US3497019A - Automatic drilling system - Google Patents

Automatic drilling system Download PDF

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US3497019A
US3497019A US3497019DA US3497019A US 3497019 A US3497019 A US 3497019A US 3497019D A US3497019D A US 3497019DA US 3497019 A US3497019 A US 3497019A
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piston
lower
bit
upper
pressure
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John E Ortloff
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ExxonMobil Upstream Research Co
Esso Products Research Co
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ExxonMobil Upstream Research Co
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    • EFIXED CONSTRUCTIONS
    • E21EARTH DRILLING; MINING
    • E21BEARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B44/00Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
    • E21B44/005Below-ground automatic control systems
    • EFIXED CONSTRUCTIONS
    • E21EARTH DRILLING; MINING
    • E21BEARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B44/00Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
    • E21B44/02Automatic control of the tool feed

Description

5 Sheets-Sheet 1 Filed Feb. 5, 1968 JOHN E. ORTLOFF INVENTOR.

ATTORNEY Feb. 24, 1970 J. E. ORTLOFF 3,497,019

AUTOMATIC DRILLING SYSTEM Filed Feb. 5, 1968 3 Sheets-Sheet 2 ll f I83 :M/ I

JOHN E. ORTLOFF INVENTOR.

BYWEQMJ ATTORNEY Feb. 24, 1970 J. E. ORTLOFF 3,497,019

AUTOMATIC DRILLING SYSTEM Filed Feb. 5, 1968 3 Sheets-Sheet 5 ATTORNEY FIG 53 JOHN E. ORTLOFF INVENTOR.

J S 950 4 -2 4 6 44% 4 $2M O QO 22 2 222 2 United States Patent 3,497,019 AUTOMATIC DRILLING SYSTEM John E. Ortloff, Tiburon, Calitl, assignor to Esso Production Research Company, a corporation of Delaware Filed Feb. 5, 1968, Ser. No. 702,882 Int. Cl. E21c /00 U.S. Cl. 17527 6 Claims ABSTRACT OF THE DISCLOSURE Apparatus for drilling a borehole in the earth including a drill string, a bit-weight applicator including extensible members for anchoring the drill string to the borehole wall and a reciprocating piston for forcing a drill bit against the bottom of the borehole, means for transmitting a signal to the surface when the piston reaches the end of its stroke, and means for lowering the drill string and resetting the piston in response to the signal to permit continued drilling.

BACKGROUND OF THE INVENTION Field of the invention This invention pertains to the drilling of boreholes in the earth and is particularly concerned with an automatically resettable bit-weight applicator for use in rotary drilling operations.

Description of the prior art In conventional rotary drilling systems the penetration rate of the drill bit through the subsurface formation is to some degree proportional to the weight applied to the bit. Such systems generally include a string of heavy drill collars which are placed in the drill string just above the bit to increase the downward force or weight acting on it. Bit-weight applicators have been developed to supplant the drill collars and provide the same force at the bit by means of a hydraulically actuated piston. These devices alleviate certain undesirable features associated with the use of drill collars, such as the requirement for heavier equipment at the surface and the necessity for more horsepower and rig time to lift the drill pipe, drill collars, and drill bit from the well. The use of bit-weight applicators thus offers certain advantages over the use of drill collars.

Apparatus for lowering the drill pipe, drill collars, and drill bit in response to weight changes at the surface caused by penetration of the drill bit is commercially available for use with conventional rotary drilling systems. Drilling with a constant weight on the bit can thus be carried out more or less continuously. Existing bitweight applicators also apply a constant force to the bottom of the hole throughout the stroke of the hydraulic piston. This force is opposed by a wall anchor which transfers the reacting force to the borehole wall. There is therefore no change in weight at the surface when the piston reaches the lower end of its stroke. Since there is thus no weight reduction to which a conventional continuous drilling device can respond, continuous drilling operations are not feasible with most bit weight applicators. Instead, the period of time for the drilling of one stroke length must be estimated, circulation periodically stopped, and the drill pipe lowered to reset the tool. This manual monitoring of the operation is often unreliable, is generally time-consuming, and is usually expensive.

SUMMARY OF THE INVENTION The automatic drilling system of this invention permits continuous drilling with a hydraulic bit-weight applicator. The apparatus of the invention includes a string of drill pipe or a similar conduit, a bit-weight applicator including extensible shoes and a hydraulically actuated piston for anchoring the lower end of the string to the borehole wall, means for transmitting a signal to the upper end of the string when the piston reaches the end of its stroke, and means responsive to this signal for lowering the drill string and resetting the piston to permit continued drilling.

The bit-weight applicator utilized in carrying out the invention will normally be mounted in the drill string just above the bit and will include an outer housing containing extensible shoes which are actuated hydraulically in response to a differential pressure between the interior of the drill string and the annulus. A telescoping shaft assembly linking the drill string and bit is free to rotate within this outer housing. Differential pressure acting on one or more pistons attached to the shaft causes it to move downwardly and thus exert force through the bit on the bottom of the borehole. At the end of its stroke, the piston mechanically opens a port between the drill string and annulus which permits fluid Within the string to rush into the low-pressure annulus. This results in a reduction in pressure within the drill string. The extensible shoes are released in response to the pressure reduction. A hoist control at the surface which causes the drill string to be lowered the length of a piston stroke is simultaneously actuated. The pressure relief port is closed and the string is lowered permitting pressure to build up within the drill string and reset the hydraulic wall anchor. Lowering the string also resets the piston to the beginning of its stroke, so that drilling can continue.

The apparatus of the invention has the advantage that the drilling operation can be carried out on a substantially continuous basis while using a bit-weight applicator. The necessity for manual supervision of the drilling, inherent in conventional operations utilizing a bit-weight applicator, is eliminated. It is also advantageous in that the heavy string of drill collars used in existing automatic drilling systems can be eliminated. This makes possible a reduction in the size of the hoisting equipment and in the amount of rig horsepower necessary. The system of the invention thus offers distinct advantages over automatic drilling systems available in the past.

