Abstract: A sensor element for a cutting tool has a hard portion having a first sensing surface, first and second electrodes, and first and second sets of thermocouple wires, and an electrically insulating portion. The second electrode has a second sensing surface, The hard portion comprises hard and/or super-hard material and the first and second electrodes comprise electrically conductive hard and/or super-hard material, the hard portion isolating the first sensing surface from the second sensing surface. The second electrode is attached to or forms part of an electrically conductive region of the hard portion or a region attached thereto. Electric current flows between the first and second electrodes through external material when the sensing surfaces contact the material in response to the cutting tool engaging the material. The first and second electrodes are operable to indicate any one or more of a temperature of the first and second electrodes, and conductivity between the electrodes.

Abstract: The present invention provides a brake hydraulic pressure controller capable of suppressing retention of air bubbles on a release side of a pump. The brake hydraulic pressure controller includes: a housing; a motor attached to the housing; and plural pump elements, each of which is attached to a recess formed on a side surface of the housing and driven by a motor. Each of the pump elements includes: a suction valve suctioning a brake fluid into a pump chamber; a release valve releasing the brake fluid from the pump chamber; and a channel forming member arranged on a release side of the release valve. The channel forming member includes: a spring chamber accommodating a spring for urging a valve body of the release valve in a closing direction; and a passage communicating between the spring chamber and an outer surface of the channel forming member.

Abstract: Apparatus and methods for managing power at a wellsite. An example apparatus may include a well construction equipment operable to construct a well at the wellsite, a power supply system operable to output electrical power to the well construction equipment to facilitate operation of the well construction equipment, and a control system for controlling the well construction system. The control system may be operable to store a digital drilling program and cause the well construction equipment to perform planned well construction operations based on the digital drilling program. The digital drilling program may include an equipment operational plan indicative of the planned well construction operations to be performed by the well construction equipment to construct the well, and an electrical power plan indicative of a planned electrical power demand of the well construction equipment to perform the planned well construction operations.

Abstract: A drill bit device may include a cutter housing delimited by an outermost surface and various walls forming a socket. The drill bit device may include various main cutters disposed on an outermost surface of the cutter housing. The various main cutters may be configured to move in an outward direction upon receiving a predetermined pressure. The drill bit device may include various pre-charged cutters disposed immediately behind the various main cutters inside the cutter housing. The various pre-charged cutters may be configured to move in the outward direction upon receiving the predetermined pressure. The drill bit device may include a gate that connects the cutter housing to an internal groove that may be directly connected to a port switch that may allow release of the predetermined pressure through the internal groove and into the gate.

Abstract: Methods and systems are described for drilling a wellbore. A method includes: sensing electrical resistance of an insulated conductor extending from a surface of a drill bit to a sensor inside the drill bit; calculating drill bit dimensions based on the sensed electrical resistance; and transmitting sensed electrical resistance, calculated drill bit dimensions, or both uphole to a system for controlling drilling operations.

Abstract: In some embodiments, a method includes performing a directional drilling operation using a drill string having a drilling motor and cutting structures that include a drill bit and a reamer. The method includes receiving data from one or more sensors, wherein at least one of the one or more sensors output data related to at least one performance attribute associated with load monitoring between the drill bit and the reamer. The load monitoring is distributed between the drill bit and the reamer by the drilling motor. The at least one performance attribute comprises a differentiation of distribution of at least one of a weight and a torque applied to each of the drill bit and the reamer. The method includes displaying the data related to the at least one performance attribute associated with the load monitoring in a graphical and numerical representation on a graphical user interface screen.

Abstract: Described is a system for estimating a trajectory of a borehole. The system processes signals of sensor streams obtained from an inertial sensor system. Using the set of processed signals, the system determines whether a drill is in a survey mode state or a continuous mode state, and a measured depth of the borehole is determined. A set of survey mode positioning algorithms is applied when the drill is stationary. A set of continuous mode navigation algorithms is applied when the drill is non-stationary. Using at least one Kalman filter, results of the set of survey mode positioning algorithms and the set of continuous mode navigation algorithms are combined. An estimate of a borehole trajectory and corresponding ellipse of uncertainty (EOU) is generated using the combined results.

