Abstract: A system for optimizing a rate-of-penetration of a drill string includes a plurality of sensors in operable communication with the drill string and a controller in operable communication with the plurality of sensors. The controller is connectable to a downhole active vibration control device and capable of outputting a signal to the downhole active vibration control device for optimizing the rate-of-penetration of the drill string.

Abstract: Apparatus and methods used to prevent an operator from inadvertently dropping a string into a wellbore during assembling and disassembling of tubulars. In one instance, an interlock system is used to control the operations of a gripping apparatus connected to the top drive and a spider such that at least one of the top drive or the spider retains the tubular. The interlock system allows the spider to open when the gripping apparatus is supporting a load of the tubular or is in position to support a load of the tubular.

Abstract: A control circuit for a coiled tubing injector includes a circuit controller (14). One or more counterbalance valves (3) may be responsive to the circuit controller to prevent the tubing string from descending into the wellbore during rate of penetration movement. In one embodiment, a control valve (4) allows fluid to flow through a bypass line around the counterbalance valves when drilling in a weight-on-bit mode. Other hydraulic control circuits allow for the release of fluid pressure to control the injector hydraulic motor. In yet another embodiment, the control circuit regulates power to an electric motor of the injector.

Abstract: A system for monitoring loads at well drilling and service operations includes a digital user interface. The digital interface is in electronic communication with a first pressure transducer in fluid communication with a first pad type hydraulic load sensor, a second pressure transducer in fluid communication with a second pad type hydraulic load sensor, and a third pressure transducer in fluid communication with a hydraulic diaphragm type deadline load sensor. The digital user interface module functions to monitor the hydraulic pressures experienced at each pressure transducer and functions to calculate and display a corresponding weight load in numerical and graphical form for each pressure transducer. The digital user interface is also in electronic communication with a fourth transducer in fluid communication with a hydraulic power tong unit.

Abstract: The invention relates to a control apparatus for controlling a rock-drilling rig performing a multiphase rock-drilling event. The control apparatus is arranged to display a working phase indicator on a display, and rock drilling phase-specific information elements is associated with different working phases. The control apparatus is arranged to specify the phase of the rock-drilling event and to update the working phase indicator to display at least one display information element in accordance with the specified working phase.

Abstract: A system and method of making up and breaking out a dual-member drill string. The system comprises a spindle, a spindle carriage and a drive frame. The drive frame provides thrust to the spindle, while the spindle carriage provides rotation. The spindle has an outer spindle and an inner spindle, and is adapted to connect to a pipe section having an outer pipe section and an inner pipe section. Inner joints are geometrically shaped, while outer joints are threaded. When making up dual member drill string, the spindle is advanced, with the outer spindle rotating, and the inner spindle rotating in alternating directions, or “dithering.” A float sensor and a processor are used in tandem to cooperatively couple the inner spindle with the inner pipe sections and the outer spindle with the outer pipe sections.

Abstract: A system for optimizing a rate-of-penetration of a drill string includes a plurality of sensors in operable communication with the drill string; and a controller in operable communication with the plurality of sensors. The controller is connectable to a drill string motivator and capable of outputting a signal to the drill string motivator for optimizing the rate-of-penetration of the drill string, and the signal is configured to provide at least one of weight on bit, an amount of speed to rotate the drill string, an amount of torque to be applied to the drill string, and an amount of mudflow to the drill string.

Abstract: A cylinder stroke system with a laser proximity detector including a pressure containing tube. The pressure containing tube can include a first tube end and a second tube end. A cylinder rod can be movably disposed within the pressure containing tube. The system can also include a piston disposed on the cylinder rod first end; a first fluid port formed in the pressure containing tube; a second fluid disposed within the pressure containing tube; a blind end cap and mount; a laser secured to the pressure containing tube; at least one optic guide; a lens separating the at least one optic guide from the second fluid. The cylinder stroke system can also include a camera in communication with a main controller. The camera can receive the reflection from the piston and convert the reflection into a reflection signal.

Abstract: A well drilling method utilizing real time response to ahead of bit measurements. A well drilling method includes measuring a property of a portion of the earth prior to drilling a wellbore into the earth portion; and varying a drilling parameter in real time while drilling the wellbore, in response to measuring the property.

