Abstract: Systems and methods for utilizing hybrid mechanical-laser drilling tools, such as drill bits and hole-openers, are provided. Such drilling tools may include mechanical cutters in addition to laser cutting mechanisms designed to focus laser beams toward a subterranean formation. The mechanical cutters and laser cutting mechanisms may work in combination to advance a wellbore through the subterranean formation. The drilling tools may be controlled to vary the amount of energy output through the mechanical drilling via the cutters and through the laser-assisted drilling via the lasers.

Abstract: A drilling apparatus having a drive section and a bearing section axially distal to the drive section. The bearing section includes a unitary bearing housing defining a bearing housing bore, a driveshaft received within the bearing housing bore and rotatable relative to the bearing housing, and a bearing assembly radially interposed between the bearing housing and the driveshaft for rotatably supporting the driveshaft within the bearing housing bore. The unitary bearing housing may be connected directly with a transmission housing. An axis intersection point between a primary axis of the drilling apparatus and the driveshaft axis may be axially located between a proximal bearing housing end and a distal bearing housing end. One or more stationary bearing components may be non-rotatably engaged with one or more sleeves which are non-rotatably engaged with the bearing housing.

Abstract: A surface steerable system coupled to a drilling rig receives BHA information from a bottom hole assembly (BHA) located in a borehole. The BHA information corresponds to a first location of the BHA with respect to a target drilling path and geological formation drift information. The surface steerable system calculates a toolface vector to create a convergence path from the first location of the BHA to the target drilling path that accounts for geological formation drift defined by the geological formation drift information such that the BHA will converge with the target drilling path by drilling in accordance with the toolface vector. The surface steerable system causes at least one control parameter to be modified in order to alter a drilling direction of the BHA based on the calculated toolface vector and transmits the at least one control parameter to the drilling rig to target the BHA in accordance with the calculated toolface vector.

Abstract: The static push-the-bit articulated high-built-rate rotary steerable tool has the main body of a non-rotary measurement and control unit articulated with the main body of a non-rotary actuator, rather than an integral structure. Due to the fact that the drilling tool is easy to bend in a wellbore, the bending stress in an upper portion of the steerable tool is low, and the consumption of the pushing force for bending deformation of the drilling tool is minimized. Since the steering sleeve around the main body of a load-bearing actuator only slides along the well wall in an axial direction without rotational friction there-between, the service life of the steering sleeve is long. Besides, since hydraulic pressure is used instead of pressure difference of mud to act on the pistons to form the pushing force, the pushing force is greatly improved, and the sealing life of the pistons is longer.

Abstract: A drilling apparatus having a drive section and a bearing section axially distal to the drive section. The bearing section includes a bearing housing having a bearing housing bore defining a bearing housing bore axis, a sleeve assembly received within the bearing housing bore, the sleeve assembly having a sleeve assembly bore defining a sleeve assembly bore axis, a driveshaft received within the sleeve assembly bore, and a bearing assembly for rotatably supporting the driveshaft within the sleeve assembly bore. The sleeve assembly includes a plurality of axially arranged sleeve sections. The sleeve assembly bore axis is oblique to the bearing housing bore axis. The sleeve sections may be received within the bearing housing bore so that they maintain a fixed angular position relative to each other and relative to the bearing housing, and so that they maintain a fixed axial position relative to the bearing housing.

Abstract: A system and method for drilling is disclosed, the system including a drill string with at least one drill pipe, a bottom hole assembly and a drill bit. The bottom hole assembly includes a downhole mud motor for rotating the drill bit, and a steering motor coupled between the mud motor and the drill pipe. The downhole mud motor includes a bent housing. The drill pipe is continuously rotated to minimize friction, regardless of whether the drill bit is turned using rotary drilling or drilling with the downhole mud motor. Tool face orientation may be controlled by operating the steering motor at the drill pipe speed, but in an opposite rotational direction to thereby hold the mud motor and bent housing stationary with respect to the formation. Steering motor speed may be increased or decreased to adjust tool face orientation.

