Abstract: The disclosure provides for a bottom hole assembly that comprises a stator solenoid winding transmitter assembly operable to generate a magnetic field. The stator solenoid winding transmitter assembly comprises a coil comprising a plurality of windings and a sleeve, wherein the coil is disposed within the sleeve. The bottom hole assembly further comprises a solenoid control assembly disposed adjacent to the stator solenoid winding transmitter assembly, wherein the solenoid control assembly is communicatively coupled to a controller and electrically connected to the coil and a mud motor comprising a rotor and a stator, wherein the stator solenoid winding transmitter assembly is disposed around the mud motor.

Abstract: A method, drill string, bottomhole assembly, drill bit, and insert are for extending a borehole for a relief well in a subsurface. The rotary drill string is provided in the borehole and includes a bottomhole assembly. The bottomhole assembly includes a drill bit. Current is provided into the subsurface using at least one electrode on the drill string, thereby generating current in a casing of a mother well located a distance away from the borehole of the relief well. At least one component of a magnetic field associated with the current generated in the casing is detected using at least one sensor disposed on the drill string. Data is obtained from the sensor for determining either or both the proximity and direction to the mother well. The drill string is advanced into the subsurface based upon the obtained data to extend the borehole.

Abstract: Measurement of the inclination and azimuthal direction of a borehole extending beneath an obstacle, such as a body of water, which utilizes magnetic and gravity sensors at the drill bit of a borehole being drilled. Embodiments of the present invention determine and remove remanent field components and the effects of ferromagnetic permeability prior to and during drilling of the borehole.

Abstract: The invention relates to a method (100) for determining a hydrocarbon-water contact position in a hydrocarbon reservoir, said method comprising the steps of:—Providing (110) at least two reservoir fluid samples collected, from connected hydrocarbon reservoir(s), at different known sampling depth values, —Measuring (120) abundance of at least one isotope of noble gas from each of the at least two reservoir fluid samples, and—Calculating (130) the hydrocarbon-water contact position in the hydrocarbon reservoir from the measured abundances and the known sampling depth values of the at least two reservoir fluid samples.

Abstract: A coring tool includes an electronics section that includes a material that is buoyant in a wellbore fluid, a coring section coupled to the electronics section and including a sidewall coring unit operable to penetrate an inner wall of a wellbore and thereby obtain a core sample, and a stabilizer arm assembly operable to laterally extend a stabilizer arm into engagement with the inner wall of the wellbore. A weight section is operatively coupled to the electronics and coring sections and exhibits a weight that overcomes buoyancy forces generated by the buoyant material in the wellbore fluid, and a release mechanism releasably attaches the weight section to the electronics and coring sections. Activating the release mechanism detaches the weight section, and thereby allows the electronics and coring sections to float in the wellbore fluid and ascend the wellbore.

Abstract: A method of controlling a pumping sequence of a fracturing fleet at a wellsite. A managing application executing on a computer in the control van can retrieve the pumping sequence from a local or remote storage computer. The managing application can establish an electronic communication link to receive sensor data from a plurality of fracturing units. The managing application can control the plurality of fracturing units with a stage script with multiple sequential instructions for a pumping stage of a pumping sequence while receiving one or more periodic data sets from the plurality of fracturing units wherein the data sets are indicative of the current state of the pumping stage of the pumping sequence.

Abstract: Some systems and methods for determining depths of subterranean formation layer tops while drilling through the subterranean formation include a drill bit, a drill rig, a microphone, a depth sensor, and a processor. While drilling the through the subterranean formation, the processor receives a measured sound from the microphone and a measured drill bit depth from the depth sensor, normalizes the measured sound across all measured drill bit depths, determines frequency information of the normalized sound for each depth of the plurality of depths, determines frequency spectrums of the normalized sound for one or more depths of the plurality of depths, transforms the frequency spectrums into a depth spectrum, and determines the depths of subterranean formation layer tops based on the depth spectrum.

