerable push-the-bit drilling apparatus with self-cleaning fluid filter |
US10590710B2 (en) | 2016-12-09 | 2020-03-17 | Baker Hughes, A Ge Company, Llc | Cutting elements, earth-boring tools including the cutting elements, and methods of forming the cutting elements |
Also Published As
Publication number | Publication date |
---|---|
US20110240377A1 (en) | 2011-10-06 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
US10731419B2 (en) | Earth-boring tools including retractable pads | |
US8550190B2 (en) | Inner bit disposed within an outer bit | |
US7559379B2 (en) | Downhole steering | |
US7506701B2 (en) | Drill bit assembly for directional drilling | |
US8567524B2 (en) | Downhole apparatus with a wireless data communication device between rotating and non-rotating members | |
US20080302572A1 (en) | Drill Bit Porting System | |
US20140305709A1 (en) | Dual Pipe Drilling Head With Improved Bearing Retention Structure | |
US20120080234A1 (en) | Drill Bit Steering Assembly | |
US20110240369A1 (en) | Downhole Steerable Hammer Element | |
US10914120B2 (en) | Flexible collar for a rotary steerable system | |
US20180179828A1 (en) | Oil and gas well drill pipe electrical and communication assembly | |
US8132622B2 (en) | Surface instrumentation configuration for drilling rig operation | |
US10577917B2 (en) | Downhole drill bit chassis | |
US8955586B1 (en) | Beacon assembly | |
CN114599857A (en) | Downhole communication system | |
AU2012391485B2 (en) | Multiple channel rotary electrical connector | |
US20210189871A1 (en) | Downhole communication system | |
US20200208472A1 (en) | Steerable downhole drilling tool | |
US7967083B2 (en) | Sensor for determining a position of a jack element | |
US20180016850A1 (en) | Downhole Outer Drill Bit |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
AS | Assignment |
Owner name: HALL, DAVID R., UTAH Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:DAHLGREN, SCOTT;MARSHALL, JONATHAN;REEL/FRAME:027198/0272 Effective date: 20100329 |
|
STCB | Information on status: application discontinuation |
Free format text: ABANDONED -- FAILURE TO RESPOND TO AN OFFICE ACTION |
|
AS | Assignment |
Owner name: NOVATEK IP, LLC, UTAH Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNOR:HALL, DAVID R.;REEL/FRAME:036109/0109 Effective date: 20150715 |