Abstract: In one aspect, a method of determining a corrected weight-on-bit is provided, which method, in one embodiment, may include: drilling a wellbore with the drill bit; determining a weight-on-bit while drilling the wellbore; determining a pressure differential across an effective area of the drill bit while drilling the wellbore; and determining the corrected weight-on-bit from the determined weight-on-bit and the determined pressure differential.

Abstract: An expansion and sensing tool (50) comprising a tool body, cutter blocks and sensors which permit simultaneous underreaming and measurement of the diameter of a wellbore (40) drilled by an oil and gas rig (10). Radially extendable cutter blocks (62) incorporating positional sensors (80) contained on the block or within the body measure the position of the cutter block relative to the tool, and a vibration sensor (76) measures vibration and underreaming wellbore dimensions in real-time. Receivers, sensors and microprocessors deliver a desired wellbore depth both simultaneously comparing and correlating measured vibration data and optimizing underreaming parameters. The tool may be optionally configured with a caliper or a stabilizer.

Abstract: A method and system for controlling a horizontal directional drilling machine having a boring tool. A rate of rotation and a rate of thrust are selected by an operator. Controls allow an automatic boring operation mode to be initiated to maintain the selected rate of rotation and thrust without further input from the operator. Periodically, when the rotation and thrust are interrupted, such as to modify the drill string, the automatic boring operation mode is interrupted. The automatic boring operation mode may be resumed without requiring the operator to select the rate of rotation and rate of thrust. The rate of rotation is resumed before the rate of thrust to reduce drill string shock loads and increase drilling performance.

Abstract: A method for selecting a drilling motor for rotating a drill bit relative to a drill string made up of casing accounts for a tendency for the casing to elongate as the internal pressure increases. The increase in pressure in the casing string increases the weight on the drill bit, the amount of which may be calculated based on the size and type of the string of casing. The ratio of bit torque over the weight on the bit may be assumed to be a constant number based on empirical measurements or a theoretical model. The increase in the weight on the drill bit can be expressed in terms of the bit torque versus the casing pressure, which is a linear slope. This linear slope may be compared to the delivery torque of candidate motors.

Abstract: A top drive assembly that includes a gauge for measuring strain in a linkage coupling the top drive to a drilling rig frame. The strain measuring gauge, which can be a strain gauge, is disposed on a pin that pivotingly links members of the linkage coupling. When a motor in the top drive assembly operates to rotate an associated pipe string, the torque generated by the motor can be estimated by monitoring strain measured in the pin.

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

Abstract: A method, device and system for augmenting a traditional drilling or workover rig with automated operational, monitoring and reporting systems. The automation system comprises integratable components of various automated operational systems, combined in a device easily adapted to install into the operational area of a drilling or workover rig, wherein the automated operational systems are dynamically selectable either or both locally or remotely.

Abstract: A system, in certain embodiments, includes a spider configured to support multiple mineral extraction riser segments. The system also includes a gimbal disposed below the spider and configured to support the spider during operation. The system further includes one or more arcuate radio frequency identification (RFID) antennas disposed within the gimbal and/or the spider. The one or more arcuate RFID antennas are configured to communicate with one or more RFID tags coupled to each riser segment.

Abstract: Methods and systems are for tripping pipe on a rig floor that is positioned over a well. A measuring device is operated to measure a length characteristic of a first drill pipe in a plurality of separated drill pipes. The length characteristic is inputted into a controller configured to control machinery to hoist the first drill pipe above the drill string, to connect the first drill pipe to the uppermost drill pipe in the drill string, and to operate the drill string to drill into the well. The controller is operated to calculate a first vertical position into which it is necessary to hoist the first drill pipe so that a predetermined clearance distance exists between the lower end of the first drill pipe and the upper end of the uppermost drill pipe in the drill string.

Abstract: The invention relates to a handling device for drill pipes (18) and to a so-called top drive (16) comprising said handling device, a so-called pipe handler, and having means for detecting a position of an elevator bail (30) comprised by the handling device/pipe handler and for transmitting the associated position information, wherein the position information is transmitted from the pipe handler to, e.g., the top drive (16) and is converted into an electrical signal for detecting and avoiding potentially critical situations as a result of a position/deflection of the elevator bail (30).