Abstract: The present disclosure provides an inductive magnetic sensor, which includes a signal pre-amplifying measurement circuit, a feedback loop, a magnetic core and coil group, a low-noise autozero processing circuit, and an output protection module. The magnetic core and coil group is electrically connected between the signal pre-amplifying measurement circuit and the feedback loop, the signal pre-amplifying measurement circuit comprises the low-noise autozero processing circuit, and the feedback loop and the low-noise autozero processing circuit are electrically connected to the output protection module respectively. By introducing the resonant notch filter, it may extend the passband to the low frequency, and extend the low-frequency characteristic of the magnetic sensor, to obtain a better low-frequency magnetic sensor. The present disclosure further provides an electromagnetic prospecting equipment.

Abstract: An apparatus for use in a wellbore includes a non-rotating section disposed along the drill string. The non-rotating section has a bore and at least one biasing member engaging an adjacent wall. A rotating section is disposed in the bore of the non-rotating section and a bearing is positioned between the rotating section and the non-rotating section. The apparatus also includes a relative rotation sensor that generates signals representative of a rotation of the rotating section relative to the non-rotating section, an orientation sensor that generates signals representative of an orientation of the non-rotating section relative to a selected frame of reference, and a controller in signal communication with the at least one relative rotation sensor and the at least one orientation sensor.

Abstract: A transmitter is powered by a regulated battery voltage and is installable in one of a plurality of different housings, each housing is characterized by a different design and each can form part of an inground tool for performing an inground operation in which a drill string extends from a drill rig to the inground tool. An antenna driver drives an antenna based on the regulated voltage to emanate an electromagnetic signal for remote reception. A controller limits power consumption from the regulated voltage so as not to exceed a power consumption threshold, irrespective of installation of the transmitter in any one of the housings when the transmitter would otherwise exhibit a different power consumption for each housing design. A corresponding method is described. Features relating to power consumption threshold modification based on temperature as well as mechanical shock and vibration are described.

Abstract: Disclosed herein are methods for performing downhole operations. The methods include determining, at the earth surface, a first depth value of a downhole component in a borehole, transmitting to the downhole component in the borehole a first signal indicating the first depth value, changing a depth of the downhole component in the borehole, determining, at the earth surface, a second depth value of the downhole component in the borehole, transmitting, to the downhole component in the borehole, a second signal indicating the second depth value, and updating a downhole operation performed by the downhole component based on at least one of the first depth value and the second depth value.

Abstract: Systems, devices, and methods for measuring toolface angles on a drilling rig and calculating a slide stability score are provided. The slide stability score may represent an amount of consistency of the toolface angle of a bottom hole assembly (BHA) of the drilling rig during a slide drilling operation. Calculating the slide stability score may include measuring one or more toolface angles of the BHA during the slide drilling operation, comparing the measured one or more toolface angles, and calculating the consistency of the toolface angle using the measured one or more toolface angles.

Abstract: A downhole tool operable to connect within a downhole tool string. The downhole tool may include a first sub, a second sub, and a movable joint movably connecting the first sub and the second sub to facilitate relative angular movement between the first sub and the second sub. The downhole tool may be operable to connect together a first portion of the tool string and a second portion of the tool string and facilitate relative angular movement between the first portion of the tool string and the second portion of the tool string when the downhole tool is connected within the tool string.

Abstract: A system includes a quick access casing coupling, a drill string, a whipstock, a lateral entry locator, a logging tool, and a drill bit. The quick access casing coupling has an inner profile and is installed on a tubular body. The whipstock has a whip face and is removably connected to the drill string. The lateral entry locator is connected to the whipstock and includes an outer surface designed to engage with the inner profile of the quick access casing coupling. Engagement of the outer surface and the inner profile orients the whip face towards a planned location of a lateral. The drill bit is connected to the drill string and is configured to kick off from the whip face into a portion of the circumferential wall adjacent to the planned location to drill the lateral.