Abstract: A method for introducing a borehole into the ground includes advancing at least two drill heads, detecting one of the two drill heads is detected by a detection unit on the other drill head, and adapting the direction of advance of at least one of the drill heads relative to the other drill head.

Abstract: A method for evaluating load performance of a rotor/stator test coupon, advantageously within a sealable test chamber comprising test fluid. In some embodiments, the test coupon comprises at least a partial length of a PDM stage, and in others the test coupon comprises a splined rotor/stator. The method includes rotating either the rotor section or the stator section, wherein such rotation actuates corresponding rotation of the other of the rotor section and the stator section. A braking torque is applied to the actuated one of the rotor section and the stator section such that load performance of the test coupon may be evaluated. Embodiments include selectively applying non-linear torque to load the test coupon, and evaluating load performance of the test coupon with reference to relative angular positions of the rotor section and the stator section over time.

Abstract: A latching assembly for use in a well system is provided. The latching assembly can include an outer mandrel and a running tool coupling assembly coupled to a first longitudinal end of the outer mandrel. The running tool coupling assembly can be operable to couple to a running tool that includes a drill string component. The latching assembly can be controllable using the running tool. The latching assembly can also include a bearing coupling assembly coupled to a second longitudinal end of the outer mandrel that is opposite longitudinally with respect to the first longitudinal end. The bearing coupling assembly can be operable to couple to a bearing assembly. The latching assembly can further include a rotating control device (RCD) coupling assembly coupled to the side of the outer mandrel. The RCD coupling assembly can be operable to couple to an RCD positioned in the well system.

Abstract: A fully rotating bias unit for directional drilling rotates at bit speed while providing proportional control of directional response and steering force. The unit also provides added reliability by having increased redundancy (multiple independently controlled actuators). The unit disposed on a drillstring transfers rotation to a drill bit and has a bore communicating fluid from the drillstring to the drill bit. Directors are disposed on the unit to rotate with it. Each of the directors is independently movable between extended and retracted conditions relative to the unit's housing. Actuators of the unit are in fluid communication between the bore and the borehole or some other low pressure. Each actuator is independently operable to direct communicated fluid from the bore to extend a respective one of the directors toward the extended condition.

Abstract: A technique facilitates delivery of high pressure actuating fluid, e.g. drilling mud, to a plurality of actuators. The technique employs a valve system in which high pressure actuating fluid is delivered from inside a rotor to outer stator ports on a surrounding stator. The construction and arrangement of the rotor and stator reduces the inherent instability and susceptibility to sticking that can otherwise affect the operation of the valve.

Abstract: A self-guided geosteering assembly having an on-board, automated guidance system that incorporates a detailed subsurface earth model and well path to geosteer the assembly along a formation. While advancing along the formation, the guidance system continually monitors data related to formation characteristics and the formation/tool location, compares the data to the earth model and well path, and adjusts the direction of the assembly accordingly. In addition, the data may be utilized to update the earth model in real-time.

Abstract: Some examples of monitoring hydrocarbon reservoirs using induced polarization effect includes inducing polarization in a subterranean zone using an induced polarization fluid. The subterranean zone includes first formations and second formations. A quantity of hydrocarbons in the first formations is greater than quantity of hydrocarbons in the second formations. The induced polarization data is obtained from the subterranean zone. A portion of the induced polarization data from the first formations is different from a portion of the induced polarization data from the second formations. The second formations in the subterranean zone are identified based on the obtained induced polarization data.

Abstract: A plant for exploiting geothermal energy by circulating water or another fluid through a non-porous geological formation at a substantial depth below the earth surface, comprising multiple heat absorbing/production holes penetrating the said formation, with a total length of several kilometers and spaced more than 50 m apart. The production holes are connected to the surface by one single combined supply and return hole in which upward and downward flow is separated by a pipe comprising an insulating material and a seal. At the given positions of the common supply and return hole manifold zone designs connect the hole to the multiple production holes. The supply and return holes and production holes are closed circuits for transport of a fluid such as water through the said formation. A method for designing and establishing the plant is also disclosed.