Abstract: This disclosure, in one aspect, provides an apparatus for use in a wellbore that includes a member having an encoded magnetic field and a sensor proximate the encoded magnetic field that measures a change in the magnetic field due to a change in the load on the member. In another aspect, a method for measuring loads on a downhole tool is provided that comprises inducing an encoded magnetic field along a section of a member of the tool and detecting a change in the magnetic field due to a load on the member when the tool is in the wellbore.

Abstract: The invention relates to a method for drilling rock, wherein holes to be drilled are determined prior to drilling as a drilling pattern wherein for each hole, a starting place, direction and hole depth for drilling are determined with respect to the rock to be drilled. In the invention, hole-type-specific drilling parameters are determined for the holes to be drilled, and during a drilling phase a drill rig automatically selects drilling parameters for each hole to be drilled on the basis of the hole type of the particular hole.

Abstract: An anti-stall tool in an oil well drilling assembly that controls reciprocation of the drill bit by a controller that alters weight-on-bit (WOB) depending upon measured downhole pressure or torque at the downhole motor. The controller receives preset high and low working pressure limits for the downhole motor and keeps the drill bit rotating by maintaining WOB during normal drilling operations, increasing WOB if sensed working pressure indicates that drill bit loading or torque is undesirably low, and reversing WOB by retracting the drill bit if excessive working pressure or torque is sensed.

Abstract: Method and apparatus for controlling rock drilling with a percussion device belonging to a rock drill to deliver stress waves to rock through a tool by pushing the tool against the rock by means of a feed motor and rotating simultaneously the tool by means of a rotation motor, whereby the maximum feed force is determined, pressure medium is supplied to the feed motor and to the rotation motor and the feed force is controlled according to the drilling conditions. The feed force is controlled on the basis of the feed speed and the rotation torque. The apparatus has a load control valve which controls the feed.

Abstract: A drill bit made according to one embodiment includes a bit body and at least one preloaded sensor in the bit body. In one aspect, the sensor may include a sensor element on a sensor body having a first end and a second end and wherein the sensor is preloaded after placing the sensor body in the bit body. In another aspect, the sensor may be preloaded outside the bit body and then placed in the bit body in a manner that enables the sensor to retain the preloading.

Abstract: A drilling tool includes a hydraulically driven device (21) for advancing a drilling head (2) in a bore (5), and a flow limiter (30) arranged in a hydraulic conduit (25) of the advancing device (21) for adjusting an advancing speed of the drilling head (2) in the bore (5), with the flow limiter (30) having a pressure-actuated adjusting member (38) for adjusting flow of a hydraulic fluid in the hydraulic conduit means (25) in accordance with a flow volume of a rinsing fluid (7) for rinsing the bore.

Abstract: An anti-stall tool in an oil well drilling assembly that controls reciprocation of the drill bit by a controller that alters weight-on-bit (WOB) depending upon measured downhole pressure or torque at the downhole motor. The controller receives preset high and low working pressure limits for the downhole motor and keeps the drill bit rotating by maintaining WOB during normal drilling operations, increasing WOB if sensed working pressure indicates that drill bit loading or torque is undesirably low, and reversing WOB by retracting the drill bit if excessive working pressure or torque is sensed.

Abstract: A wellbore drilling system includes a weight on bit controller configured to generate a normalized weight on bit output, a drilling torque controller configured to generate a normalized toque on bit output, and a differential pressure controller configured to generate a normalized differential pressure output. The system further includes a rate of penetration controller that is configured to multiply a rate of penetration setpoint with the normalized weight on bit output, the normalized torque on bit output, and the normalized differential pressure output to generate a rate of penetration output.

Abstract: A drilling agitator tool, system and method facilitates axial movement of a drill string in a well. The tool has a valve assembly that provides pulses of fluid pressure in the drill string. A valve control assembly controls a frequency and pressure amplitude of the pulses induced by the valve assembly. The valve control assembly monitors real-time pressure and vibration levels of the drill string. An agitator assembly reciprocates in response to the pulses of fluid pressure to provide axial movement of the drill string in the well.