Abstract: Wellbore ranging methods and systems for active electromagnetic ranging between a pair of conductive tubulars. Methods may include generating a depth-dependent current on one conductive tubular of the pair and a return current on another and thereby causing an injection current to flow into the earth formation by electrically exciting a first conductive tubular of the pair at a first wellhead and a second of the pair at a second wellhead, wherein the return current on the one results from the injection current on the other and is received from the earth formation; making electromagnetic measurements indicative of at least one electromagnetic field resulting from the depth-dependent current in the earth formation; and estimating a relative position of the first conductive tubular with respect to the second tubular using the electromagnetic measurements.

Abstract: A rotary cutting tool for use in a wellbore has an instrumented cutter fitted into a cavity in the tool body. The instrumented cutter body has an outer end portion exposed at the open end of a cavity and is connected to the tool body through at least one connecting section having a smaller cross-section and greater compliance than the outer end portion. The outer end portion and the connecting section are slightly movable within the cavity but the cavity surrounds at least part of the outer end portion sufficiently closely to limit transverse movement to elastic strain of the compliant connecting portion. One or more sensors, which may be strain gauges, are used to measure force on the outer end portion in a plurality of directions transverse to the cavity and causing elastic strain of the at least one connecting section.

Abstract: This application relates to a hard-shell inclusion strain gauge for 3D stress in surrounding rockmass of underground engineering. The hard-shell inclusion strain gauge comprises an elastic cylinder and at least three sets of strain rosettes, wherein the elastic cylinder is installed in a borehole of underground engineering, and at least three sets of strain rosettes are equidistant along the circumference on the inner wall of the elastic cylinder. It can accurately measure strain values and variables of each strain rosette through data collection and transmission module, and calculate 3D stress in surrounding rock of underground engineering. It can obtain dynamic long-term monitoring of 3D stress evolution in complex environments of underground engineering, truly reflecting the real-time state, the spatial distribution, and the evolution of 3D stress in rockmass, and provide in-situ basic data for engineering disaster warning and control.

Abstract: A planning tool plans movement of a boring tool for an underground drilling operation. The planning tool includes one or more wheels for rolling on a surface of the ground along a path responsive to movement by an operator to characterize the surface contour and to generate guidance for the boring tool to reach a target position. Planning can additionally be based on waypoints. The planning tool can be rolled unidirectionally or bidirectionally to characterize the surface contour. Bidirectional movement cancels accelerometer fixed bias. Path stitching is used to plan around obstacles. The planning tool can facilitate tracker placement. The planning tool can collect noise information for frequency selection purposes. A described technique maximizes linear drilling in an underground plan. Compensation and/or warnings are provided for unsteady, fast and slow movement of the planning tool while measuring the surface contour.

Abstract: Systems and methods for performing slide drilling and for determining operational parameters to be utilized during slide drilling. An example method includes commencing operation of a processing device, whereby the processing device determines a reference rotational distance of a top drive to be utilized during slide drilling. The processing device outputs a control command to the top drive to cause the top drive to rotate a drill string. The processing device also determines the reference rotational distance based on rotational distance measurements indicative of rotational distance achieved by the top drive and torque measurements indicative of torque applied to the drill string by the top drive.

Abstract: A new horizontal directional drilling (HDD) bit comprising a bit body is provided with illustrated embodiments including a flat bit design and a cobble bit design. Cutter teeth may be cut (e.g. formed or machined) into the base steel material of the bit body. Additionally, a broken edge profile may be generated to avoid sharp corners for better receipt of hard facing material such as laser clad beads that may be applied in higher wear regions.

Abstract: A directional tool and method of surveying a wellbore with the directional tool in a borehole string. A first sensor of the directional tool is disposed in a non-homogeneous ambient magnetic field. A first applied magnetic field is applied to the first sensor. A first measurement is obtained at the first sensor while the first sensor is disposed within the non-homogeneous ambient magnetic field and with the first applied magnetic field applied. A second applied magnetic field is applied to the first sensor. A second measurement is obtained at the first sensor while the first sensor is disposed within the non-homogeneous ambient magnetic field and with the second applied magnetic field applied. The directional tool is calibrated based on the first and second measurement. A downhole survey measurement is obtained with the calibrated directional tool in the wellbore.