Abstract: A diameter expansion drill bit used to expand the diameter of a part of a prepared hole bored in a frame by grinding includes: a cutting-blade portion that has a plurality of separate cutting-blade portions; a cutting-blade holding portion that slidably holds the plurality of separate cutting-blade portions in a radial direction; and a shank portion that supports the cutting-blade holding portion. The plurality of separate cutting-blade portions is arranged in a peripheral direction and arranged over a plurality of stages in a shaft direction, and the plurality of separate cutting-blade portions of the respective stages is caused to slide by a centrifugal force resulting from rotation so as to spread to an outside in the radial direction with respect to the cutting-blade holding portion.

Abstract: A weight-on-bit self-adjusting drill bit includes a reaming bit, a WOB adjusting element, a transmission mechanism and a pilot bit and a pulsating impact generating mechanism; the pulsating impact generating mechanism includes a centralizing element, a driving element, a rotating element and a throttling element which are placed and connected successively, the centralizing element, the driving element and the rotating element are connected successively, the throttling element is in clearance fit with the rotating element, both of the centralizing element and the throttling element are respectively provided with a flow-through passage for the drilling fluid to flow through, the driving element drives the rotating element to rotate, the rotating element rotates relative to the flow-through passage on the throttling element.

Abstract: A rotary steerable system (RSS) including an upper stabilizer connected to a collar of a drill string, an articulated section connected by a flexible joint to the collar, a drill bit connected to the articulated section opposite from the flexible joint, a lower stabilizer located proximate to the flexible joint and an actuator located with the articulated section and selectively operable to tilt an axis of the drill bit and the articulated section relative to the collar. A method includes drilling with the RSS a bias phase of a drilling cycle on a demand tool face and drilling a neutral phase of the drilling cycle on a 180 degree offset tool face from the demand tool face.

Abstract: A system and method for surface steerable drilling are provided. In one example, the method includes monitoring operating parameters for drilling rig equipment and bottom hole assembly (BHA) equipment for a BHA, where the operating parameters control the drilling rig equipment and BHA equipment. The method includes receiving current inputs corresponding to performance data of the drilling rig equipment and BHA equipment during a drilling operation and determining that an amount of change between the current inputs and corresponding previously received inputs exceeds a defined threshold. The method further includes determining whether a modification to the operating parameters has occurred that would result in the amount of change exceeding the defined threshold and identifying that a problem exists in at least one of the drilling rig equipment and BA equipment if no modification has occurred to the operating parameters. The method includes performing a defined action if a problem exists.

Abstract: A method for steerable drilling is presented herein. The method includes inducing a drill string rotation modulation system to modulate a rotational speed of a drill string during each revolution of the drill string. The method also includes inducing a Measuring-While-Drilling device (MWD) to transmit repeatedly measured orientations of a Bottom Hole Assembly (BHA) between the drill string and the drill bit to the drill string rotation modulation system to steer a drill bit with a tilted toolface in a deviated drilling direction. The MWD divides each revolution of the BHA into a plurality of angular intervals, and transmits average percentages of time that the BHA rotates through the angular intervals to the drill string rotation modulation system to provide the modulation system with information about an angular orientation of the deviated drilling direction.

Abstract: A system and method for surface steerable drilling are provided. In one example, the system receives toolface information for a bottom hole assembly (BHA) and non-survey sensor information corresponding to a location of the BHA in a borehole. The system calculates an amount of incremental progress made by the BHA based on the non-survey sensor information and calculates an estimate of the location based on the toolface information and the amount of incremental progress. The system repeats the steps of receiving toolface information and non-survey sensor information and calculating an amount of incremental progress to calculate an estimate of a plurality of locations representing a path of the BHA from a first survey point towards a second sequential survey point.

Abstract: Some examples of monitoring hydrocarbon reservoirs using induced polarization effect includes inducing polarization in a subterranean zone using an induced polarization fluid. The subterranean zone includes first formations and second formations. A quantity of hydrocarbons in the first formations is greater than quantity of hydrocarbons in the second formations. The induced polarization data is obtained from the subterranean zone. A portion of the induced polarization data from the first formations is different from a portion of the induced polarization data from the second formations.