Abstract: A system and method of making up and breaking out a dual-member drill string. The system comprises a spindle, a spindle carriage and a drive frame. The drive frame provides thrust to the spindle, while the spindle carriage provides rotation. The spindle has an outer spindle and an inner spindle, and is adapted to connect to a pipe section having an outer pipe section and an inner pipe section. Inner joints are geometrically shaped, while outer joints are threaded. When making up dual member drill string, the spindle is advanced, with the outer spindle rotating, and the inner spindle rotating in alternating directions, or “dithering.” A float sensor and a processor are used in tandem to cooperatively couple the inner spindle with the inner pipe sections and the outer spindle with the outer pipe sections.

Abstract: A drilling assembly for drilling pipe into a drilling surface using a drill bit. The drilling assembly comprises a power unit, a thrust frame, a means for moving the thrust frame, a rotary and carriage assembly and a microprocessor adapted to control the load on the drill based upon the level of mud pressure in the assembly. The drilling assembly is adapted to drill pipe at any angle relative to the drilling surface between substantially parallel to the drilling surface and substantially perpendicular to the drilling surface. The method comprises providing a such drilling assembly, placing a drill pipe onto the drilling assembly, moving the thrust frame to a desired drilling angle, moving the rotary and carriage assembly into direct contact with the drill pipe, applying rotational, thrust and pull-back forces to the drill pipe, drilling the pipe into the drilling surface and controlling the load on the drill bit.

Abstract: Methods of adjusting a velocity at which a drill string is moved within a well are provided. One method includes adjusting the velocity at which the drill string is moved within the well based upon a hookload associated therewith. Another method includes adjusting the velocity at which the drill string is moved within the well based upon the actual velocity at which the drill string is moved within the well. Another method includes adjusting the velocity at which the drill string is moved within the well based upon the volume of fluid displaced by the drill string flowing from the well as it is lowered into the well.

Abstract: A steerable drilling system includes a drill string carrying a bent housing, the bent housing containing or having associated therewith a drive motor arranged to drive a drive shaft angled to an axis of part of the drill string adjacent the bent housing, and an orientating motor permitting relative rotation between the drill string and the bent housing, the orientating motor driving the output shaft in a reverse direction relative to a direction of rotation of the drill string to form a curve in a borehole being formed.

Abstract: A system and method of making up and breaking out a dual-member drill string. The system comprises a spindle, a spindle carriage and a drive frame. The drive frame provides thrust to the spindle, while the spindle carriage provides rotation. The spindle has an outer spindle and an inner spindle, and is adapted to connect to a pipe section having an outer pipe section and an inner pipe section. Inner joints are geometrically shaped, while outer joints are threaded. When making up dual member drill string, the spindle is advanced, with the outer spindle rotating, and the inner spindle rotating in alternating directions, or “dithering.” A float sensor and a processor are used in tandem to cooperatively couple the inner spindle with the inner pipe sections and the outer spindle with the outer pipe sections.

Abstract: A draw-works (10) is for maneuvering drilling devices that includes a winder (11) for winding at least one rope (12), which is centered on a shaft (13) having one first end and one second end and rotating in one first direction and in one second direction opposite to the first. The winder (11) is at least partially substantially cylindrical in shape. One or more supports (14) rotatably support the shaft (13). Motors (19) are designed to enable rotation in the first direction and in the second direction of the shaft (13) and of the winder (11). The supports (14) and the motors (19) are fixed to a frame base (16). The motors (19) are set on both sides of the winder (11) and connect to them without speed-reducing elements, with direct drive on the shaft (13).

Abstract: A system for drilling a well comprises a drill string in a wellbore having a bit at a distal end thereof. At least one sensor measures a drilling parameter. A computer controller has a set of instructions stored therein to process the measured drilling parameter over a drilled interval to calculate, in substantially real time, an updated friction slope and an updated worn bit slope and to calculate an updated drilling parameter for at least a portion of the well-based on the updated friction slope and the updated worn bit slope.

Abstract: A method and system of subterranean excavating that estimates a buoyancy force applied to a downhole excavating system from drilling fluid. The estimated buoyancy force is used to derive a true weight on bit (WOB) at the borehole bottom. The derived realized WOB is compared to a target WOB to obtain a change in WOB. Based on the change in WOB, the excavating system is adjusted so the realized WOB approximates the target WOB. The excavating system adjustment includes applying a compensating force to the string. Compensating forces can be produced by manipulating a block assembly or deploying a thruster device in the string.