Abstract: A disclosed downhole drilling system may include a drill bit electrically coupled to a pulse-generating circuit to generate electrical arcs between first and second electrodes during pulsed drilling operations, a sensor to record responses to electromagnetic or acoustic waves produced by the electrical arcs, and a sensor analysis system. The electrical arcs occur at different azimuthal locations between the electrodes. The sensor analysis system may obtain a plurality of measurements representing first responses recorded by the sensor during a pulsed drilling operation, generate a model of a source of the electrical arcs based on the measurements, obtain an additional measurement representing a second response recorded by the sensor during the operation, and determine a characteristic of a formation near the drill bit using an inversion based on the model and the additional measurement. The determined characteristic may be used to determine dip parameters or construct images of the formation.

Abstract: A plug assembly for a cementing operation in a well includes a bottom wiper plug configured to land in or near the toe of a well and receive a cement slurry therethrough, a top wiper plug releasably coupled to the bottom wiper plug and configured to land on the bottom wiper plug after the cement slurry is received through the bottom wiper plug, a bridge plug coupled to the top wiper plug and configured to move toward the bottom wiper plug with the top wiper plug after the bottom wiper plug is landed in or near the toe of the well, and a sensor sub coupled to the bridge plug and configured to detect a gate in the well.

Abstract: An apparatus for, and method of identifying a potential problem with a bottom hole assembly (“BHA”) combination that is used in a drilling operation. The method includes monitoring, using a sensor, an actual drilling parameter; comparing the actual drilling parameter to a target drilling parameter to determine a deviation; creating, in response to the deviation and by a feedback control loop system that references an electronic database, instructions thereby omitting variability associated with human input in creating the instructions; monitoring, using the controller, a change in the deviation; determining that the change in the deviation is below a threshold; and determining, based on the change in the deviation being below the threshold, that there is a potential problem with the BHA combination. The BHA combination comprises a mud motor and a drill bit.

Abstract: A system for tracking a below-ground transmitter from an aerial receiver. The receiver has an antenna assembly, a processor, and a propulsion system. The antenna assembly detects the magnetic field from an underground transmitter and generates an antenna signal. The processor is programmed to receive the antenna signal and generate a command signal, which moves the receiver to a position above the transmitter. Once in the desired position, which may be a reference plane at a fixed elevation, the antenna assembly measures the magnetic field to determine the location of the drill bit along borepath.

Abstract: A rotary tool for operation within an underground borehole or within tubing in a borehole has a tool body and at least one sensor-containing unit attached to the tool body and positioned to contact the conduit wall. The sensor-containing unit includes an exterior portion to contact the borehole or tubing wall and one or more sensors is located in a cavity between the exterior portion and the tool body. The sensor-containing unit may be formed from the exterior portion, an attachment portion for attachment to the tool body, and one or more connecting portions extending between the attachment and exterior portions, with the sensor-containing cavity between the attachment and exterior portions. Possible rotary tools include drill bits, reamers, mills, stabilizers, and rotary steerable systems.

Abstract: A wireless data telemetry system for use in a drilling system can include a drill head wireless transmitter and at least one data link transceiver. The drill head wireless transmitter can be in a drill head of the drilling system, the drill head wireless transmitter configured to generate and transmit one or more data signals associated with a drilling process. The at least one data link transceiver can be wirelessly coupled to at least one of the drill head wireless transmitter or another data link transceiver, with the drill head wireless transmitter and the at least one data link transceiver configured to be physically coupled within a drill string and spaced apart from one another. The drill head wireless transmitter and the at least one data link transceiver together configured to wirelessly communicate the one or more data signals beyond a transmission range of the drill head wireless transmitter.

Abstract: A method for steering a downhole tool includes receiving an electromagnetic (EM) signal from the downhole tool. The downhole tool is in a wellbore in a formation. The EM signal comprises a gap voltage and a gap current that are measured across a gap sub in the downhole tool. The method also includes determining a gap impedance based at least partially upon the gap voltage and the gap current. The method also includes determining a first formation resistivity at a first location in the wellbore based at least partially upon the gap impedance. The method also includes steering the downhole tool based at least partially upon the first formation resistivity.

