Abstract: In one aspect of the present invention, a drilling assembly comprises a drill bit comprising a bit body and a cutting surface. A formation engaging element protrudes from the cutting surface and is configured to engage a formation. At least one compliant member is disposed intermediate the bit body and formation engaging element and is configured to provide compliancy in a lateral direction for the formation engaging element.

Abstract: Disclosed herein is a method of locating and quantifying friction between a drillstring and a wellbore. The method includes, positioning a plurality of sensors within a wellbore, communicatively coupling the plurality of sensors, monitoring signals from the plurality of sensors, logging the sensed signals versus time versus depth of each of the plurality of sensors, locating at least one friction zone along the drillstring within the wellbore based on the logging and quantifying friction in the at least one friction zone based on the logging.

Abstract: The level of hydrogen sulfide in drilling fluid within a well formed in the Earth is assessed in an ongoing and/or in situ manner. The well may be constructed for the removal of hydrocarbons from the Earth. The assessment of hydrogen sulfide level may be provided in an ongoing manner such that real time, or near real time, fluctuations in hydrogen sulfide levels in the drilling fluid within the well may be conveyed to users. This may provide various advantages over systems in which drilling fluid must be extracted and separately tested for hydrogen sulfide content, and/or in which assessments of hydrogen sulfide level require time for performance.

Abstract: The level of hydrogen sulfide in drilling fluid within a well formed in the Earth is assessed in an ongoing and/or in situ manner. The well may be constructed for the removal of hydrocarbons from the Earth. The assessment of hydrogen sulfide level may be provided in an ongoing manner such that real time, or near real time, fluctuations in hydrogen sulfide levels in the drilling fluid within the well may be conveyed to users. This may provide various advantages over systems in which drilling fluid must be extracted and separately tested for hydrogen sulfide content, and/or in which assessments of hydrogen sulfide level require time for performance.

Abstract: A downhole communication system for an extended reach borehole, including an operator unit operatively arranged to enable at least one of remote monitoring or control of at least one device disposed in the extended reach borehole. A first communicator is disposed in a highly deviated extension of the borehole and configured to receive or transmit a signal at least one of from or to the at least one device. A second communicator is included spatially remote from the borehole. The first communicator and the second communicator are located substantially in a vertically extending plane defined along a length of the highly deviated extension. The second communicator is operatively in signal communication with both the first communicator and the operator unit for enabling signal communication between the first communicator and the operator unit via the second communicator. Methods of communicating downhole and completing an extended reach borehole are also included.

Abstract: An apparatus for cutting a wellbore includes a motor having a stator and a rotor. The rotor has an output shaft connected to a cutting structure. The stator and rotor are spaced radially outwardly of the axis of rotation of the rotor such that at least one of the stator and the rotor had an access bore extending through the motor to adjacent the cutting structure. A further object can pass therethrough, without obstruction. The further object comprises a further cutting. A flow diverter is disposed in the motor proximate a connection between the motor and a wellbore tubular, and has a first fluid outlet in fluid communication with a power section of the motor, and a second fluid outlet in fluid communication with the access bore. The flow diverter is coupled to the stator such that axial loading created by fluid pressure is substantially transferred to the stator.

Abstract: A device for monitoring a seal assembly includes a body having a central axis and a through-passage, a piston slidably disposed in the through-passage and biased towards one end of the body by a biasing member, and a signaling assembly coupled to the body. The signaling assembly includes an indicator and a switch coupled to the indicator. The through-passage and the piston are exposed to a fluid pressure in the seal assembly. The piston is configured to translate axially in the through-passage to transition the switch between a first position and a second position, allowing the switch to transition the indicator between a deactivated state and an activated state.

Abstract: A method for excavating a rock cavern one round at a time and a rock drilling rig for the same. The rock drilling rig includes at least one drilling boom and at least one drilling unit is arranged in the drilling boom. A plurality of holes of a round is drilled in accordance with a drilling pattern designed for the round. In order to drill each single hole, the drilling unit is controlled in a rotating angle that effects a location and direction determined for the particular hole from the drilling pattern designed for the particular round. The rotating angle of the drilling unit to be used for drilling the hole is determined on the basis of the rotating angle of the drilling unit carried out in connection with the drilling of one or more previously drilled holes.