Abstract: Performance measurement and/or malfunction detection of rotating machinery can be accomplished by using one or more strain measuring devices attached to a journal bearing housing, using the strain measuring device or devices to generate an electrically measurable output in response to a change of a force in at least part of the journal bearing housing, using a Wheatstone bridge circuit to convert the electrically measurable output to an analog electrical signal, converting the analog electrical signal to a digital electrical signal and analyzing the digital electrical signal to determine the performance of the machinery and/or existence of a malfunction in the rotating machinery.

Abstract: Apparatus, computer readable medium, and program code for identifying rock properties in real-time during drilling, are provided. An example of an embodiment of such an apparatus includes a downhole sensor subassembly connected between a drill bit and a drill string, acoustic sensors operably coupled to a downhole data interface, and a surface computer operably coupled to the downhole data interface.

Abstract: In an embodiment, a method is performed by a computer system. The method includes integrating a series of data inputs related to a well. The series of data inputs includes at least one real-time data input and at least one non-real-time data input. The method further includes based, at least in part, on a result of the integrating, facilitating a real-time display of performance data for the well. The real-time display includes information related to at least one of hydraulic surveillance and torque-and-drag surveillance.

Abstract: A method for drilling a borehole penetrating the earth includes: inputting drilling parameters as a function of depth used to drill one or more offset boreholes and rate of penetration using the drilling parameters, any drilling dysfunctions that occurred using the drilling parameters, and one or more lithologies as a function of depth for the one or more offset boreholes. The method also includes identifying those drilling parameters that correspond to a rate of penetration (ROP) that meets or exceeds an ROP threshold for each input lithology and a minimum number of drilling dysfunctions or minimum magnitude of a drilling dysfunction to provide identified drilling parameters; correlating a borehole plan comprising a borehole path and one or more assumed lithologies as a function of depth to the one or more lithologies of the one or more offset boreholes; and drilling the borehole with the drill rig using the identified drilling.

Abstract: In some examples, a system may receive log data including a depth-series of data for a sensed parameter. The system may determine a parameter value of the depth series data for individual subunits of depth corresponding to a larger unit of depth. The system may further determine a scale of graphic effects corresponding to parameter values for the depth-series data. The system may present, on a display, a visualization of the depth-series data. For instance, the visualization may include a plurality of cells arranged in a plurality of rows, with each cell corresponding to the larger unit of depth and including a plurality of subcells corresponding to the subunits of depth. Additionally, each subcell may be presented with a respective graphic effect corresponding to the parameter value determined at a corresponding depth, and the graphic effect may correspond to the parameter value on the scale of graphic effects.

Abstract: A disclosed embodiment for a drill bit arm for a rotary subterranean drill bit includes a pocket that extends radially inward from an outer surface of the drill bit arm. The pocket may include a void where work piece material has been removed. The pocket may be next to a leading edge of the drill bit arm and may extend to remove at least a portion of a trailing edge of the drill bit arm. When the drill bit arm includes a lifting surface, the pocket may be next to and follow an upward curvature of the lifting sur face. The pocket may reduce wear and tear on the drill bit arm during operation. The pocket may provide a location for placing a desired piece of equipment, such as an instrumentation element and/or a communication element.

Abstract: Techniques and systems are described to determine levels of competency of users as part of an online community and control generation of subsequent digital content to be used interaction of the online community with the users based on this determination. In one example, determination of the level of competency is based on relevance to topics of the online community. In another example, a determination is made as to whether the topic of the online community is stable before using user competency scores to control generation of subsequent digital content. In a further example, users of the online community are identified as exhibiting dormant or non-dormant behavior and used as a basis to control generation of subsequent digital content. In yet another example, user competency scores are adjusted based on a decay factor to address dormancy of users over a period of time.

Abstract: Methods of evaluating prototype cutting elements for earth-boring tools may involve generating first and second sets of virtual representations of cutting elements from first and second sets of used cutting elements. First and second sets of measures of damage corresponding to damage for each of the first and second sets set of virtual representations of cutting elements may be determined. A best-performing set of cutting elements from the first and second sets of used cutting elements according to the first and second sets of measures of damage may be identified by performing a statistical analysis.

Abstract: A method for estimating the wear of a drilling tool is disclosed. The method includes selecting a first incremental distance along a length of a formation. The method further includes determining a first characteristic of the formation along the first incremental distance. The method further includes deriving a first fractional wear factor, y1, for the drilling tool based on the first characteristic of the formation and a first operating condition of the cutting element. The method further includes calculating a first wear function, Wf1, the cutting element based on the first fractional wear factor and estimating an amount of wear of the cutting element during a drilling operation based on the first wear function.