BRIEF DESCRIPTION OF THE DRAWINGS FIG. 1 is a schematic illustration of the automatic drilling system of the invention. FIG. 2 shows schematically a pressure-responsive hoist controller suitable for use with the system of FIG. 1. FIGS 3A and 3B are cross-sectional views of bit-weight applicator that may be employed in the system depicted in FIG. 1. FIG. 4 is a detail section of the bit-weight applicator of FIG. 3 taken along line 44. FIGS 5A and 5B are cross-sections of an alternate bit-weight applicator useful in the system of FIG. 1. FIG. 6 is a detail section of the bit-weight applicator of FIG. 5B taken along line 66.

DESCRIPTION OF THE PREFERRED EMBODIMENTS The automatic drilling system of the invention, as depicted in FIG. 1, includes a string of drill pipe or a similar conduit 11 suspended in borehole 12. The drill pipe can be raised or lowered by hoist 13 acting on drilling line 14 which suspends traveling block 15 from the crown block, not shown, of derrick l6. Hook 17 is attached to the lower part of the traveling block and carries swivel 18 from which kelly 27 and drill pipe 11 are suspended. Mounted at the bottom of the drill pipe is drill bit 19.

Drilling fluid is circulated in the system of FIG. 1 by means of a pump 20 which discharges through line 21 to swivel 18, connected to the upper end of the kelly. Fluid passes down the kelly and drill pipe, through the drill bit,

3 and returns through annulus 22 and return line 23 to fluid tank 24.

The apparatus of FIG. 1 also includes a drive mechanism, not shown, within housing 25 for applying torque to rotary table 26. The rotary table imparts rotary motion to kelly 27 which is coupled at its lower end to the drill string. In lieu of a rotary table, kelly and rigid string of drill pipe as shown, the invention can also be carried out with a flexible drill string connected to a turbodrill or similar downhole drive system.

Force is applied to the pit in FIG. 1 py bit-weight applicator 28 which includes extensible anchor shoes 29 and a hydraulic piston which is not shown. The construction of the bit-weight applicator is discussed in greater detail below in connection with FIGS. 3 through 6. In the device shown schematically in FIG. 1, hydraulic pressure is applied to the piston to force the drill bit downwardly against the bottom of the borehole. Pressure applied to the extensible shoes forces them outwardly against the borehole wall and thus prevents movement of the apparatus upwardly in the borehole.

A signal is transmitted to the upper end of the drill string when the piston reaches the lower end of its stroke. This can be accomplished by means of a mechanically actuated valve that is opened when the piston reaches the lower end of its stroke. The opening of the valve causes fluid within the drill string to be vented to the lowpressure annulus, thus reducing the fluid pressure within the drill pipe and causing a drop in pressure at the surface. The construction of such a valve is discussed in connection with the bit-weight applicators of FIGS. 3 through 6 below. Other signaling means such as an electric or acoustic system could also be used to create a detectable signal.

The apparatus responsive to the signal for lowering the drill pipe and resetting the piston for continuous drilling is illustrated in FIG. 2. This apparatus includes a cylinder 30 within which is a slidable piston 31. The piston is connected to hoist brake arm 32 by connecting rod 33. A packing gland, not shown, maintains a pressure-tight seal between the connecting rod and end of the cylinder. A pressure source 34 and a pressure regulator 35 control the pressure on the lower end of the piston. The pressure on the upper side of the piston 36 is that exerted by the drilling fluid. These two pressures are balanced by regulator 35 so that as the bit-weight applicator piston reaches the end of its stroke and the drilling fluid pressure drops in response to opening of the valve, the higher pressure on the under side of the piston forces the connecting rod 33 to move outwardly from hydraulic cylinder 30 and release the brake. The hoist then lowers the drill String the length of the weight-applicator piston stroke. This automatically closes the relief valve in the bit-weight applicator, causing pressure to build up within the drill string. The pressure buildup resets the extensible shoes and brake and actuates the hydraulic weight applicator piston so that drilling can be continued. It should be noted, however, that when the specific drilling operations undertaken require precise control of the progress of the bit within the borehole, it may be advisable to manually operate the hoist control instead of utilizing the apparatus illustrated in FIG. 2.

A bit-weight applicator suitable for use in the automatic drilling system of this invention is shown in FIG. 3. A hollow, telescoping power transmission shaft 101 is divided into an upper section 102 and a lower section 103. These are connected by a telescoping joint 104. The inner diameter of the upper section is enlarged near the lower end thereof to form an internal recess 105 bounded by a downwardly facing shoulder 106 and an upwardly facing shoulder 107. The upper end of lower section 103 includes an enlarged section 108 which fits within recess 105. Enlarged section 108 has an upwardly facing surface 109 which, when section 108 is in its uppermost position in recess 105, contacts shoulder 106. When section 108 is in its lowermost position, a downwardly facing shoulder 110 contacts upwardly facing shoulder 111 in recess 105. As is seen more clearly in the section shown in FIG. 4, splines 113 on lower shaft section 103 fit or interlock within matching recesses 114 of upper shaft section 102.

Outer housing 115 is mounted about telescopin shaft assembly 101. The lower part of the housing surrounds and is supported on lower section 103 by bearings 178 at the lower end of the housing and by intermediate bearings 116, 117, .118, and 119. A seal 179 is provided between housing 115 and shaft 103 just above bearings 178. H using 115 surrounds surrounds and is supported on upper shaft Section 102 by lower bearing 121 and upper bearing 122. The upper end of housing 155, designated by reference numeral 123, supports bearing 122 and wiper 124. The housing includes an external upwardly facing surface 125 and an internal downwardly facing shoulder 126. A resetting collar 127 having a downwardly facing surface 128 is provided on upper shaft section 102 above housing 115. Surface 128 is arranged to contact surface 125 on housing .115 when the shaft moves downwardly with respect to the housing. Upper shaft section 102 has an upwardly facing shoulder 129 just above annular recess 105. When shaft 101 is raised with respect to the housing, shoulder 129 engages shoulder 126 in the housing and supports it.