Abstract: Methods and apparatus for MSE-based drilling operation and/or optimization, comprising detecting MSE parameters, utilizing the MSE parameters to determine MSE, and automatically adjusting drilling operational parameters as a function of the determined MSE.

Abstract: A system and a method manage and use data related to a wellbore or a drill string. The system and the method may provide remote access to tools in a drill string using a network. In addition, the tools have access to the data. In a disclosed embodiment, the tools are able to automatically access the data needed to optimize or improve function of the tools. An example of the network is a wireless network where the tools may be monitored and/or controlled remotely by an application. A linking tool is optionally provided to communicate with the network and one or more of the tools.

Abstract: An anti-stall tool in an oil well drilling assembly that controls reciprocation of the drill bit by a controller that alters weight-on-bit (WOB) depending upon measured downhole pressure or torque. The downhole controller keeps the drill bit rotating by maintaining WOB during normal drilling operations, increasing WOB if sensed working pressure indicates that drill bit loading or torque is undesirably low, and reversing WOB by applying a spring force for retracting the drill bit if excessive working pressure or torque is sensed.

Abstract: A system and method of making up and breaking out a dual-member drill string. The system comprises a spindle, a spindle carriage and a drive frame. The drive frame provides thrust to the spindle, while the spindle carriage provides rotation. The spindle has an outer spindle and an inner spindle, and is adapted to connect to a pipe section having an outer pipe section and an inner pipe section. Inner joints are geometrically shaped, while outer joints are threaded. When making up dual member drill string, the spindle is advanced, with the outer spindle rotating, and the inner spindle rotating in alternating directions, or “dithering.” A float sensor and a processor are used in tandem to cooperatively couple the inner spindle with the inner pipe sections and the outer spindle with the outer pipe sections.

Abstract: Drilling a bore hole comprises rotary drilling at a first rotation rate until a first target value is substantially met, changing the first rotation rate to a second rotation rate when a trigger is substantially met, and then drilling at the second rotation rate until a second target value is substantially met. Preferably, the second rotation rate is substantially zero, so the drilling at the second rotation rate is slide drilling. Finally, the steps of rotary drilling at a first rotation rate, changing the rotation rate to a second rotation rate, and drilling at the second rotation rate are repeated.

Abstract: A wellbore drilling system is disclosed herein, in which the system includes a weight on bit controller configured to generate a normalized weight on bit output, a drilling torque controller configured to generate a normalized toque on bit output, and a differential pressure controller configured to generate a normalized differential pressure output. The system further includes a rate of penetration controller that is configured to multiply a rate of penetration setpoint with the normalized weight on bit output, the normalized torque on pit output, and the normalized differential pressure output to generate a rate of penetration output.

Abstract: A system for optimizing a rate-of-penetration of a drill string, the system including: a plurality of sensors in operable communication with the drill string; and a controller in operable communication with the plurality of sensors, the controller connectable to a drill string motivator and capable of outputting a signal to the drill string motivator for optimizing the rate-of-penetration of the drill string, the signal configured to provide at least one of weight on bit, an amount of speed to rotate the drill string, an amount of torque to be applied to the drill string, and an amount of mudflow to the drill string.

Abstract: A drilling tool includes a hydraulically driven device (21) for advancing a drilling head (2) in a bore (5), and a flow limiter (30) arranged in a hydraulic conduit (25) of the advancing device (21) for adjusting an advancing speed of the drilling head (2) in the bore (5), with the flow limiter (30) having a pressure-actuated adjusting member (38) for adjusting flow of a hydraulic fluid in the hydraulic conduit means (25) in accordance with a flow volume of a rinsing fluid (7) for rinsing the bore.

Abstract: A method of automatic drilling of a well with coil tubing or drill pipe tubing utilizes AC motors coupled to variable frequency drives controlled by a programmable logic controller. For example, a coil tube injector is supported in a mast for injecting coil tube from a reel and into a wellbore for drilling the wellbore. The AC motors for the injector are driven for controlling a rate of injection of coil tube by the injector for maintaining at least one drilling parameter such as weight-on-bit, differential mud pressure or rate of penetration. The AC motor for the reel is also controlled for driving the reel and maintaining a relative rate of coil tube supplied from the reel to the injector. Drawworks and a top drive supported by the draworks can also be equipped with AC motors and variable frequency drives for controlling a drilling rate for maintaining at least one of the drilling parameters.