Abstract: One implementation of the disclosure provides a computer implemented method for underbalanced drilling. The implementation may include determining an initial 2D UBD operation envelope based on a set of initial operating points for a selected TVD or time, displaying the initial 2D UBD operation envelope on a computer display, providing at least one data point representing actual data from a well, determining at least one actual UBD operation point using the at least one data point and displaying it on the computer display along with the 2D UBD operation envelope, selecting an optimization parameter, determining a set of optimized operating points based on the optimization parameter, and displaying the set of optimized operating points on the computer display along with the 2D UBD operation envelope.

Abstract: A method of planning and/or performing an energy industry operation includes estimating variable coefficient of friction (CoF) functions defining the variation of a CoF as a function of a downhole condition dependent on a selected operational parameter of an energy industry operation, the operation including deploying a downhole component configured to perform the operation, each variable CoF function associated with a different value of the selected operational parameter.

Abstract: A method for selecting a bottomhole assembly (BHA) includes inputting casing while drilling BHA parameters, wellbore parameters, and casing while drilling operating parameters, performing a dynamic simulation of a first BHA based on the casing while drilling BHA parameters, wellbore parameters, and casing while drilling operating parameters, and presenting a first set of performance data of the first BHA calculated from the dynamic simulation.

Abstract: Wear sensors are provided on a drill bit or other rotary cutting tool which is for operation in a subterranean borehole and has a plurality of separate cutters protruding from a support structure towards the material to be cut by the tool. The electrically operated sensing means are located at or coupled to a sensing point within a protrusion from the support structure. This sensing point is located within a protrusion such that attrition of at least one cutter to a partially worn state brings the protrusion into abrasive contact with the material being cut and attrition of the protrusion then exposes the sensing point to the material which is being cut by the tool and thereby brings about a detectable change, which may include damage to the sensor at the sensing point, indicative of wear. The tool includes means to communicate data from the sensing means to the surface.

Abstract: The method disclosed receives a data stream from an MWD system and determines the response of a specific energy (SE) relationship and a rate of penetration (ROP) relationship respectively to variables controllable by the operator, in order to enable operation at a lowest SE, or a highest Rate-of-Penetration (ROP) to SE ratio. The method utilizes artificial neural networks trained by MWD data to deduce a depth-of-cut and torque based on relationships manifesting between the various data points collected, and an SE equation and a predicted ROP is evaluated over a series of probable operating points. The method continuously gathers and analyzes MWD data during the drilling operation and allows an operator to manage the controllable parameters such that operation at the lowest SE or highest ROP or ROP to SE ratio can be achieved during the drilling operation.

Abstract: An earth-boring tool may include a body and at least one rotatable cutting structure assembly. The rotatable cutting structure assembly may include a leg, a rotatable cutting structure rotatably coupled to the leg, and a resistance actuator configured to impose rotational resistance on the rotatable cutting structure relative to the leg. An earth-boring to may include a plurality of rotatable cutting structure assemblies coupled to the bit body and a plurality of blades coupled to the body. A method of drilling a borehole may include rotating an earth-boring tool within the borehole, causing rotational resistance to be imposed on at least one rotatable cutting structure of the earth-boring tool, causing a blade of the earth-boring tool to be pushed into a sidewall of the borehole, and side cutting the sidewall of the borehole with the blade.

Abstract: A cutting element for an earth-boring drilling tool and its method of making are provided. The cutting element may include a substrate, a superhard layer, and a sensing element. The superhard layer may be bonded to the substrate along an interface. The superhard layer may have a working surface opposite the interface and an outer peripheral surface. The outer peripheral surface may extend between the working surface and the interface. The sensing element may comprise at least a part of the superhard layer.

Abstract: The state measuring device includes a measurement section attached to the blade portion or to a vicinity of the blade portion to measure a state of the blade portion, an AD converter attached to the cutting tool to acquire a measurement value measured by the measurement section at a predetermined sampling rate and perform AD conversion on the measurement value, a transmission section which transmits, on each acquisition of the measurement value from the AD converter, the acquired measurement value using digital wireless communication, and a monitor device provided outside the cutting tool. The monitor device includes a reception section which receives the measurement value transmitted by the transmission section, and a data management section which causes a display section to display the measurement value and causes a storage section to store the measurement value on each reception of the measurement value by the reception section.