Abstract: A vibration detection apparatus applied to a nuclear magnetic resonance while drilling instrument, including a vibration table. The vibration table is configured to horizontally clamp the nuclear magnetic resonance while drilling instrument and further includes a graduated barrel that contains a detection liquid; the graduated barrel is configured to be suspended at the upper side of the vibration table and be spaced apart from the nuclear magnetic resonance while drilling instrument; when the vibration table performs vibration, the graduated barrel keeps stationary, and the nuclear magnetic resonance while drilling instrument preforms high-pressure emission and measurement by means of the graduated barrel. Therefore, the nuclear magnetic resonance while drilling instrument can obtain the echo signal of the graduated barrel during vibration, thereby more accurately detecting the performance thereof and shortening a detection time length.

Abstract: Methods and systems for determining caving volume estimations based on logging data and geomechanical models are provided. For example, a system can receive image log data measured during a drilling operation in a wellbore. The system can receive an identification of a breakout in a subterranean formation around the wellbore. The system can determine, using the image log data, a breakout angular width for the breakout. The system can determine a breakout depth for the breakout. The system can determine a caving volume based on the breakout depth and the breakout angular width substantially contemporaneously with the drilling operation. The system can output the caving volume estimation for use in substantially contemporaneously adjusting a drilling parameter for the drilling operation.

Abstract: A method of controlling a pumping sequence of a fracturing fleet at a wellsite. A managing application executing on a computer in the control van can retrieve the pumping sequence from a local or remote storage computer. The managing application can establish an electronic communication link to receive sensor data from a plurality of fracturing units. The managing application can control the plurality of fracturing units with a stage script with multiple sequential instructions for a pumping stage of a pumping sequence while receiving one or more periodic data sets from the plurality of fracturing units wherein the data sets are indicative of the current state of the pumping stage of the pumping sequence.

Abstract: A system, method and a computing architecture, for well path planning that can be used in directional drilling and provides for optimal path planning in directional drilling operations. One method includes receiving information about the planned drilling path, target-zone location and planned path changes, and real-time drill-bit location measurements. The method estimates the current state of the geometric location of the drill-bit in the earth during directional drilling operations, and the characteristics of the bottom-hole assembly before and after receiving drill bit location measurements. Such a method preferably determines a time optimal path, such as a Dubins path between the current state of the drill-bit location and the user-provided target-zone.

Abstract: A ranging system and method uses three-dimensional (“3D”) magnetic field measurements to correct ranging distance and direction. Ghost well interference may also be decoupled from the ranging solutions using 3D magnetic gradient field measurements.

Abstract: A method can include training a deep neural network to generate a trained deep neural network where the trained deep neural network represents functions of a nonlinear Kalman filter that represents a dynamic system of equipment and environment via an internal state vector of the dynamic system; generating a base internal state vector, that corresponds to a pre-defined operational procedure, using the trained deep neural network; receiving operation data from the equipment responsive to operation in the environment; generating an internal state vector using the operation data and the trained deep neural network; and comparing at least the internal state vector to at least the base internal state vector.

Abstract: A rotary tool for operation within an underground wellbore or within tubing in a wellbore has at least one force-sensitive element attached to the tool body and positioned to contact the conduit wall, wherein the force-sensitive element comprises an outer portion to contact the wellbore or tubing wall, at least one connecting portion which is more compliant than the outer portion and through which the outer portion is connected to the tool body, and at least one sensor responsive to force on the outer portion transmitted through the force-sensitive element to the tool body. The sensors may resolve forces into measurable forces on three axes. Possible rotary tools include drill bit, reamer, mill, stabilizer and rotary steerable system for a drill bit.