Abstract: A downhole tool may include a bridge plug releasably coupled to a casing cutting tool. The bridge plug may be set within a wellbore and the casing cutting tool may be used in a milling or perforating operation during a single downhole trip of the downhole tool. A method for using a downhole tool may include setting the bridge plug in a wellbore and performing a casing cutting operation during a same downhole trip. The casing cutting tool may be a section mill and a section milling operation may be performed before or after uncoupling the bridge plug from the section mill while downhole. The section milling operation may remove an entire portion of casing within a region of the wellbore for receiving a cement plug. The casing cutting too may be a perforation tool and perforating may be used to remove portions of casing.

Abstract: A drilling system can include a mud motor arranged in a drill string and a turbine shaft operatively coupled to a drill bit. The drilling system can also include a plurality of turbine stages axially arranged along a portion of the turbine shaft, a measure-while-drilling (MWD) tool operatively and communicably coupled to the mud motor, and a pressure sensor configured to detect pressure pulses generated by the mud motor and generate data signals corresponding to the pressure pulses. Further, the drilling system can include an electronics module communicably coupled to the pressure sensor and configured to process the data signals and thereby calculate a rotational speed of the mud motor. Furthermore, the drilling system can include a communications module communicably coupled to the electronics module and configured to transmit signals indicative of the rotational speed of the mud motor to a surface location.

Abstract: Roll reduction system for rotary steerable system. A well drilling system includes a tubular housing that attaches inline in a drill string and a bit drive shaft supported to rotate in the housing by a roll reduction system. The roll reduction system includes a first gear carried by the housing to rotate relative to the housing and coupled to rotate with the bit drive shaft, and a second gear carried by the housing to rotate relative to the housing and coupled to the first gear to rotate in an opposite direction to the first gear.

Abstract: The present invention relates to a drilling system with a multi-function drill head used in, among other applications, oil and gas drilling. The system is used to enhance the effective permeability of an oil and/or gas reservoir by drilling or cutting new structures into the reservoir. The system is capable of cutting straight bores, radius bores, or side panels, by water jets alone or in combination with lasers. In various embodiments, a device for remotely controlling the mode of the system by variations in the pressure of a drilling fluid is also provided, allowing an operator to switch between various modes (straight drilling, radius bore drilling, panel cutting, etc.) without withdrawing the drill string from the well bore.

Abstract: An example multi-bore junction assembly includes a connector body having an upper end and a lower end, the lower end providing a main bore leg receptacle and a lateral bore leg receptacle. A main bore leg is coupled to the main bore leg receptacle and extending longitudinally therefrom, and a lateral bore leg coupled to the lateral bore leg receptacle and extending longitudinally therefrom, wherein the main and lateral bore legs are round, tubular structures. At least one mechanical stiffener extends longitudinally between the connector body and a D-round connector arranged on one of the main and lateral bore legs.

Abstract: A thermally stable ultra-hard material, a cutting element incorporating such thermally stable ultra-hard material, and methods for forming the same. A thermally stable ultra-hard diamond element is combined with a second ultra-hard material volume forming an assembly. One or more surfaces of the thermally stable diamond element that face the second diamond volume are coated with a coating prior to combining the thermally stable diamond element with the second diamond volume. The assembly is sintered at high pressure and high temperature to form PCD from the second diamond volume.

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.

Abstract: A multi-layer downhole drilling tool designed for directional and horizontal drilling is disclosed. The drilling tool includes a bit body including a rotational axis extending therethrough. A plurality of primary blades are disposed on exterior portions of the bit body and a plurality of secondary blades are disposed on exterior portions of the bit body between the primary blades. The drilling tool further includes a plurality of first-layer cutting elements disposed on exterior portions of the primary blades and a plurality of second-layer cutting elements disposed on exterior portions of the secondary blades. The second-layer cutting elements are track set with the first-layer cutting elements in an opposite track set configuration.