Abstract: A method for predicting a change in lateral displacement with a change in axial displacement of a drill bit drilling in a formation rock includes: constructing a virtual representation of the drill bit and the formation rock, the drill bit having a gage pad configured to remove rock by wearing or crushing the rock during moving contact and a cutter configured to cut into the rock during moving contact with the rock; adjusting lateral penetration depth until rock reactive force equals a side force applied to the drill bit to provide an adjusted lateral penetration depth; removing formation rock to where the pad and the cutters contact the rock at the adjusted lateral penetration depth and to a selected axial displacement of the drill bit; moving the drill bit in a drilling direction to the end of the currently drilled borehole; and iterating the adjusting, the removing, and the moving.

Abstract: Methods and systems are described for improved drilling operations through the use of real-time drilling data to predict bit wear, lithology, pore pressure, a rotating friction coefficient, permeability, and cost in real-time and to adjust drilling parameters in real-time based on the predictions. The real-time lithology prediction is made by processing the real-time drilling data through a multilayer neural network. The real-time bit wear prediction is made by using the real-time drilling data to predict a bit efficiency factor and to detect changes in the bit efficiency factor over time. These predictions may be used to adjust drilling parameters in the drilling operation in real-time, subject to override by the operator. The methods and systems may also include determining various downhole hydraulics parameters and a rotary friction factor. Historical data may be used in combination with real-time data to provide expert system assistance and to identify safety concerns.

Abstract: A method for making downhole whirl measurements in a drill string includes rotating a sensor set in a borehole. The sensor set is deployed in the drill string and includes at least one cross-axial accelerometer and at least one cross-axial magnetometer. Sensor measurements, including a plurality of accelerometer measurements and a plurality of magnetometer measurements made at predetermined measurement intervals, may be obtained while drilling and used to compute a whirl magnitude.

Abstract: There is disclosed herein a method for assessing the drilling performance of a drill bit configuration used to drill at least a portion of a wellbore in a formation, comprising: determining a value of at least one drill bit performance parameter at points along the wellbore, at least including at multiple points along an interval constituting at least part of the portion drilled using the drill bit configuration; determining rock characteristics for the interval; determining the drilling performance for said drill bit configuration in the interval based on the values for the drill bit performance parameter; and assessing the effectiveness of the drill bit configuration for drilling the interval based on the determined drilling performance and the determined rock characteristics.

Abstract: A method includes performing a directional drilling operation. The method also includes receiving data from one or more sensors, wherein at least one of the one or more sensors output data related to a performance attribute of a downhole component that is from a group consisting of a downhole drilling motor and a rotary steerable tool. The downhole component comprises part of a drill string that is used to perform the directional drilling operation. The performance attribute is selected from a group consisting of rotations per unit of time of the downhole component, operating differential pressure across the downhole component and torque output of the downhole component. The method also includes displaying the data in a graphical and numerical representation on a graphical user interface screen.

Abstract: This invention relates to a method for determining a wear state of a chisel, a chisel holder, and/or a chisel holder replacement system equipped with a chisel and chisel holder. For this method to give the user qualitative and quantitative information about the wear, according to one embodiment of this invention, a position of at least one point of the chisel and/or the chisel holder is determined by a contactless measurement method and a corresponding measurement result is compared in a switching unit to a reference value stored in a memory device.

Abstract: A downhole drilling tool may include a strain gauge inside a rolling-bearing element. For example, the downhole drilling tool may include a rolling-bearing element having an inner race, an outer race, and one or more bearings disposed between the inner and outer races; and a strain gauge disposed on an interior surface of the rolling-element bearing, the strain gauge including at least one circuit formed by (1) a first substrate and a second substrate defining a gap therebetween and having first conductive fibers and second conductive fibers, respectively, extending therefrom into the gap in an intermingling configuration, (2) an electrical connection between the first and second substrates, and (3) an electrical resistance sensor arranged within the electrical connection.

Abstract: A system and method for detecting a failure of a fluid film bearing is disclosed. The system and method use one or more non-laser based strain transducers to detect changes in the frequency spectrum of the pressure of the fluid film at one or more locations in the bearing to identify failure or the risk of failure of the bearing. The system and can use metallic film, piezoelectric, and piezoresistive strain sensors to generate alarms when particular frequency bands become present in the strain frequency spectrum. The system and method can also generate strain orbit plots and perform waveform analysis of the time varying strains in the bearing housing caused by time-varying changes in the pressure of the fluid film.