Abstract: The present invention relates to methods of inserting and removing tools and/or robots into/from inside subsea oil wells. In this scenario, the present invention provides a system for insertion and removal of a device (30) in a subsea oil well (20), said system comprising (i) a WCT assembly (10) comprising a removable protective cap (40) and (ii) a WCT tool (50) connected to a receptacle (60) comprising within it the device (30), wherein the WCT tool (50) is suitable for being inserted in the place where the protective cap (40) is coupled, wherein at least one of receptacle (60) and WCT tool (50) is able to be opened or closed, releasing the device (30) into the subsea oil well (20) or retaining same inside the receptacle (60). The invention further provides methods of inserting and removing a device (30) into/from a subsea oil well (20).

Abstract: An automated slide drilling system (ASDS) may be used with a drilling rig system to control slide drilling. The ASDS may autonomously control slide drilling without user input during the slide drilling. The ASDS may further support a transition from rotary drilling to slide drilling to rotary drilling without user input during the transitions. The ASDS may also support user input and user notifications for various steps to enable manual or semi-manual control of slide drilling by a driller or an operator.

Abstract: A system (10) and method (50) of enabling the acquisition of borehole survey data and core orientation data in a single instrument trip in a core drill (12) having a drill string (18) and an inner core barrel assembly (16). The method uses a borehole survey tool 14 that is arranged to at least log its position in three-dimensional space. The borehole survey tool (14) is run down the drill string (12) in which the inner core barrel assembly (16) is installed. The inner core barrel assembly (16) is arranged to either provide or facilitate detection of an indication of tool face of a core sample (24) held in the inner core barrel assembly (16). The indication of tool face is then transferred mechanically or electronically to the visiting borehole survey tool (14).

Abstract: An apparatus and methods for detecting drill pipe connection joints via magnetic flux leakage. An apparatus may include a magnet operable to magnetize a portion of a drill string extending out of a wellbore that extends into a subterranean formation below a drill rig and a sensor operable to facilitate magnetic flux measurements indicative of an amount of magnetic flux that leaked from the drill string along the magnetized portion of the drill string. The apparatus may further comprise a processing device having a processor and a memory storing a computer program code, wherein the processing device is operable to receive the magnetic flux measurements and detect a connection joint between adjacent drill pipes of the drill string based on the magnetic flux measurements.

Abstract: Systems and methods of the present disclosure relate to protecting a control line as it passes through a junction in a downhole environment. A retractable transition joint (RTJ) comprises at least two members. A first member is operable to retract into a second member. A tubular extends through the first and second members. The tubular comprises a distal end that is removably attached to a distal end of the second member. The first and second members are operable to receive the control line.

Abstract: Apparatus, systems, and methods are disclosed for tracking movement over the ground or other surfaces using two or more spaced apart cameras and an associated processing element to detect ground features in images from the cameras and determine tracking parameters based on the position of the detected ground features in the images.

Abstract: A system for tracking and steering a downhole tool using an augmented reality device. A tracker tracks the location of a downhole tool as it moves underground and transmits data to the device, while one or more sensors measure a position and orientation of the device. The device analyzes the data received from the tracker and the sensors and generates a virtual image of the downhole tool. The virtual image is displayed on the device at its detected location relative to the ground surface and relative to the position of the device. The position of the displayed virtual image is modified in response to updated information from the tracker or the sensors. Virtual images representing various parameters of the drilling operation are also displayed on the device in juxtaposition with the virtual image of the downhole tool.

Abstract: An apparatus and method are used in conjunction with a system for performing horizontal directional drilling, the system including a drill string extending from a drill rig to a boring tool such that the boring tool is steerable based on a roll orientation. The system also includes an arrangement for generating steering commands for guiding the boring tool to a target position. Responsive at least in part to the steering commands, a display is configured to selectively indicate each of a rotate command, a push command and a spin command. A steering indicator is described which indicates a current roll orientation of the boring tool. A 3-D grid can be animated and centered on either a steering or target indicator. Rounding of a steering command ratio can limit the display of target roll orientations to only those that a given boring tool transmitter is capable of sensing and indicating.