Abstract: A down-the-hole drill hammer is provided that includes a housing, a drill bit, a piston, a roller ramp clutch and a coupler. The DHD is configured to have a bit-piston-clutch-casing torque circuit which concurrently rotates the piston and drill bit. The drill bit is positioned proximate a distal end of the housing. The piston is configured to reciprocally move within the housing along an axial direction. The piston includes a helical spline and an axial spline on a surface of the piston. The roller ramp clutch circumscribes and engages the piston. The coupler circumscribes and engages the piston and drill bit.

Abstract: A measurement while drilling (MWD) system for use in a drilling string, the MWD system comprises: a resistivity module that is configured to generate resistivity information about a resistivity of a formation that is drilled by the drilling string; a near bit sub that is configured to generate inclination information about an inclination of a drill bit of the drilling string; a MWD module; a first wireless communication module that is configured to wirelessly send the resistivity information from the resistivity module to the MWD module; a second wireless communication module that is configured to wirelessly send inclination information from the near bit sub module to the MWD module; and wherein the MWD module is configured to participate in a transmission of the inclination information and the resistivity information towards an upper surface of the formation.

Abstract: A bent sub for use in a bottom hole assembly, between the power section of a mud motor and the drill bit, which can have its bend angle altered from the surface while remaining downhole, and a method for adjusting the bend of a bent sub. A biasing mechanism includes a number of linear actuators radially positioned about the tool centerline and oriented for axial motion. The linear actuators are connected to travelling blocks, which engage the upper end of the inner race a pivoting bearing assembly. The lower end of the inner race is connected to the mud motor bearing assembly. The linear actuators and can be actuated in coordination to tilt the inner race, and hence, the mud motor bearing assembly, to various selectable angles in any radial direction for control of tool face. In an embodiment, the actuators are battery-powered motor-driven lead screws.

Abstract: An arrangement for the angular setting of a drill string includes a first tubular member, a second tubular member, a plurality of control and actuator devices that can be shortened and lengthened in a longitudinal direction through the influence of a driving device, and remote controllers by which the control and actuator devices can be set selectively and independently of each other in a radially extended or radially withdrawn condition.

Abstract: A method for making dynamic gravity toolface measurements while rotating a downhole measurement tool in a borehole is disclosed. The method includes processing magnetic field measurements and accelerometer measurements to compute a toolface offset and further processing the toolface offset in combination with a magnetic toolface to obtain the dynamic gravity toolface. Methods for correcting dynamic and static navigational sensor measurements to remove sensor biases, for example, are also disclosed.

Abstract: A bottom hole assembly for drilling a deviated wellbore is provided. The bottom hole assembly includes a drill bit and a connected rotary steerable drilling system, or RSS. The RSS includes one or more orientation sensors, a steering unit configured to direct a force through the drill bit and against a rock formation, control electronics designed to send control signals to the steering unit, and power electronics. The steering unit transforms electrical power to linear displacement and force using linear actuators acting off-center to the longitudinal axis of the drill string.

Abstract: Example systems described herein may include a housing 201 and an offsetable drive shaft 202 coupled to a drill bit 203 and at least partially disposed within the housing 201. The offset angle of the offsetable drive shaft 202 may determine an angle of the drill bit face. A motor 204 may be coupled to the housing 201 that, when activated, independently rotates the housing 201. By independently counter-rotating the housing 201 relative to a drill string during drilling operations, the angular orientation of the offsetable drive shaft 202 and drill bit 203 may remain geo-stationary with respect to the surrounding formation, without requiring that the housing 201 engage a borehole wall.

Abstract: The present disclosure provides for a sensor assembly for use in a wellbore. The sensor assembly may include a rotating sub, the rotating sub coupled to a drill string and a drive shaft, the drive shaft coupled to the rotating sub. The sensor assembly may also include a nonrotating sub where the nonrotating sub is positioned generally around the drive shaft and shaft and rotatably coupled to the drive shaft and the rotating sub. The nonrotating sub may include an outer cover. The outer cover is generally tubular. The nonrotating sub may further include a sensor collar. The sensor collar is positioned within and coupled to the outer cover. The sensor collar may be coupled to the outer cover by a drive assembly. The drive assembly may include a motor adapted to rotate the sensor collar relative to the outer cover. The nonrotating sub also includes at least one positioning sensor coupled to the sensor collar.