Abstract: The present invention relates to a drill-pipe communication assembly. The drill-pipe communication assembly includes a first drill pipe and an insulated tube disposed within, and generally concentric with, the first drill pipe. A male insert is disposed within a first end of the first drill pipe and a female insert is disposed within a second end of the first drill pipe. A conductor is electrically coupled to the male insert and the female insert. The conductor extends along a length of the first drill pipe. The conductor facilitates transmission of electrical signals from the first end of the first drill pipe to the second end of the first drill pipe.

Abstract: According to one aspect, a digital display unit includes a microcontroller to process digital information received from one or more sensors, a display, and a switch in electrical communication with the microcontroller so that the microcontroller displays an output on the display that is specific to a type of sensor. The type of sensor may be selected from a position sensor, a pressure sensor, and a stroke counter. The digital display unit may be part of a choke control panel. The microcontroller and the display may be disposed in an enclosure, and an electrical power source may be disposed in the enclosure to supply electrical power to the microcontroller and the one or more sensors. A digital hydraulic choke position sensor assembly and a digital pressure sensor assembly are also described, one or both of which may be used in a system for drilling an oil or gas well.

Abstract: A rock drilling device comprising a feed beam (4), which has a drill end (41) from which the drill point protrudes at drilling and a rear end(42) opposite the drill end; a rock drilling machine (5) movable along the feed beam (4); a pressure cylinder (6), which is arranged in connection with the feed beam (4) with one end (622) movable relative to the feed beam (4) and one end (611) fixedly arranged relative to the feed beam (4). The pressure cylinder (6) drives a feed line (51) for feeding the drilling machine (5) to and fro along the feed beam (4). The feed line (51) is routed over two outer sheaves (52, 53) that are arranged at each end (41, 42) of the feed beam (4) and a measuring device (7) for measuring the location of the drilling machine (5) relative to the feed beam (4) is arranged to the shaft (9) of one of the sheaves (52, 53) and the sheave and the shaft (9) are arranged such that they rotate together.

Abstract: Systems and methods of detecting an intersection between a wellbore and a subterranean structure that includes a marker material. The systems and methods include drilling the wellbore and determining that the wellbore has intersected a portion of the subterranean structure that includes the marker material by detecting the marker material. The systems and methods also may include distributing the marker material within the subterranean structure, aligning the marker material within the subterranean structure, determining one or more characteristics of the marker material, ceasing the drilling, repeating the method, and/or producing a hydrocarbon from the subterranean structure. The systems and methods further may include forming an electrical connection between an electric current source and a granular resistive heater that forms a portion of the subterranean structure, forming the granular resistive heater, and/or forming the subterranean structure.

Abstract: Apparatuses and methods for adjusting weight-on-bit/torque-on-bit sensor bias in a drill bit. The apparatus may include a bit adjustment device disposed at least partially in a cavity in a bit shank. The bit adjustment device includes electronics and sensors for estimating a weight-on-bit/torque-on-bit bias. The method includes adjusting the weight-on-bit/torque-on-bit sensor bias of a drill bit. The method may include adjusting force on a bit adjustment device to adjust weight-on-bit/torque-on-bit sensor bias. The method may also include securing the bit adjustment device within the cavity of the bit shank after the desired weight-on-bit/torque-on-bit sensor bias has been achieved.

Abstract: A drilling assembly is disclosed that in one embodiment includes a bi-directional wireless data transfer device between a rotating and a non-rotating member of the drilling assembly. Power may be supplied to the rotating member via any suitable method, including an inductive device and direct electrical connections.

Abstract: A drill head system and method of use is shown. Drill head systems shown provide for a secure drill head connection to a cylindrical portion or sonde housing, while still allowing for easy removal of a drill head without using pipe wrenches, breaker bars, etc. An internal fastener further provides easy assembly and disassembly of the drill head by protecting components from dirt or other debris. A tapered connection with male and female fittings are shown in one example that further provide a robust joint between components such as a drill head and a sonde housing.

Abstract: An earth-boring drilling tool comprises a cutting element. The cutting element comprises a substrate, a diamond table, and at least one sensing element formed from a doped diamond material disposed at least partially within the diamond table. A method for determining an at-bit measurement for an earth-boring drill bit comprises receiving an electrical signal generated within a doped diamond material disposed within a diamond table of a cutting element of the earth-boring drill bit, and correlating the electrical signal with at least one parameter during a drilling operation.