The portion of the apparatus utilized for applying force to the bit includes an upper piston 130 and a lower piston 13.1. These pistons may be, but-are not necessarily, an integral part of lower shaft section 103. Internal recesses 132 and 133 in the housing 115 serve as cylinders for pistons 130 and 131 respectively. The upper portion of cylinder 132 above piston 130 communicates with the interior shaft 103 through port 134 and with longitudinal passageway 135 in the housing wall through port 136. The lower part of cylinder 132 communicates with the borehole annulus through port 137 in the wall of the housing. The upper part of cylinder 133 above piston 131 communicates with the interior of shaft section 103 through port 138 and with passageway 135 through port 139. The portion of cylinder 133 below piston 131 communicates with the annulus 140 through port 141 in the wall of the housing. Pistons 130 and 131 are each provided with seals 142 and 143 respectively to prevent fluid from bypassing the pistons.

Intermediate bearing 119 and seal 145 are supported by the housing above cylinder 132. Below cylinder 132 are rntermediate bearing 118 and seal 146. Bearing 117 and seal 149 are located below cylinder 133 Seals 120, 149, 146, 145, 112, and 124 can all be similar and are preferably lipped or V-ring seals.

Below the load developing section is an anchor section. This irrcludes a pressure chamber 150 extending between the outer part of the lower shaft section 103 and the inner wall of housing 115. A port 151 in the wall of the lower shaft section provides fluid communication between the hollow shaft and pressure chamber. Port 152 in the wall of the housin leads to passageway 153. The wall of lower housing 115 adjacent pressure chamber 150 contalns a series of openings 154 in which a plurality of anchor shoes 155 are mounted. These shoes preferably include a rubber member .156 which is molded to or otherwise sealed in contact with the walls of the openings 154. A hard metal core 157 is supported within the rubber material 156. The elasticity of the rubber member is such the core 157 is forced outwardly against the borehole wall when pressure is exerted in pressure chamber 150 but, when the pressure is released, the core is retracted by the rubber member. The lower portion of the anchor section, indicated by reference numeral 168, contains a bearing 116 and a seal 120 between the interior surface of the housing and the exterior of shaft section 103.

A stroke limit indicator section 190 is located below the anchor section in the apparatus of FIGS. 3 and 4. This includes a cylindrical piston 158 which slides in contact with inner walls of housing 115. Sealing is provided by upper seal rings 159 and 160 and lower seal ring 161. The piston is held against the uppermost end of the annular chamber formed by shaft 103 and housing 115 by a ball detent assembly 162 which includes a ball 163 and a spring 164 mounted in port 165 in the wall of the housing. Concave surface 166 on the lower skirt of the piston accepts the ball.

Stops .167 separate the piston from the housing above it. Shaft section 103 is enlarged to provide an intermediate flange 169. The lower edge 170 of the flange contacts surface 171 on the piston when the thrust pistons 130 and 131 reach the end of their stroke.

Port 172 provides communication between the drill string and the upper side of piston 158. Ports 173 and 174 through wall of housing 115 provide fluid eommunication between the borehole annulus and the underside of cylindrical piston 158. Ports 175 and 176 in the housing wall communicate with the annulus above the lower most position of the piston. The lower end of the stroke limit indication section 190, indicated by reference numeral 177, contains bearing 178 and seal 179.

A drill bit 180 is mounted at the lower end of lower shaft 103. Just above the drill bit is a spiraling preventer 181 which can be made an integral part of lower shaft section .103. The spiraling preventer includes a series of shoes 182 spaced about the circumference of the shaft. The face 183 of each shoe is preferably hard-surfaced. The diameter is approximately equal to or slightly greater than the relaxed diameter of the anchor shoes and less than the gage diameter of the bit. A spiraling preventer of this type stops or reduces spiraling and prevents substantial reduction of drift diameter of the hole. This permits rapid advancement of the outer case or housing 115 while resetting the tool.

A hardened steel stop 184 is provided on lower shaft Section 103 above cylinder 132. This prevents pistons 130 and 131 from striking the packing glands housed within shoulder members 147 and 148 respectively. This stop is especially useful in drilling off; that is, when the bit has drilled nearly the full length of stroke of piston 130. Before pistons 130 and 131 strike the bottom of their respective cylinders 132 and 133, stop 184 comes in contact with annular shoulder 144 which is also hardened. This avoids severe damage to the piston packing and shaft seals.

In operation, the apparatus is assembled as shown in the drawing and is then lowered into the borehole until it reaches bottom. Drilling fluid is then pumped downwardly under pressure through the drill pipe and telescoping shaft 101 to drill bit 180. The drilling fluid expands anchor shoes 155 against the borehole, securely anchoring housing 115 against longitudinal or rotational movement. Fluid also flows through ports 134 and 138 to the upper side of push-down or thrust pistons 130 and 131. Ports 134 and 13 8 can be designed with respect to port 151 so that anchor shoes 155 Will firmly anchor before pistons 130 and 131 move substantially with respect to housing 115. Other means for preventing premature movement can also be used. The drill string is rotated, thus causing bit 180 to advance. The force on the bit is supplied primarily by the downward thrust on pistons 130 and 131. The lower sides of these thrust pistons are in fluid communication with the relatively lower pressure in the annulus.

As drilling continues, pistons 130 and 131 move downwardly toward the cylinders. Just before the pistons strike the bottoms of the cylinders, stop 184 comes to rest. The lower edge 170 of flange 169 contacts piston 158. Continued drilling forces the flange downwardly against the piston until the restraining force of ball detent assembly 162 is overcome. Since passageway 153 and port 172 introduce fluid that is at drill string pressure to the upper side of piston 158 and since the underside of piston 158 is in communication with the annulus through ports 173 and 174, a differential pressure exists across the piston that will force it down against the bottom of the housing as soon as the ball detent is released. This opens ports -175 and 176, which are in communication with the annulus, to the upper chamber of the stroke limit indicator section between shaft 103 and housing 115. High-pressure fluid above pistons and 131 flows through passageway to pressure chamber 150, which communicates through passageway 153 with the stroke limit indicator section. The drill string communicates with the stroke limit indicator section through port 172. When the ports and 176 are opened, the pressure within the tool and that in the annulus are equalized.