Abstract: A method implemented by a processor for drilling a borehole includes: inputting drilling parameters used to drill one or more offset boreholes, rate of penetration for the one or more offset boreholes, and one or more lithologies for the one or more offset boreholes; identifying those drilling parameters that correspond to a rate of penetration (ROP) that meets or exceeds a selected ROP threshold for each input lithology; correlating a borehole plan comprising a borehole path to be drilled and one or more assumed lithologies as a function of depth to the one or more lithologies of the one or more offset boreholes; sending the identified drilling parameters to a drill rig controller for each of the assumed lithologies in the borehole plan; and drilling the borehole with the drill rig using the identified drilling parameters for each of the one or more assumed lithologies in the borehole plan.

Abstract: A technique facilitates drilling applications by providing a unique flex joint. In one embodiment, the flex joint has an adjustable bending stiffness while being much more compact than conventional flex joints. The flex joint also may be designed to de-couple bending moments from the tool joints and, in some applications, can operate as an active vibration and shock control sub by incorporating suitable sensors and a hydraulic actuator system. The design also enables incorporation of other features, such as electrical insulation features disposed above and/or below the flex joint. In some applications, the flex joint also may have an electrical feed through.

Abstract: A cutting element for an earth-boring tool includes a body having a longitudinal axis, a generally planar volume of hard material carried by the body, and a sensor affixed to the body. The sensor may be configured to sense at least one of stress and strain. An earth-boring tool includes a cutting element disposed at least partially within a pocket of a body. Methods of forming cutting elements comprise securing a generally planar volume of hard material to a body, attaching a sensor to the body, and configuring the sensor. Methods of forming earth-boring tools comprise forming a cutting element and securing the cutting element within a recess in a body of the earth-boring tool. Methods of forming wellbores comprise rotating an earth-boring tool comprising a cutting element and measuring at least one of stress and strain.

Abstract: A method for analyzing a wellbore drilling operation includes acquiring sonic log data, gamma ray log data, and rate of penetration (ROP) data. The sonic log data, the gamma ray log data, and the ROP data are associated with depth intervals of a wellbore. The method further includes determining unconfined compressive strength (UCS) of a rock formation associated with the wellbore using well log data and drilling data. The well log data is limited to the sonic log data and the gamma ray log data, and the drilling data is limited to the ROP data.

Abstract: A method and apparatus for providing a reliable signal to the operator while drilling when a bit or tool becomes worn or damaged to a predetermined extent. The approach, in an exemplary embodiment, is to integrate one or more wear tracer elements into one or more parts of a drill bit or downhole tool that do not engage the earthen formation until the predetermined wear or damage occurs. At that time wear tracer elements are released upon wearing of the bit body, cutters, inserts, nozzles, or other components that include the wear tracer elements and enter the drill fluid. The presence of wear tracer elements in drilling fluid can be detected at the surface directly, or indirectly as a result of, for example, one or more reactions between the wear tracer elements and the mud, formation, or other subterranean elements, which yield some compound that may then be detected.

Abstract: Teachings of the disclosure are directed to a reamer and/or bit interaction model system and method. The method may include receiving performance data regarding a cutting structure, and calculating a characteristic curve, using the performance data. The characteristic curve may be weight-based and/or torque-based. The method may also include storing the characteristic curve. In particular embodiments, the characteristic curve may include either weight on cutting structure or torque on the cutting structure, as a function of the rate of penetration.

Abstract: A method of drilling a subterranean bore hole comprising a) pumping a drilling fluid down a drill string, the drill string having a drill bit at an end thereof, b) rotating the drill string about its longitudinal axis to that the bit forms bore hole in the ground, the method further comprising the steps of: c) changing the rate of pumping of the drilling fluid into the drill string in response to a change in the speed of rotation of the drill string, and/or changing the speed of rotation of the drill string in response to a change in the rate of pumping of the drilling fluid into the drill string.

Abstract: A device for measuring resistance to drilling in a material being investigated, especially wood, with a drilling appliance (1) driving a drill bit (2) into the material and a measuring device for measuring the mechanical resistance to the drill bit (2) upon its penetration into the material, is configured and modified in regard to a secure measurement even in tight space conditions around the material being investigated such that the drilling appliance (1) is coordinated with several U-shaped guide elements (4) which can move along a drilling axis (3) with legs (5, 6) of different length and a base region (7) joining the two legs (5, 6), and in each longer leg (6) a passage (8) is formed for the drill bit (2) in order to guide the drill bit (2).