Abstract: A drilling rig having continuous gas analysis can include a substructure, base, mast, pipe handler, mud pump, drilling rig power source, drawworks, cabling, rotating head, blowout preventer, drill string, and drill bit. A rig server of the drilling rig can have a rig processor and rig data storage for implementing rig operations. Piping can be in fluid communication between the blowout preventer and a gas analyzer system for real-time measurement of a concentration of gases in a drilling fluid. The gas analyzer system can include a sample chamber, means for agitating and creating a vortex, gas capturing chamber for receiving liberated fluid, gas analyzer for providing real-time gas speciation of the liberated fluid, suction pump for pulling the liberated fluid, filtration means, exhaust port, and exhaust line for flowing non-analyzed fluid to a drilling fluid storage chamber, drilling fluid conduit, or both.

Abstract: A cutting element for an earth-boring drilling tool comprises a cutting body having a cutting surface thereon, and a sensor coupled with the cutting surface, the sensor configured to determine resistivity of a contacting formation. An earth-boring drilling tool comprises a bit body and an instrumented cutting element coupled with the bit body. The cutting element includes a cutting body having a cutting surface thereon, and at least one sensor located proximate the cutting surface. The at least one sensor is oriented and configured to determine resistivity of a contacting formation. A method of determining resistivity of a subterranean formation during a drilling operation comprises energizing a sensor of an instrumented cutting element of a drill bit, sensing a return signal flowing on or through the subterranean formation through the instrumented cutting element, and determining a resistivity of the subterranean formation based, at least in part, on the return signal.

Abstract: Device comprising equipment for measuring parameters of a drilling or coring operation by means of a drillbit fixed to the end of a drill string, measurement equipment (7) being housed in a chamber (5) made in a coupling (1, 18) that is designed to be interposed between two drill string pipes or between the drillbit and a drill string pipe, or to constitute an adapter (18) for a cutting head (15) of the drillbit of a drill string.

Abstract: A down hole tool includes a tool body, a fluid cavity, a magnetorheological fluid disposed in the fluid cavity, and an electrical control unit in communication with the MR fluid. The electrical control unit is configured to adjust a viscosity of the MR fluid by varying a magnetic field.

Abstract: A system and method are provided for providing electromagnetic (EM) measurement-while-drilling (MWD) telemetry capabilities using an existing mud-pulse MWD tool. An EM tool intercepts the output from the mud-pulse tool and generates an EM signal that mimics a mud-pulse pressure signal. The EM signal is intercepted at the surface by a receiver module that conditions the signal and inputs the signal into the existing pulse tool receiver. Since the EM signal mimics a mud-pulse signal, the pulse tool receiver does not require software or hardware modifications in order to process an EM telemetry mode. The EM tool can be adapted to also provide dual telemetry by incorporating a conventional pressure pulser that would normally be used with the pulse tool.

Abstract: A one trip method for cleaning an existing string while performing testing on the string allows in the same trip the drilling of additional wellbore. The cleanup equipment is retracted after the testing is completed so that it will not impede the advancement of the drill bit at the lower end of the string. The cleanup tools are typically extend for run in through the string and they can be collapsed by a technique such as dropping a ball to shift a sleeve to disable the piston assembly that holds the cleanup tools extended and allows them to be retracted using a return spring or other source of potential energy.

Abstract: The High LCM Positive Pulse MWD Component is designed to reduce the entry of LCM and debris into traditional positive pulse MWD systems by utilizing a screen positioned over the fluid ports. The component modifies the traditional poppet housing utilized in positive pulse MWD systems without changing the parameters of the fluid ports or changing the operation or need to recalibrate standard positive pulse MWD systems.

Abstract: A drill bit made according to one embodiment includes a first member including one of a magnet and a coil, and a second member that moves relative to the first member, the second member including the other of the magnet and the coil, wherein the relative motion causes the generation of an electrical charge in the coil.

Abstract: The present invention relates to a navigation system for navigating a drill head out of or in collision with a casing in a first borehole. The system comprises a drill head drilling a second borehole; a drill string made of several tubulars mounted into one tubular string by means of a connection means, the drill head being mounted onto one end of the drill string; and a plurality of logging units arranged with one logging unit in or in relation to each connection means. Each logging unit comprises a data transmitter and a data receiver for sending and receiving data between the logging units; and a detector, at least one logging unit comprising an emitter. Furthermore, the invention relates to a navigation method using the navigation system.