The reduction of pressure within the drill pipe allows anchor shoes 155 to retract Reduced pressure at the surface activates the automatic hoist control to lower the drill pipe the length of the piston stroke. This in turn forces collar 127 downwardly against shoulder 125 on the housing 115. The housing is thus pushed downwardly until pistons 130 and 131 are in the uppermost part of the cylinders 132 and 133 respectively. Flange 169 pushes piston 158 back into its uppermost position and the ball detent assembly 162 is re-engaged. During this operation, the lower shaft section 103 remains stationary with bit on the bottom of the borehole. The upper shaft section 102, therefore, slides downwardly in telescoping joint 104. The stroke of the telescoping joint, the distance between upper surface 109 on the lower shaft section and the downwardly facing shoulder 106 on the upper shaft section 102 is approximately equal to the stroke of pistons 130 and 131. This permits complete resetting of the pistons. There is no danger of the pistons being jammed against the upper ends of the cylinders because stop 184 will limit relative upward movement of lower shaft section 103. In other words, the distance between stop 184 and the lower portion of upper shaft section 102 is approximately equal to the desired stroke of piston 130. The distance between upper shoulder 125 on the housing and resetting collar 128 is approximately equal to the distance between stop i184 and the housing beneath it. When the tool has been reset, fluid pressure again builds up in the drill pipe and the drilling operation continues as described before.

An important feature of telescoping joint 104 is that lower shaft section 103 can be picked up and upward force applied thereto through upper shaft section 102 and the drill string from the surface. This permits the force on bit 180 to be regulated from the surface in certain operations such as reaming where it is desired that a reduced force be applied to the bit. By lifting up on the drill string during drilling, the necessity for reducing the pressure of the fluid in the drill string to regulate the force on the bit can be eliminated. This permits variations in the circulating fluid pressure and volume without corresponding variations in the downward force on drill bit 180.

When it is desired to come out of the hole with the tool of FIGS. 3 and 4, the circulation of drilling fluid is interrupted so that anchor shoes 155 are retracted. The drill pipe is then lifted, causing upper shaft section 102 to move upwardly until shoulder '129 contacts shoulder 126 on the housing. Further upward movement of the drill pipe then moves housing 115 upwardly. Shoulder 108 on the lower shaft section contacts the shoulder 107 on the upper shaft section and thus the lower shaft section 102 and bit 180 are raised. The drill pipe is lifted until the tool has been removed from the borehole.

An alternate bit-weight applicator which is also suitable for use in the system of this invention is shown in FIG. 5. The apparatus depicted includes an upper barrel 201 including means for anchoring the device to the borehole wall and an inner telescoping power shaft 202, both of which are mounted near the lower end of the drill string. The telescoping assembly includes an inner tubular member 203, a lower barrel 204, and an extensible piston member 205, all of which rotate with respect to the upper barrel. The piston member rotates and moves longitudinally with respect to the upper barrel. It also moves longitudinally with respect to the inner tubular member and the lower barrel. The interrelationship between these three is illustrated in cross-section in FIG. 6. The inner tubular member as shown includes three threaded joints, although it will be apparent that other methods of assembly would be suitable. Fluid passageways extending longitudinally in this member include chambers 206, 207, and 208 containing piston 21 8, upper valve 210, and lower valve 211 respectively. Positioned in the lower part of these passageways is a push-rod valve assembly. Rod 209 has an upper valve 210 and a lower valve 211 accurately spaced along its length and includes an upper valve actuator peg 212 and a lower valve actuator peg 213. Each valve has sealing rings mounted circumferentially about it. The individual components of the push-rod valve assembly can be Welded, threaded, or joined in some other fashion.

Upper valve chamber 207 contains a port 214 communicating with interior conduit 215 which contains drilling fluid. A second port 216 leads to an upper passageway 217 beneath sealing piston 218. The third port, designated as 219, leads to thrust piston chamber 220. In its uppermost, open position, the upper valve 210 permits the passage of drilling fluid from the interior conduit 215 to both the sealing piston 218 and the thrust piston chamber 220. In its lowermost position, this valve prevents the passage of fluid from the interior conduit to either the sealing valve or the piston chamber.

Sealing piston chamber 206 has two ports. The upper port 221 leads to wall-anchor fluid chamber 222. The lower port opens into fluid passageway 217, which is in communication through port 216 with the upper valve chamber. The sealing piston ports are always open, since the function of this piston is to maintain segregation between drilling fluid and hydraulic fluid and yet transmit drilling fluid pressure to hydraulic fluid contained within the wall-anchor fluid chamber.

Lower valve chamber 208 contains an upper port 223 that leads to thrust piston chamber 220 and a lower port 224 that opens into lower passageway 225. This is open through slot 226 and ports 227 and 228 to the annulus when the piston is at the end of its stroke. With push rod 209 in its uppermost position, the lower valve is closed, isolating the thrust piston chamber from the annulus. The lower valve is open when the push rod is in its lowermost position and allows pressure to equalize between the annulus and the thrust piston chamber.

Positioning of the upper and lower valves occurs in response to the movement of thrust piston 229. As the piston reaches the end of its stroke, beveled edge 230 contacts valve actuator peg 2 13 and pushes it down. When the piston is reset for another stroke, upper edge 231 of the thrust piston pushes valve actuator peg 212 up and forces the push rod into its upper-most position.

The lower portion of the inner tubular member is slotted as indicated by reference numeral 232 to accommodate a spline, not shown, on the thrust piston. The splined connection between the inner tubular member and the thrust piston compels the piston to rotate with the inner tubular member, but permits the piston to move longitudinally relative to the inner tubular member. A threaded pipe sub 233 forms the lower extremity of the inner tubular member. Packing 234 located in groove 235 in the sub forms a slidable seal with the extensible thrust piston member.

The extensible piston member is shown in FIG. 5 as an integral member with a threaded connection 236 at its lower end which is coupled to the shank 237 of a drill bit, the remainder of which is not shown. This member could also be constructed of several segments. To insure that the piston member and the lower barrel will rotate with the inner tubular member and the piston will slide longitudinally with respect to the other two members, the three are splined together. The piston includes a spline, not shown, which fits into groove 232 in the inner tubular member and a groove 238 which accepts spline 239 on the lower barrel.

The upper end of the piston member is slidably disposed within thrust piston chamber 220. The exterior surfaces of the piston that contact the walls of the piston chamber are grooved for and contain sealing elements 240 and 241.