Abstract: A drill bit includes a plurality of blades. The blades provide a plurality of cutting elements or teeth arranged on a leading face of the blade. At least one temperature sensor is provided adjacent at least one of the teeth of at least one blade to sense a local temperature of the blade adjacent that tooth. Multiple temperature sensors may be provided adjacent different teeth of a blade or adjacent the teeth of at least two blades, or adjacent multiple teeth of multiple blades. Another temperature sensing element may be provided on a proximal portion of the blade distant from the cutting elements or on the shank of the bit to provide a reference temperature for the drill bit or for the blade. Information obtained by the temperature sensing elements is used to provide information regarding at least one of the drill bit, the drilling environment and the formation.

Abstract: An erosion monitoring system is disclosed for use with a machine. The erosion monitoring system may have an ultrasonic sensor embedded within a replaceable cutting edge of a ground engaging tool connectable to the machine. The erosion monitoring system may also have a wireless communication element associated with the ultrasonic sensor, and a controller mountable onboard the machine in communication with the ultrasonic sensor via the wireless communication element. The controller may be configured to monitor a wear rate of the cutting edge based on signals from the ultrasonic sensor.

Abstract: Earth-boring tools include one or more cutting elements having at least one grading feature positioned a known distance from an initial working surface of the cutting element. Methods of grading cutting element loss on earth-boring tools include comparing locations of wear surfaces on cutting elements to locations of one or more grading features in or on the cutting elements. In some embodiments, a cutting element may comprise an insert having a generally cylindrical body, a substantially planar cutting face surface, a substantially arcuate side surface, and at least one grading feature. In additional embodiments, a cutting element may comprise a tooth having one or more grading features.

Abstract: Described herein is a wear indicator (100) for use in a drill bit or a core head. The wear indicator (100) comprises an elongate element that forms part of the drill bit. The elongate element has a plurality of numbers (110, 120, 130, 140, 150, 160, 170, 180) formed along its length, each number (110, 120, 130, 140, 150, 160, 170, 180) being formed as a void and corresponds to a level of wear in accordance with the IADC dull grading system. As the drill becomes worn, the wear indicator (100) wears at the same rate to reveal one of the numbers (110, 120, 130, 140, 150, 160, 170, 180). The numbers range from “1” to “8” where the number “1” illustrates the least wear and the number “8” indicates the most wear. When unworn, none of the numbers are visible.

Abstract: A method for determining wear of a drill bit is disclosed. The method includes drilling a first hole in a worksite based on a hole pattern having a plurality of planned holes and determining an energy required to drill the first hole. The method also includes drilling a second hole in the worksite and determining an energy required to drill the second hole. The method further includes determining a wear of the drill bit using the determined energy required to drill the first hole and the determined energy required to drill the second hole.

Abstract: An earth-boring tool includes a cutting element comprising a hard material and at least one of a signal generator configured to provide an electromagnetic or acoustic signal to an interface between a surface of the hard material and a surface of a subterranean formation, and a sensor configured to receive an electromagnetic or acoustic signal from the interface. A method of forming a wellbore includes rotating the earth-boring tool within a wellbore and cutting formation material with a cutting element, transmitting a signal through the cutting element to an interface between the cutting element and the formation material, and measuring a response received at a sensor. A cutting element includes a transmitter oriented and configured to dispense a signal to an interface between the cutting surface and a surface of a formation and a sensor oriented and configured to measure a signal from the interface.

Abstract: The invention relates to a method for determining the wear of a force-loaded linkage of an earthwork device, wherein the instantaneous load on the linkage is measured during operation of the earthwork device and used to perform a calculation of the service life.

Abstract: A system, method and apparatus for determining wear on a component of a tool is disclosed. An oscillating member receives a particle freed from the component as a result of the wear on the component. A measuring device measures a change in a parameter of the oscillating member resulting from receiving the particle. A processor determines the wear on the component from the change in the parameter. In one embodiment, the component may include a component of a downhole tool.

Abstract: This invention relates to a system for determining a wear state of a chisel, a chisel holder, and/or a chisel holder replacement system equipped with a chisel and chisel holder. A sensor is arranged to inspect a milling tool of a milling machine. The sensor is configured to detect a signal corresponding to a position value of at least one point on the milling tool.

Abstract: An apparatus for forming a wellbore in a formation may include a bit body and a sensor in the bit body. The sensor may include at least one cutting element and may be configured to generate information relating to a parameter of interest when the drill bit engages a wellbore surface.