Abstract: Processes and apparatus that continuously change the physical state and characteristics of drilling fluids at planned periodic intervals to consistently and correctly compensate for differing geological formation properties, wellbore characteristics, rate of penetration, solids removal efficiency, and other essential factors involved in the drilling process, comprising: initiating a system correction of a Minimum Base Required (“MBR”); and administering a dilutant to a drilling fluid according to the MBR. The system corrections may be performed recursively, adjusting the system's base dilutant and chemical product additions according to MBR. The drilling fluid consistency produced is based upon several drilling-rig specific parameters.

Abstract: A downhole tool includes a downlinking system deployed in a downhole tool body having an internal through bore. The downlinking system includes a differential pressure transducer configured to measured a pressure difference between drilling fluid in the internal through bore and drilling fluid external to the tool (in the borehole annulus). The differential transducer is electrically connected with an electronic controller (deployed substantially anywhere in the drill string) that is configured to receive and decode pressure waveforms.

Abstract: This invention relates to a torque control device for a downhole drilling assembly. The torque control device is adapted for connection to a drill bit, and has an outer sleeve and an inner shaft, the outer sleeve being movable longitudinally relative to the inner shaft. The torque control device also has a cylinder, a piston located within the cylinder, and a controller to control the volume of the cylinder. Changing the volume of the cylinder causes relative longitudinal movement between the outer sleeve and the inner shaft. The controller can receive inputs from a torque sensor and/or an accelerometer in order to determine if a threshold torque has been exceeded. Alternatively the controller can comprise a rotary valve which automatically responds to torque in the assembly.

Abstract: A method for operating a coring tool includes moving a handling piston of a coring tool from a first position to a second position with respect to the coring tool where the handling piston moving through a coring bit to the second position. The method also includes measuring the distance of the movement of the handling piston between the first position and the second position to determine a core length, comparing the measured distance with a predetermined threshold, and operating a coring bit of the coring tool to obtain a core sample in response to determining that the measured distance is less than the predetermined threshold.

Abstract: A disconnector drill string has an uphole section and a downhole section coupled together by a disconnection sub, an operative length and an internal fluid conduit that extends along its operative length. The disconnection sub is operable to receive wirelessly a pre-designated command signal, to selectively couple the uphole section and the downhole section together, and to selectively uncouple the uphole section and the downhole section from one another. A method for using the disconnector drill string in a well bore includes the steps of introducing the disconnector drill string into the well bore, transmitting wirelessly the pre-designated command signal to the disconnection sub such that the disconnection sub selectively operates to uncouple the uphole section of the disconnector drill string from the downhole section of the disconnector drill string, and removing the uphole section of the disconnector drill string from the well bore.

Abstract: An apparatus and method conducting downhole measurement operations in a borehole penetrating an earth formation. The apparatus may include a module configured to be conveyed in a borehole and to receive at least one device. The module may receive the device internally or in one or more recessed areas. A housing with at least one opening may encompass the exterior of the module. The apparatus may have a first position that allows access to the module through the at least one opening, and a second position that isolates the module from the exterior of the housing. The method may include conducting downhole measurement related operations using the apparatus. The method may include moving the housing and module between the first position and the second position.

Abstract: An apparatus for communication with a downhole tool linked to a plurality of wired drill pipes includes a base. In addition, the apparatus includes an extension assembly having a first end pivotally coupled to the base and a second end. Further, the apparatus includes a head assembly pivotally coupled to the second end of the extension assembly. Still further, the apparatus includes an interface connector moveably coupled to the head assembly and configured to connect to an uphole end of the tool string and form an interface link between a surface unit and the downhole tool.

Abstract: A down hole drilling tool for preventing overpressure strain on surface pumping equipment or a down hole drilling motor having a housing and a circulation port and four hydraulic valves positioned on the housing actively working together to affectively open the circulation port to drilling annulus at a high pressure setting and dose the circulation port to annulus at a low pressure setting, the four hydraulic valves include a high pressure setting valve, a low pressure setting valve, a control valve and a fixed setting valve.

Abstract: Methods are described using resistivity measurements obtained while drilling one or more offset wells using a drilling mud to guide drilling of one or more uncased intervals of a well to identify a casing point or points in the uncased intervals of the well. Resistivity data is gathered during drilling the offset well and prior to penetrating a region of interest of a known subterranean formation. The drill string in the uncased interval of the well progresses toward the region of interest, using resistivity data at similar depths to identify a casing point while the drill bit advances toward but does not penetrate the region. In certain embodiments resistivity may also be obtained in front of the drill bit in the uncased interval of the well and used in conjunction with the offset well resistivity data to identify casing points in the uncased intervals of the well.