Upper port 228 and lower port 242 allow fluid to pass through the cylindrical piston member. Port 228 is necessary to release fluid from the thrust piston chamber at the end of the piston stroke so that the wall anchor will release. Port 242 allows fluid within the drill string to escape to the annulus at the end of the piston stroke, thus equalizing pressure within and without the drill string and providing an ascertainable surface indication that the piston has completed its stroke.

The lower barrel 204 is splined to the extensible piston member at its lower end and attached at its upper end to outwardly flared upper portion 243 of the inner tubular member. The inner surface of the lower barrel forms the exterior surface of thrust piston chamber 220. The upper barrel 201 contains wall anchor shoes 244 which lock it to the walls of the borehole. This barrel remains stationary during the drilling of each piston stroke, while permitting rotation of the inner telescoping power shaft within it.

The barrel is connected to the inner tubular member of the telescoping power shaft by means of bearings 245 and 246. The lower set of four bearings 246 is mounted in groove 247 of the inner tubular member and groove 248 of the upper barrel, while upper bearing 245 is mounted in groove 249 of the inner tubular member and groove 250 of the upper barrel. These bearings both permit rotation of the inner power shaft and transmit force from the inner shaft to the walls of the borehole by means of the wall anchor shoes. Packing between the upper barrel and the rotating inner shaft is contained in upper groove 251 and lower groove 252 of the upper barrel.

Wall anchor fluid chamber 222 is in communication with wall anchor shoes and with sealing piston 218 through passageway 254. Pressure of the hydraulic fluid is controlled by the pressure of the fluid in the drill pipe, which is in communication with the underside of the sealing piston. Wall anchor shoes 244 have teeth on their outer surface to better grip the walls of the borehole. Return springs 253 bias each of the shoes so that in their normal position they are retracted. As pressure builds up within the wall anchor fluid chamber, the shoes extend outwardly and dig into the borehole wall.

In operation, the tool with a drill bit attached to its lower end is lowered into the borehole on the end of a string of drill pipe or other suitable conduit. Drilling fluid is directed down the interior of the conduit, and, as a result of the pressure drop across the bit, pressure in excess of that within the annulus rapidly builds up within the drill pipe.

Setting the tool on bottom prior to any pressure buildup within the drill string collapses the telescoping power shaft and forces the thrust piston to its uppermost position within the piston chamber. This causes upper beveled edge 231 of the piston to push valve actuator peg 212 up positioning the push-rod valve assembly in its uppermost position as it is shown in FIG. 5.

Pressurized drilling fluid enters port 214 and flows toward the sealing piston and the thrust piston. The differential pressure between the drill string and the annulus causes wall anchor shoes 244 to overcome the force of return springs, extend, and engage the borehole wall. Since drilling fluid enters thrust piston chamber 220 through port 219 of the upper valve chamber, differential 9 pressure is exerted on the thrust piston. The downward resultant of this force drives the bit against the bottom of the borehole. An opposing resultant force is, of course, transmitted to the borehole wall through the wall anchor shoes.

As the drill bit advances, the extensible thrust piston moves downwardly. The push-rod valve assembly does not move, however, until the piston reaches the end of its stroke. Near the end of the piston stroke, the lower beveled edge 230 of the thrust piston contacts valve actuator peg 213 and forces it and the whole push-rod assembly to their lowermost positions. This closes the upper valve and opens the lower valve. With the upper valve closed, no more pressurized drilling fluid can enter the thrust piston chamber or the sealing piston cylinder. Opening of the lower valve permits pressurized drilling fluid to escape from the thrust piston chamber through passageway 225, slot 226, port 227, and port 228 into the annulus. This terminates the application of force on the bit and also allows the return springs to retract the wall anchor shoes, thus releasing the tool. At the same time, port 242 located in the extensible piston member moves past packing element 234 located at the lower extremity of the inner tubular member. This allows drilling fluid within the drill string to pass through port 242 to the annulus and so bypass the drill bit. Pressure between the drill pipe and the annulus equalizes.

Equalization of the pressures creates a reduction in pressure at the surface which actuates the hoist control, causing it to lower the drill string the length of the piston stroke. This resets the piston to the top of its stroke and another cycle is initiated.

What is claimed is:

1. Apparatus for drilling a borehole in the earth comprising:

(a) a drill string;

(b) means operatively connected to said drill string near the lower end thereof for anchoring said string to the wall of a borehole and exerting a downward force against the bottom of said borehole, said means including a hydraulically actuated piston having a vertical stroke, a plurality of laterally extensible shoes, and a device for emitting a signal detectable at the earths surface when said piston reaches the lower end of its stroke;

() means at the earths surface for detecting said signal, said means operatively related to said signal emitting device; and

(d) means operatively connected to said drill string and responsive to said detecting means for lowering said drill string and resetting said piston to permit continued drilling.

2. An apparatus for drilling a borehole in the earth comprising:

(a) a drill string;

(b) means operatively connected to said drill string near the lower end thereof for anchoring the string to the borehole wall and for forcing a drill bit against the bottom of the borehole, said means including a hydraulically actuated piston and a hydraulically actuated wall anchor;

(c) means operatively connected to said anchoring means for substantially reducing the pressure of a drilling fluid within said drill string when said piston reaches the end of its stroke; and

(d) means at the earths surface operatively connected to said drill string and responsive to said pressure change for lowering said drill string to reset the piston for continued drilling.

3. Apparatus for applying force to a drill bit comprising:

(a) a hollow cylindrical upper barrel provided with pressure-actuated means for anchoring said barrel to the walls of a borehole;

(b) a hollow cylindrical inner tubular member, the upper portion of which is rotatably aflixed within said upper barrel and the lower portion of which extends downwardly therefrom, the interior of said hollow inner tubular member forming an inner conduit extending from the top to the bottom of said tubular member;

(c) a cylindrical lower barrel member having a substantially frusto-conical upper end which is attached to the lower part of said inner tubular member to form an annular piston chamber between said lower barrel and said tubular member;

(d) a cylindrical extensible piston member having said drill bit structurally connected to the lower end thereof, said piston member slidably disposed within said annular piston chamber and attached to said inner tubular member and said lower barrel member to rotate therewith;

(e) means operatively connected to said inner tubular member for admitting fluid from said internal conduit to the upper end of said piston chamber to force said extensible piston to slide downwardly in relation to said inner tubular member and said lower barrel member; and

(f) means operatively connected to said extensible piston member for discharging said fluid from the upper end of said piston chamber to the annulus between said piston member and said borehole whenever said piston reaches the end of its stroke.