Abstract: A downhole drilling tool comprises an earth-boring drill bit including a bit body and a shank coupled to the bit body. The drill bit includes a motion puck positioned in a cavity of the shank, wherein the motion puck includes a motion sensor to detect movement indicating a force applied to the earth-boring drill bit during a drilling operation. The drill bit includes a strain puck positioned in the cavity of the shank, wherein the strain puck includes a strain gauge to measure the force applied to the earth-boring drill bit during the drilling operation. The drill bit includes a plurality of blades disposed on exterior portions of the bit body, each blade having respective cutting elements disposed thereon.

Abstract: A system for drilling a bore in a bone (7) and measuring a depth of the bore during surgery, said system comprising: a drill (5) comprising a drill chuck (6) for holding a drill bit; a drill bit (3) mounted in the drill chuck; at least one sensor (11,12) arranged to produce signals for determining the depth of the bore, preferably comprising a strain gauge (11) arranged to produce a signal representing a force exerted on the system during drilling, and a distance sensor (12) arranged to produce a signal representing a distance between a reference point on the system and the bone surface during drilling; first communication means (19) arranged to communicate said signals to electronic processing means; electronic processing means (16) arranged to receive said signals from said first communication means and to determine a depth of a bore from said signals; second communication means (13a) arranged to communicate said determined depth to output means; output means (2) for outputting information about the determi

Abstract: A high efficiency smart steering drilling system includes a smart push force application tool and a centralizer. The centralizer is at an end close to a drill bit. The smart push force application tool is at an end away from the drill bit and includes a push force application wing rib having a telescoping function. The smart push force application tool is capable of automatically measuring an inclination angle and an azimuth angle and comparing the inclination angle and the azimuth angle with design values so as to control the push force application wing rib to output a push force in a telescopic manner based on a difference between the measured values and the design values and applying a push force to the drill bit. The drilling system achieves combined deflection under double action of drill bit push and pointing, greatly improving the deflection capability.

Abstract: A drilling device for surveying front rock-mass intactness of a tunnel face for a tunnel constructed by a TBM and a method using the same are provided. The drilling device includes a drilling assembly, a drill-attitude control assembly, a data monitoring assembly and a TBM-platform fixing seat. The drilling assembly is connected to a TBM hydraulic system to obtain power, to drill the rock mass by an alloy bit through rotation and translation thereof. The drill-attitude control assembly controls an angle, a direction and a position of a drill rod and maintains drilling accuracy and stability. The data monitoring assembly acquires and stores a drilling dynamic-response signal by a high-accuracy sensor and a data recorder, to analyze an intactness characteristic of the rock mass. The TBM-platform fixing seat mounts the drilling device on the TBM.

Abstract: Embodiments directed to an apparatus and system of monitoring an instrument with a working tool engaged thereby. In one aspect, an embodiment including a working tool with a machine readable indicium indicative of a working tool attribute. The working tool may be receivable by an instrument such that a corresponding machine readable indicia reader receives an identifier of the working tool. Various attributes and conditions in relation to the instrument and working tool received thereby may be identified to facilitate the provisioning of a response to prompt various corrective actions. In this regard, a controller may provide an output in response to a received identifier of a working tool and an identified instrument operating condition.

Abstract: A method for wellbore construction management includes measuring at least one drilling operating parameter during drilling of a wellbore. At least one well state parameter is calculated from the measured drilling operating parameter. A difference between the calculated well state parameter and a predetermined value of the well state parameter is determined. When the difference exceeds a selected threshold a modified well plan is calculated comprising at least one drilling task to enable construction of at least part of the wellbore to conform to the modified well plan. The at least one drilling task is displayed to a user.

Abstract: In some examples, a method performed by a drilling rig control center, includes receiving raw data for a first time segment, the raw data related to a drilling operation. In addition, the method includes deriving first drilling state measurements based on the raw data of the first time segment. Further, the method includes deriving first formation state measurements based on the raw data of the first time segment. The method also includes correlating the first derived drilling and formation state measurements of the first time segment with a second derived drilling and formation state measurements of a second time segment. Still further, the method includes generating a control response based on the correlation.