Abstract: A method of signal processing includes providing at least a first pressure sensor and a second pressure sensor spaced in a drilling system and using an algorithm to separate the downwardly propagating waves from the upwardly propagating waves. In one or more examples, an algorithm may include determining a velocity of pressure signals in a wellbore, time-shifting and stacking pressure signals from at least the first pressure sensor and the second pressure sensor to determine a downwardly propagating noise signal, and subtracting the downwardly propagating noise signal from at least the signal from the first pressure sensor.

Abstract: An apparatus for use in a horizontal section of a drill string is disclosed. The apparatus includes a motor that is connected to the horizontal section of the drill string. The motor is adapted to impart vibrations in the horizontal section of the drill string, where the vibrations are at about the lateral resonant frequency of the horizontal section of the drill string.

Abstract: Various embodiments include apparatus and methods that use hand mobile communications device with respect to a drilling operation at a drilling site. Data with respect to one or more sensors downhole at a drilling site can be wirelessly received in the hand mobile communications device. Representations of the received data can be displayed on a graphical user interface screen of the hand mobile communications device. The representations can include displaying the data in a graphical representation, a numerical representation, or a graphical and numerical representation on the graphical user interface screen. Additional apparatus, systems, and methods are disclosed.

Abstract: Downhole magnetic measurement devices and methods are provided for estimation of magnetic fields during drilling. In certain embodiments, a triaxial vector magnetometer is provided and affixed to a drill string subassembly. While the drill string subassembly is rotating, as during drilling operations, an average total magnetic field value (BTwR) is determined as an average of the instantaneous vector magnitudes of the three measured orthogonal component magnetic fields. In this way, near-bit estimates of the downhole magnetic field may be obtained and used for a variety of functions. These downhole magnetic measurement devices may be useful determining magnetic fields, and estimating borehole inclination and azimuth of drill string subassemblies during drilling operations. Additionally, downhole magnetic measurement devices may be used for detecting the presence and distance to external ferromagnetic materials.

Abstract: A bottom-hole assembly (202), BHA, for drilling a borehole (204, 301) in an earth formation (208, 300), comprising a percussion drill bit (208), a percussion mechanism adapted to strike the drill bit (208), at least one sensor (226, 228, 230, 232, 234) for measuring a physical quantity and converting it into an electrical signal, and converting means (237) for converting the electrical signal into a digital signal, and a method for transmitting data from such a bottom-hole assembly (202) positioned in a borehole (204, 301), the bottom-hole assembly (202) and the method being characterized by encoding the digital signal by controlling the percussion mechanism and time periods between two impacts delivered by the percussion mechanism on the drill bit (208) during drilling, and transmitting the encoded digital signal by waves generated by the impacts delivered by the percussion mechanism on the drill bit (208). A system which comprises said bottom-hole assembly (202).

Abstract: A method and device for monitoring down-the-hole percussion drilling. A down-the-hole hammer is supplied with percussion and flushing fluid flow. The down-the-hole hammer is subjected to rotational force and to feed force. Percussion frequency or a related frequency of the down-the-hole hammer is sensed. A representation of a spread thereof is created so as to produce a response to an adjustment of at least one drilling parameter as a change of width of the spread.

Abstract: An assembly for drilling and logging includes a device for electro pulse drilling (EPD device), at least one device to receive acoustic signals generated by the EPD device, distinguished in that the assembly further includes at least one device to receive electromagnetic signals generated by the EPD device. A method for drilling and logging, and device for electro pulse drilling.

Abstract: The present invention is a method and apparatus used to transmit information to the surface from a subsurface location during the process of drilling a bore hole comprising a pressure pulse generator or “pulser” coupled to a sensor package, a controller, an active electromagnetic system for subsurface collision avoidance, and a battery power source all of which reside inside a short section of drill pipe close to the bit at the bottom of the bore hole being drilled wherein the apparatus or “MWD Tool” can be commanded from the surface to make a measurement of desired parameters and transmit this information to the surface by encoding data in pressure pulses generated by a pulser valve that includes a stator and a rotor which may be open and closed to create pressure pulses.