4. Apparatus for applying force to a drill bit comprising:

(a) a hollow cylindrical outer housing having pressure actuated means for anchoring said housing to the walls of a borehole, said housing having a plurality of internal circular shoulders that form annular piston chambers therebetween;

(b) a substantially cylindrical upper shaft section having an enlarged lower portion that terminates in a circular shoulder and having an internal fluid passageway therethrough, said upper shaft section rotatable with respect to said outer housing and slidably received within the upper end thereof;

(c) a substantially cylindrical lower shaft section, the lower end thereof being operatively connected to said drilling bit, said lower shaft section having an internal conduit therethrough, having its upper end slidably received within said enlarged lower portion of said upper shaft section so that its travel relative thereto is limited by said circular shoulder of said upper shaft section and having affixed to its exterior a plurality of cylindrical pistons, said pistons being so positioned along said lower shaft section as to be slidably disposed within said annular piston chambers of said outer housing;

(d) means operatively connected to said internal conduit for admitting fluid from said internal conduit to the upper ends of said piston chambers so as to force said pistons and said lower shaft section downwardly in relation to said outer housing; and

(e) means operatively connected to said internal conduit for discharging fluid from the upper ends of said piston chambers and from said internal conduit into the annulus between said outer housing and said borehole whenever said pistons reach the ends of their strokes.

5. A method for drilling a borehole in the earth wherein a drill string, bit-weight applicator, and drill bit are suspending within a borehole comprising:

(a) forcing drilling fluid down said drill string and through said drill bit so as to anchor said bit-weight applicator against the borehole wall and so as to cause said bit-weight applicator to force said drill bit against the bottom of the borehole;

(b) rotating said drill bit while continuing to force drilling fluid down said drill string so as to continu- 1 1 1 2 ously apply force to said drill bit until the corn- References Cited bination of rotation and force causes the drill bit to UNITED STATES PATENTS extend the borehole within the earth a distance equal to the length of the stroke of a thrust piston integral 2931007 5/1960 Whlttle 175 321 X 3,088,532 5/1963 Kellner 175-321 X within said bit-weight applicator, and 5 3,138 214 6/1964 Bridwen 175 321 X (c) lowering said drill string the length of the stroke 3,207,238 9/ 1965 Davidson 175-27 X of said piston 1n response to a surface-detectable 3 225 843 12/1965 Ortloff 5 X signal emitted by said bit-Weight applicator whenever 3:233i689 2/1966 Whittle 175 27 X said piston reaches the end of its stroke. -6. Apparatus as defined by claim 3 wherein said means 10 NILE BYERS Pnmary Exammer for discharging fiuid from the piston chamber is opera- US. Cl. X.R. tively connected to said lower barrel member. 175 21

US3497019A 1968-02-05 1968-02-05 Automatic drilling system Expired - Lifetime US3497019A (en)

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Cited By (30)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4130000A (en) * 1976-09-20 1978-12-19 Richard Dean Hawn, Jr. Drill string shock absorber
EP0184304A1 (en) * 1984-11-07 1986-06-11 Mobil Oil Corporation Method and system of drilling deviated wellbores
EP0469317A2 (en) * 1990-07-30 1992-02-05 Baker-Hughes Incorporated Method and device for modifying the weight on an earth frill bit
WO1997015749A2 (en) * 1995-10-23 1997-05-01 Baker Hughes Incorporated Closed loop drilling system
US5842149A (en) * 1996-10-22 1998-11-24 Baker Hughes Incorporated Closed loop drilling system
US6206108B1 (en) 1995-01-12 2001-03-27 Baker Hughes Incorporated Drilling system with integrated bottom hole assembly
US6241031B1 (en) 1998-12-18 2001-06-05 Western Well Tool, Inc. Electro-hydraulically controlled tractor
US6347674B1 (en) 1998-12-18 2002-02-19 Western Well Tool, Inc. Electrically sequenced tractor
US6367366B1 (en) 1999-12-02 2002-04-09 Western Well Tool, Inc. Sensor assembly
US6431291B1 (en) 2001-06-14 2002-08-13 Western Well Tool, Inc. Packerfoot with bladder assembly having reduced likelihood of bladder delamination
US6464003B2 (en) 2000-05-18 2002-10-15 Western Well Tool, Inc. Gripper assembly for downhole tractors
US6679341B2 (en) 2000-12-01 2004-01-20 Western Well Tool, Inc. Tractor with improved valve system
US20040055788A1 (en) * 2001-01-10 2004-03-25 Bruno Best Device for anchoring a drill string in a borehole
US6715559B2 (en) 2001-12-03 2004-04-06 Western Well Tool, Inc. Gripper assembly for downhole tractors
US6739409B2 (en) * 1999-02-09 2004-05-25 Baker Hughes Incorporated Method and apparatus for a downhole NMR MWD tool configuration
US20040168828A1 (en) * 2003-02-10 2004-09-02 Mock Philip W. Tractor with improved valve system
US20050247488A1 (en) * 2004-03-17 2005-11-10 Mock Philip W Roller link toggle gripper and downhole tractor
US20050279532A1 (en) * 2004-06-22 2005-12-22 Baker Hughes Incorporated Drilling wellbores with optimal physical drill string conditions
US20080053663A1 (en) * 2006-08-24 2008-03-06 Western Well Tool, Inc. Downhole tool with turbine-powered motor
US20080217024A1 (en) * 2006-08-24 2008-09-11 Western Well Tool, Inc. Downhole tool with closed loop power systems
US20080308318A1 (en) * 2007-06-14 2008-12-18 Western Well Tool, Inc. Electrically powered tractor
US7624808B2 (en) 2006-03-13 2009-12-01 Western Well Tool, Inc. Expandable ramp gripper
US7748476B2 (en) 2006-11-14 2010-07-06 Wwt International, Inc. Variable linkage assisted gripper
US20100307832A1 (en) * 2000-12-01 2010-12-09 Western Well Tool, Inc. Tractor with improved valve system
US20100319907A1 (en) * 2007-02-28 2010-12-23 Hallundbaek Joergen Drilling Tool with Feed Control
US20110073300A1 (en) * 2009-09-29 2011-03-31 Mock Philip W Methods and apparatuses for inhibiting rotational misalignment of assemblies in expandable well tools
WO2016139264A1 (en) * 2015-03-03 2016-09-09 Welltec A/S Downhole stroking tool
US9447648B2 (en) 2011-10-28 2016-09-20 Wwt North America Holdings, Inc High expansion or dual link gripper
EP3070258A1 (en) * 2015-03-20 2016-09-21 Welltec A/S Downhole stroking tool
US9488020B2 (en) 2014-01-27 2016-11-08 Wwt North America Holdings, Inc. Eccentric linkage gripper