Abstract: A system for monitoring and controlling a load on a downhole component of a well drilling system is disclosed. The system includes: a downhole tool disposed in a drillstring and configured to be movable within a borehole, the drillstring configured to allow a drilling fluid to be advanced therethrough and into the borehole; at least one sensor disposed within the downhole tool for in-situ measurement of at least one physicochemical property of an environment surrounding the downhole tool; and a processor configured to monitor the at least one physicochemical property and at least one of i) provide physicochemical property information to a user during a drilling/steering operation, ii) adjust a load on the downhole component based on the environment information and iii) shut down the system in response to a detection of a measured physicochemical property beyond a selected threshold.

Abstract: A drilling apparatus includes a tubular body including an upper connection and a lower connection with a drill bit disposed thereon, and an axial borehole therethrough, wherein the upper connection is configured to attach to a drillstring, primary cutter blocks coupled to the tubular body and configured to selectively expand radially therefrom. The drilling apparatus further includes backup cutter blocks coupled to the tubular body and configured to selectively expand radially therefrom, and an activation system configured to selectively expand and collapse the primary and backup cutter blocks in response to changes in weight applied to the primary and backup cutter blocks.

Abstract: A system and method of making up and breaking out a dual-member drill string. The system comprises a spindle, a spindle carriage and a drive frame. The drive frame provides thrust to the spindle, while the spindle carriage provides rotation. The spindle has an outer spindle and an inner spindle, and is adapted to connect to a pipe section having an outer pipe section and an inner pipe section. Inner joints are geometrically shaped, while outer joints are threaded. When making up dual, member drill string, the spindle is advanced, with the outer spindle rotating, and the inner spindle rotating in alternating directions, or “dithering.” A float sensor and a processor are used in tandem to cooperatively couple the inner spindle with the inner pipe sections and the outer spindle with the outer pipe sections.

Abstract: A drilling apparatus controls or eliminates reaction torque from drill bits thereby preventing loss of penetration due to undesired rotation of the drilling apparatus or controls drilling direction by intentionally manipulating reaction torque thereby inducing desired drill bit walk. The drilling apparatus has a concentrically divided drill bit in which an inner drill bit rotates simultaneously in the opposite direction from an outer drill bit. The inner drill bit can be moved axially forward from or back toward the outer drill bit. Forces produced by the inner and outer drill bits are controlled to eliminate or adjust reaction torque.

Abstract: According to the invention, a system for drilling a cavity in a medium is disclosed. The system may include a drill bit, a processor, and a controller. The drill bit may be configured to rotate in the medium and remove at least a portion of the medium. The processor may be configured to receive a first set of data representative of a variable rotational speed of the drill bit during a length of time in the medium, and determine, based at least in part on the first set of data, a first resonant frequency of the variable rotational speed of the drill bit. The controller may be configured to receive a second set of data representative of the first resonant frequency of the variable rotational speed of the drill bit, and vary the force applied to the drill bit based at least in part on the second set of data.

Abstract: A system and method for controlling drill string frictional forces during horizontal drilling are provided. The system includes a top drive having a motor that transmits a torque to a drill string to rotate the drill string, and an automated controller operably connected to the top drive to send at least one command signal to the top drive to initiate the rotation of the drill string. The controller monitors torque feedback signals, indicating that a torque limit on the drill string is exceeded, and/or a turn feedback signals indicating that the drill string is stalled to control the direction of the torque applied to the drill string when either the torque limit is exceeded or the drill string stalls.

Abstract: An automatic driller for controlling a rotating primary mover. The automatic driller has a manual brake handle. The manual brake handle has a stroke. A first elastic means applies a first tension to the manual brake handle. A swivel bracket is connected to the first elastic means. The first elastic means provides a first tension onto the swivel bracket.

Abstract: A method and system of subterranean excavating that estimates a buoyancy force applied to a downhole excavating system from drilling fluid. The estimated buoyancy force is used to derive a true weight on bit (WOB) at the borehole bottom. The derived realized WOB is compared to a target WOB to obtain a change in WOB. Based on the change in WOB, the excavating system is adjusted so the realized WOB approximates the target WOB. The excavating system adjustment includes applying a compensating force to the string. Compensating forces can be produced by manipulating a block assembly or deploying a thruster device in the string.