Abstract: Estimating and predicting wellbore tortuosity. At least some of the illustrative embodiments are methods including: receiving, by a computer system, an indication of rotational drilling time and slide drilling time for a wellpath; calculating a value indicative of tortuosity for the wellpath based on the indication of rotational drilling time and slide drilling time for the wellpath; determining, by the computer system, that the wellpath exceeds a tortuosity threshold, the determining based on the value indicative of tortuosity; and changing a drilling parameter regarding the wellpath responsive to determining that the wellpath exceeds the tortuosity threshold.

Abstract: Adjustable drill string housings are described for use in the directional drilling of wellbores, e.g. wellbores for hydrocarbon recovery wells. The adjustable drill string housings permit adjustment of a bend angle in the housings without removing the housings from a wellbore. In some exemplary embodiments, the bend angle can be adjusted by changing the internal stresses in a support member carried by the housings. In other embodiments, the bend angle may be adjusted by causing failure of sacrificial support members carried by the housings, and the failure may be caused by delivering chemicals through a chemical delivery system to the sacrificial support members. Methods of operating the adjustable drill string housings include multi-lateral drilling operations wherein the bend angle is adjusted when a casing window has been detected.

Abstract: A lateral wellbore is formed from a high side of a horizontal portion of a primary wellbore with a drill bit assembly that has a selectively extendable pilot bit. The drill bit assembly is mounted on a lower end of a drill string. A bit guide is disposed adjacent the drill bit assembly for urging the drill bit assembly in a lateral direction against the high side of the primary wellbore. Rotating the drill bit assembly while urging the drill bit assembly upward creates a groove in a subterranean formation adjacent the primary wellbore. This forms a ledge at a far end of the groove. The drill string is then drawn back from the groove, and the pilot bit is deployed. Urging the drill bit assembly forward engages the pilot bit with the ledge, providing leverage for retaining the drill bit assembly in an orientation for excavating the lateral wellbore.

Abstract: Embodiments of this invention relate to highwall mining, and more particularly to a launch vehicle adapted for use in highwall mining of downward angled seams of mineable material, such as coal. More specifically, the provided launch vehicle includes a substantially horizontally oriented control deck, a launch deck pivotally attached to the control deck, and a substantially horizontally oriented conveyor belt. A miner and at least one conveyor car are positioned on the launch deck while the launch deck is in a substantially horizontal orientation, then the launch deck is tilted upward relative to the conveyor belt to substantially match a planned entry dip angle of the seam to be mined.

Abstract: A magnetic sensor may comprise a first linear output sensing element configured to sense a first component of an external magnetic field associated with a first axis. The first linear output sensing element may provide a first output voltage corresponding to the first component of the external magnetic field. The magnetic sensor may also comprise a second linear output sending component configured to sense a second component of the external magnetic field associated with a second axis. The second axis may be substantially orthogonal to the first axis. The second linear output sensing element may provide a second output voltage corresponding to the second component of the external magnetic field. The first output voltage and the second output voltage may be provided to determine an angle, associated with the external magnetic field, corresponding to a plane including the first axis and the second axis.

Abstract: A system for determining the position and orientation of a cutter module relative to a frame of a highwall miner is provided. The cutter module is attached to the highwall miner by a string of push beams and moveable relative to the highwall miner. A reel is rotatably mounted to the highwall miner frame and configured to feed out a hose chain that supplies fluid to the cutter module. A fiber optic shape sensing system is associated with the cutter module is configured to receive strain information from the fiber bundle and compute the location of at least one position of the fiber bundle that is associated with the cutter module relative to the reference frame.