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Cited By (89)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4130000A (en) * 1976-09-20 1978-12-19 Richard Dean Hawn, Jr. Drill string shock absorber
EP0184304A1 (en) * 1984-11-07 1986-06-11 Mobil Oil Corporation Method and system of drilling deviated wellbores
EP0469317A2 (en) * 1990-07-30 1992-02-05 Baker-Hughes Incorporated Method and device for modifying the weight on an earth frill bit
EP0469317A3 (en) * 1990-07-30 1993-04-14 Baker Hughes Incorporated Method and device for modifying the weight on an earth frill bit
US6206108B1 (en) 1995-01-12 2001-03-27 Baker Hughes Incorporated Drilling system with integrated bottom hole assembly
WO1997015749A2 (en) * 1995-10-23 1997-05-01 Baker Hughes Incorporated Closed loop drilling system
WO1997015749A3 (en) * 1995-10-23 1997-07-24 Baker Hughes Inc Closed loop drilling system
US6021377A (en) * 1995-10-23 2000-02-01 Baker Hughes Incorporated Drilling system utilizing downhole dysfunctions for determining corrective actions and simulating drilling conditions
US6233524B1 (en) 1995-10-23 2001-05-15 Baker Hughes Incorporated Closed loop drilling system
US5842149A (en) * 1996-10-22 1998-11-24 Baker Hughes Incorporated Closed loop drilling system
US20060196696A1 (en) * 1998-12-18 2006-09-07 Duane Bloom Electrically sequenced tractor
US6241031B1 (en) 1998-12-18 2001-06-05 Western Well Tool, Inc. Electro-hydraulically controlled tractor
US6347674B1 (en) 1998-12-18 2002-02-19 Western Well Tool, Inc. Electrically sequenced tractor
US6427786B2 (en) 1998-12-18 2002-08-06 Western Well Tool, Inc. Electro-hydraulically controlled tractor
US7185716B2 (en) 1998-12-18 2007-03-06 Western Well Tool, Inc. Electrically sequenced tractor
US7174974B2 (en) 1998-12-18 2007-02-13 Western Well Tool, Inc. Electrically sequenced tractor
US6478097B2 (en) 1998-12-18 2002-11-12 Western Well Tool, Inc. Electrically sequenced tractor
US20060196694A1 (en) * 1998-12-18 2006-09-07 Duane Bloom Electrically sequenced tractor
US7080701B2 (en) 1998-12-18 2006-07-25 Western Well Tool, Inc. Electrically sequenced tractor
US20050252686A1 (en) * 1998-12-18 2005-11-17 Duane Bloom Electrically sequenced tractor
US6938708B2 (en) 1998-12-18 2005-09-06 Western Well Tool, Inc. Electrically sequenced tractor
US6745854B2 (en) 1998-12-18 2004-06-08 Western Well Tool, Inc. Electrically sequenced tractor
US20040245018A1 (en) * 1998-12-18 2004-12-09 Duane Bloom Electrically sequenced tractor
US6739409B2 (en) * 1999-02-09 2004-05-25 Baker Hughes Incorporated Method and apparatus for a downhole NMR MWD tool configuration
US6367366B1 (en) 1999-12-02 2002-04-09 Western Well Tool, Inc. Sensor assembly
US20070017670A1 (en) * 2000-02-16 2007-01-25 Duane Bloom Gripper assembly for downhole tools
US20050082055A1 (en) * 2000-02-16 2005-04-21 Duane Bloom Gripper assembly for downhole tools
US20060201716A1 (en) * 2000-02-16 2006-09-14 Duane Bloom Gripper assembly for downhole tools
US6640894B2 (en) 2000-02-16 2003-11-04 Western Well Tool, Inc. Gripper assembly for downhole tools
US7191829B2 (en) * 2000-02-16 2007-03-20 Western Well Tool, Inc. Gripper assembly for downhole tools
US7275593B2 (en) 2000-02-16 2007-10-02 Western Well Tool, Inc. Gripper assembly for downhole tools
US7048047B2 (en) 2000-02-16 2006-05-23 Western Well Tool, Inc. Gripper assembly for downhole tools
US9988868B2 (en) 2000-05-18 2018-06-05 Wwt North America Holdings, Inc. Gripper assembly for downhole tools
US8944161B2 (en) 2000-05-18 2015-02-03 Wwt North America Holdings, Inc. Gripper assembly for downhole tools
US20080078559A1 (en) * 2000-05-18 2008-04-03 Western Well Tool, Inc. Griper assembly for downhole tools
US8069917B2 (en) 2000-05-18 2011-12-06 Wwt International, Inc. Gripper assembly for downhole tools
US9228403B1 (en) 2000-05-18 2016-01-05 Wwt North America Holdings, Inc. Gripper assembly for downhole tools
US8555963B2 (en) 2000-05-18 2013-10-15 Wwt International, Inc. Gripper assembly for downhole tools
US7604060B2 (en) 2000-05-18 2009-10-20 Western Well Tool, Inc. Gripper assembly for downhole tools
US6464003B2 (en) 2000-05-18 2002-10-15 Western Well Tool, Inc. Gripper assembly for downhole tractors
US20040144548A1 (en) * 2000-12-01 2004-07-29 Duane Bloom Tractor with improved valve system
US20070000693A1 (en) * 2000-12-01 2007-01-04 Duane Bloom Tractor with improved valve system
US7353886B2 (en) 2000-12-01 2008-04-08 Western Well Tool, Inc. Tractor with improved valve system
US7188681B2 (en) 2000-12-01 2007-03-13 Western Well Tool, Inc. Tractor with improved valve system
US7607495B2 (en) 2000-12-01 2009-10-27 Western Well Tool, Inc. Tractor with improved valve system