Abstract: A rotary coring device and a method for acquiring a sidewall core from an earth formation adjacent a wellbore are provided. The rotary coring device includes a coring tool having a housing with a core receptacle therein and being adapted for positioning at selected depths within the wellbore. The coring tool further includes a first gear assembly operably coupled to a rotary coring bit. The first gear assembly is configured to rotate the rotary coring bit. The rotary coring device further includes an electrical motor configured to drive the first gear assembly for rotating the rotary coring bit at one of a plurality of rotational speeds. The rotary coring device further includes a hydraulic actuator configured to move the rotary coring bit in a first direction toward the earth formation for obtaining the sidewall core and to move the rotary coring bit in a second direction away from the earth formation.

Abstract: In one aspect, the invention comprises an instrumented drill head for intended use with a drilling machine including a drilling element, such as a drill bit. The drill head includes a case with a rotatable chuck for the drilling element. A first sensor associated with the drill head senses and generates an output signal representative of a first parameter of the drilling operation. A transmitter wirelessly transmits the signal to a receiver associated with a controller. A roof bolting machine including the drill head and a resin inserter is also disclosed, as are related methods of instrumenting a drill head and drilling using an instrumented drill head.

Abstract: An apparatus is provided for maintaining control of a machine which produces thrust, rotation or other outputs in response to input signals. The apparatus has two distinct parts, namely the operator input portion and the output portion. The operator input portion consists of the primary thrust, rotation and other output control, and the input signal generation, signal maintenance and signal resume control. Through these controls, the operator enters the desired operation at conditions and levels for rotation, thrust, and other input signals. The output portion consists of an information processing and control portion and the power units for rotation, thrust and other outputs generated from the machine. The information processing and control system interprets all of the desired operational conditions and levels from the input portion and sends commands to the thrust, rotation and other power units to produce the desired outputs in response to the input signals.

Abstract: A system and method of making up and breaking out a dual-member drill string. The system comprises a spindle, a spindle carriage and a drive frame. The drive frame provides thrust to the spindle, while the spindle carriage provides rotation. The spindle has an outer spindle and an inner spindle, and is adapted to connect to a pipe section having an outer pipe section and an inner pipe section. Inner joints are geometrically shaped, while outer joints are threaded. When making up dual, member drill string, the spindle is advanced, with the outer spindle rotating, and the inner spindle rotating in alternating directions, or “dithering.” A float sensor and a processor are used in tandem to cooperatively couple the inner spindle with the inner pipe sections and the outer spindle with the outer pipe sections.

Abstract: An apparatus is used with an impact hammer penetration assemble such as standard penetration test (SPT) in geotechnical engineering. The impact hammer penetration assembly comprises a penetration sample, a series of rods coupled together and an impact hammer apparatus. The drop of the hammer from a constant height hits the coupled rods and sampler in series and forces the sampler deeper into the ground. The apparatus includes a tip depth transducer and sampler to output a first electrical signal that is a function of the sampler tip position. A shock force transducer communicates the axial shock force in the rod to output a second electrical signal that is a function of the rod shock force and hammer blows. A shock penetration transducer communicates the movement of the coupled rods and sampler to output a third electrical signal that is a function of the sampler penetration due to the hammer blows. A micro-process controller monitors and processes the first, second and third signals in real time.

Abstract: Methods and apparatus for MSE-based drilling operation and/or optimization, comprising detecting MSE parameters, utilizing the MSE parameters to determine MSE, and automatically adjusting drilling operational parameters as a function of the determined MSE.

Abstract: A drilling apparatus controls or eliminates reaction torque from drill bits thereby preventing loss of penetration due to undesired rotation of the drilling apparatus or controls drilling direction by intentionally manipulating reaction torque thereby inducing desired drill bit walk. The drilling apparatus has a concentrically divided drill bit in which an inner drill bit rotates simultaneously in the opposite direction from an outer drill bit. The inner drill bit can be moved axially forward from or back toward the outer drill bit. Forces produced by the inner and outer drill bits are controlled to eliminate or adjust reaction torque.