Abstract: A motor rotary steerable system having a sun gear shaft, a pair of planetary gears rotated by the sun gear shaft, an adjustable slip clutch assembly rotated by the planetary gears in an opposite direction, and an orienting device connected to the planetary gears and adjustable slip clutch assembly. The orienting device comprises a bent sub with a bent sub housing, a bearing section, a bit drive assembly, a pulse counter to count the rotating drive shaft rotations, a drilling bit locator, and a transmitting device conveying signals from the orienting device to a receiver in an opposite side of a power section. The orienting device rotates independently from a drill string and is synchronously timed to the rotation of the drill string to rotate continuously while producing both straight and curved bore path segments and increase production rates.

Abstract: A method of testing an earth formation can include incrementally opening a choke while drilling into the formation is ceased, thereby reducing pressure in a wellbore, and detecting an influx into the wellbore due to the reducing pressure in the wellbore. Another method of testing an earth formation can include drilling into the formation, with an annulus between a drill string and a wellbore being pressure isolated from atmosphere, then incrementally opening a choke while drilling is ceased, thereby reducing pressure in the wellbore, detecting an influx into the wellbore due to the reducing pressure in the wellbore, and determining approximate formation pore pressure as pressure in the wellbore when the influx is detected. Drilling fluid may or may not flow through the drill string when the influx is detected. A downhole pressure sensor can be used to verify pressure in the wellbore.

Abstract: Embodiments of this invention relate to highwall mining, and more particularly to a launch vehicle adapted for use in highwall mining of downward angled seams of mineable material, such as coal. More specifically, the provided launch vehicle includes a lower deck, an upper deck disposed above the lower deck, a launch deck pivotally attached to the upper deck, a first conveyor belt carried on the lower deck and a second conveyor belt carried on the launch deck. A conveyor car is positioned on the launch deck while the launch deck is in a substantially horizontal orientation, then the launch deck is tilted in a vertical place relative to the upper deck to substantially match a dip angle of the seam to be mined. The conveyor car is attached to a conveyor train extending into the seam as the rearmost car in the train.

Abstract: A system is provided for drilling and/or servicing a well bore using continuous lengths of coiled tubing in which a turntable assembly rotates a coiled tubing reel assembly and a counter balance system about the well bore such that the coiled tubing is rotated while in the wellbore. A coiled tubing injector may be provided on a separate turntable assembly or on the same turntable assembly as the reel assembly. A swivel support assembly may be provided for managing operation lines associated with the system.

Abstract: A self-propelled, remotely-controlled equipment deployment vehicle is configured to deliver equipment to a desired location within the horizontal portion of a deviated wellbore. The deployment vehicle includes a cargo frame, an electric motor and an active mobility assembly. The active mobility assembly is connected to the cargo frame and powered by the electric motor. The cargo frame can be configured to transport, offload and accurately position the selected cargo. Alternatively, the equipment deployment vehicle can be configured with a passive mobility assembly that allows the equipment deployment vehicle to be pushed or pulled along the horizontal section of the wellbore without power.

Abstract: A method for determining a configuration of a mechanical actuator coupled to a drilling shaft in a drilling shaft deflection device of a rotary steerable subterranean drill. The method includes receiving, at a controller, data representative of a present rotary position of a rotor of an electronically commutated deflector motor of a drilling shaft deflection device of a rotary steerable subterranean drill. The rotor is operatively coupled by a fixed-ratio transmission to a mechanical actuator comprising a drilling shaft receiver coupled about a portion of a deflectable drilling shaft of the drilling shaft deflection device. The method includes determining, at the controller, the present position of the drilling shaft receiver in dependence upon the received data representative of the present rotary position of the rotor of the electronically commutated deflector motor.

Abstract: A method of and system for directional drilling reduces the friction between the drill string and the well bore. A downhole drilling motor is connected to the surface by a drill string. The drilling motor is oriented at a selected tool face angle. The drill string is rotated at said surface location in a first direction until a first torque magnitude without changing the tool face angle. The drill string is then rotated in the opposite direction until a second torque magnitude is reached, again without changing the tool face angle. The drill string is rocked back and forth between the first and second torque magnitudes.