US20080217059A1 (en) * 2000-12-01 2008-09-11 Duane Bloom Tractor with improved valve system
US20070151764A1 (en) * 2000-12-01 2007-07-05 Duane Bloom Tractor with improved valve system
US20100307832A1 (en) * 2000-12-01 2010-12-09 Western Well Tool, Inc. Tractor with improved valve system
US6679341B2 (en) 2000-12-01 2004-01-20 Western Well Tool, Inc. Tractor with improved valve system
US7080700B2 (en) 2000-12-01 2006-07-25 Western Well Tool, Inc. Tractor with improved valve system
US8245796B2 (en) 2000-12-01 2012-08-21 Wwt International, Inc. Tractor with improved valve system
US7090037B2 (en) * 2001-01-10 2006-08-15 Shell Oil Company Device for anchoring a drill string in a borehole
US20040055788A1 (en) * 2001-01-10 2004-03-25 Bruno Best Device for anchoring a drill string in a borehole
US6431291B1 (en) 2001-06-14 2002-08-13 Western Well Tool, Inc. Packerfoot with bladder assembly having reduced likelihood of bladder delamination
US6715559B2 (en) 2001-12-03 2004-04-06 Western Well Tool, Inc. Gripper assembly for downhole tractors
US20070107943A1 (en) * 2003-02-10 2007-05-17 Mock Philip W Tractor with improved valve system
US20080223616A1 (en) * 2003-02-10 2008-09-18 Western Well Tool, Inc. Tractor with improved valve system
US20040168828A1 (en) * 2003-02-10 2004-09-02 Mock Philip W. Tractor with improved valve system
US7493967B2 (en) 2003-02-10 2009-02-24 Western Well Tool, Inc. Tractor with improved valve system
US7121364B2 (en) 2003-02-10 2006-10-17 Western Well Tool, Inc. Tractor with improved valve system
US7343982B2 (en) 2003-02-10 2008-03-18 Western Well Tool, Inc. Tractor with improved valve system
US20050247488A1 (en) * 2004-03-17 2005-11-10 Mock Philip W Roller link toggle gripper and downhole tractor
US7954563B2 (en) 2004-03-17 2011-06-07 Wwt International, Inc. Roller link toggle gripper and downhole tractor
US7392859B2 (en) 2004-03-17 2008-07-01 Western Well Tool, Inc. Roller link toggle gripper and downhole tractor
US20090008152A1 (en) * 2004-03-17 2009-01-08 Mock Philip W Roller link toggle gripper and downhole tractor
US20100163251A1 (en) * 2004-03-17 2010-07-01 Mock Philip W Roller link toggle gripper and downhole tractor
US7607497B2 (en) 2004-03-17 2009-10-27 Western Well Tool, Inc. Roller link toggle gripper and downhole tractor
US7730967B2 (en) 2004-06-22 2010-06-08 Baker Hughes Incorporated Drilling wellbores with optimal physical drill string conditions
US20050279532A1 (en) * 2004-06-22 2005-12-22 Baker Hughes Incorporated Drilling wellbores with optimal physical drill string conditions
US7954562B2 (en) 2006-03-13 2011-06-07 Wwt International, Inc. Expandable ramp gripper
US8302679B2 (en) 2006-03-13 2012-11-06 Wwt International, Inc. Expandable ramp gripper
US20100018720A1 (en) * 2006-03-13 2010-01-28 Western Well Tool, Inc. Expandable ramp gripper
US7624808B2 (en) 2006-03-13 2009-12-01 Western Well Tool, Inc. Expandable ramp gripper
US20080217024A1 (en) * 2006-08-24 2008-09-11 Western Well Tool, Inc. Downhole tool with closed loop power systems
US20080053663A1 (en) * 2006-08-24 2008-03-06 Western Well Tool, Inc. Downhole tool with turbine-powered motor
US7748476B2 (en) 2006-11-14 2010-07-06 Wwt International, Inc. Variable linkage assisted gripper
US8061447B2 (en) 2006-11-14 2011-11-22 Wwt International, Inc. Variable linkage assisted gripper
US20100314131A1 (en) * 2006-11-14 2010-12-16 Wwt International, Inc. Variable linkage assisted gripper
US8327953B2 (en) * 2007-02-28 2012-12-11 Welltec A/S Drilling tool with feed control
US20100319907A1 (en) * 2007-02-28 2010-12-23 Hallundbaek Joergen Drilling Tool with Feed Control
US20080308318A1 (en) * 2007-06-14 2008-12-18 Western Well Tool, Inc. Electrically powered tractor
US8028766B2 (en) 2007-06-14 2011-10-04 Wwt International, Inc. Electrically powered tractor
US7770667B2 (en) 2007-06-14 2010-08-10 Wwt International, Inc. Electrically powered tractor
US8485278B2 (en) 2009-09-29 2013-07-16 Wwt International, Inc. Methods and apparatuses for inhibiting rotational misalignment of assemblies in expandable well tools
US20110073300A1 (en) * 2009-09-29 2011-03-31 Mock Philip W Methods and apparatuses for inhibiting rotational misalignment of assemblies in expandable well tools
US9447648B2 (en) 2011-10-28 2016-09-20 Wwt North America Holdings, Inc High expansion or dual link gripper
US9488020B2 (en) 2014-01-27 2016-11-08 Wwt North America Holdings, Inc. Eccentric linkage gripper
WO2016139264A1 (en) * 2015-03-03 2016-09-09 Welltec A/S Downhole stroking tool
EP3070258A1 (en) * 2015-03-20 2016-09-21 Welltec A/S Downhole stroking tool

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