Abstract: The present invention relates to making one or more measurements in a virgin formation using a downhole tool that includes a miniature logging tool. The downhole tool is disposed in a wellbore penetrating the formation, adjacent to the formation, and a sidetrack borehole is made into the formation. All or a portion of the miniature logging tool is deployed into the sidetrack borehole and measurements are made in the virgin formation using the miniature logging tool. The downhole tool may include a drilling/coring module, a pump module, and packers. The drilling/coring module is used to make the sidetrack borehole, and the packers and pump module can be used to create an underbalanced drilling condition in an isolated section of the wellbore.

Abstract: Systems and methods to inhibit packoff during drilling assembly removal from a wellbore, utilizing a drilling assembly that includes a transition region between a first section having a first cross-sectional area and a second section having a second cross-sectional area, wherein the second cross-sectional area is greater than the first cross-sectional area. The transition region includes a fluidizing assembly configured to partially fluidize a portion of the cuttings bed that is proximal to the transition region, and/or be in fluid communication with a flow control assembly configured to control flow rate of a fluidizing stream from the fluidizing assembly and to the portion of cuttings bed.

Abstract: A method for controlling a downhole pressure during drilling comprises continually sensing in real-time at least one real-time fluid property of an input fluid to a well and of a return fluid from the well. A wellhead setpoint pressure is calculated in real-time that results in a predetermined downhole pressure at a predetermined location in the well, where the calculation based, at least in part, on the at least one continually sensed real-time fluid property. The flow of the return fluid is controllably regulated to maintain the calculated wellhead setpoint pressure.

Abstract: Processes and systems for drilling a borehole wherein a gravitational energy term, a torsional energy term, a hydraulic energy term and a hydromechanical specific energy which is the sum thereof may be determined using real-time data and compared against corresponding setpoints. The hydraulic energy term may include a hydraulic energy reduction factor so as to account for the distance between the fluid nozzle of the drill bit and the rock and may include the kinematic viscosity of drilling fluid. One or more drilling parameters, such as weight on bit, revolutions per minute, drilling fluid flow rate, or combinations thereof, may be adjusted based upon such comparison to approximate the least amount of energy required to destroy and remove a given unit volume of rock. The setpoints may be changed manually or automatically at the direction of the user.

Abstract: Aspects of the inventions generally provide a method and apparatus for coupling a communication sub to a wired drill pipe. In one aspect, a surface of a coupler head is non threaded and configured to provide a retaining force. In another aspect, a coupler head is coupled to a body, and a support mechanism is coupled to the body and configured to secure the coupler head within a receiving end of the wired drill pipe. In another aspect, a method of placing a communication sub involves inserting the communication sub into the receiving end of the wired drill pipe, adjusting the position of the communication sub until an indication of signal communication between the communication sub and the wired drill pipe is observed, and after the indication of signal communication is observed, retaining the communication sub within the receiving end until removal of the communication sub is desired.

Abstract: A dual pipe rod assembly section includes an inner rod section and an outer rod section, with a probe which is arranged in the dual pipe rod assembly section, a horizontal drilling device and a probe housing. The probe is arranged in the inner rod section and rotationally coupled to the outer rod section.

Abstract: The present invention relates to a control of a compressor (8) at a rock drilling apparatus, said rock drilling apparatus including a power source for driving a compressor (8) at a rock drilling process, said compressor (8) being arranged to operate according to a first mode and according to a second mode, wherein, in said first mode, the work produced by the compressor (8) is arranged to be controlled by controlling the rotation speed of said compressor (8), and wherein, in said second mode, the work produced by the compressor (8) is arranged to be controlled by controlling the air flow at the compressor inlet.

Abstract: Embodiments of the present invention generally relate to extendable cutting tools for use in a wellbore. In one embodiment, a tool for use in a wellbore includes a tubular body having a bore therethrough, an opening through a wall thereof, and a connector at each longitudinal end thereof; and an arm. The arm is pivotally connected to a first piston and rotationally coupled to the body, is disposed in the opening in a retracted position, and is movable to an extended position where an outer surface of the arm extends outward past an outer surface of the body. The tool further includes the first piston. The first piston is disposed in the body bore, has a bore therethrough, and is operable to move the arm from the retracted position to the extended position in response to fluid pressure in the piston bore exceeding fluid pressure in the opening. The tool further includes a lock operable to retain the first piston in the retracted position; and a second piston operably coupled to the lock.