Abstract: A bit is assembled by forming the bit, including a bit body and a plurality of cutting components; embedding at least one electrical circuit into the bit, the circuit including a temperature sensor; and providing a module to monitor the circuits and generate an indication of bit wear. The electrical circuit may experience a change in resistance or conductivity due to wear of the bit and/or changes in an earth formation adjacent the bit. The bit wear and/or formation changes may be displayed for an operator.

Abstract: A method of downlinking to a downhole tool located in a borehole is provided. The downhole tool detects transitions in the flow velocity of fluid circulating in the borehole at the downhole tool. To provide for the detection of the transitions fluid is pumped into the drillstring so that it circulates in the borehole at the downhole tool and the the pumping rate of fluid into the drillstring is either increased to a rate which overshoots a steady state pumping rate needed to produce a transition or is decreased to a rate which undershoots a steady state pumping rate needed to produce a transition.

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

Abstract: Apparatus and methods for establishing electrical communication between an instrument subsection disposed below a mud motor and an electronics sonde disposed above the mud motor in a drill string conveyed borehole logging system. Electrical communication is established via at least one conductor disposed within the mud motor and connecting the instrument sub section to a link disposed between the mud motor and the electronics sonde. The link can be embodied as a current coupling link, a magnetic coupling ling, an electromagnetic telemetry ling and a direct electrical contact link. Two way data transfer is established in all link embodiments. Power transfer is also established in all but the electromagnetic telemetry link.

Abstract: The present invention relates to a system for transferring signals through a drill pipe system during drilling of a subsurface well. The drill pipe system comprises a first pipe (1) provided concentric inside a second pipe (2) by means of hanging devices (3, 3a). The first pipe (1) is electrically insulated from the second pipe (2). A first signal transceiver is electrically connected to the top of the drill pipe system. A second signal transceiver is electrically connected along or in the bottom of the drill pipe system. The first and second signal transceivers are electrically connected to the first and second pipes (1, 2) for transferring the signals through the drill pipe system.

Abstract: A method in core drilling, wherein a tubular drill bit (8) being arranged at the end of a tubular drill string (6) is driven under rotation against a material intended for drilling, and wherein for the purpose of core retrieving, a tool (17, 20) is brought inside the drill string to an operative position in the area of the drill bit. Acoustic vibrations (24, 25) from the drill string are sensed when the tool is brought to its operative position, sensed acoustic vibrations are analysed for detecting the occurrence of acoustic vibrations characteristic for when the tool has reached its operative position, and an output signal is emitted when the occurrence of vibrations characteristic of when the tool has reached its operative position has been detected. The invention also concerns a device and a drill rig.

Abstract: A downhole communication device comprises a first energy harvesting device; a downhole transceiver in communication with the first energy harvesting device; an accumulator in communication with the energy harvesting device; and a microcontroller. The microcontroller manages communication between the first energy harvesting device, transceiver, and accumulator.

Abstract: The present disclosure describes a spindle for a mud pulse telemetry tool. The spindle includes a seal section having an outer surface for contacting a lip seal of a spindle housing in which the spindle is mounted; a top section attachable to at least part of a valve assembly for generating mud pulses; and a base section having a proximal end attachable to a drive motor for moving the spindle and a distal end attachable to the top section such that the seal section is fixed between the top and base sections. The seal section can be made of a ceramic material such as yttrium-stabilized zirconia.

Abstract: Jointly designed channel coding and modulation are used in an uplink telemetry system for transmitting a message signal from a bottomhole location to a surface location. A constant envelope quadrature-quadrature phase-shift keying may be used.

Abstract: A system and method for downhole measurement for use with drill strings to reduce the borehole gap with respect to sensors carried by the drill string. In one embodiment, the sensors are mounted on a surface of the directional drilling hinged pad that comes in contact with the borehole wall. The hinged pad is pressed against the borehole wall as contact is made with the wall, thereby keeping the sensors at a minimum gap with respect to the wall. In another embodiment, the hinged pad is not used for directional drilling. Therefore the hinged pad is extended outward to the wall with the minimum necessary amount of force. Activation of the hinged pad can be initiated, for example, by flow of mud in the annulus of the string or through a user-provided command. The sensors can include resistivity, density, neutron, electromagnetic, acoustic, seismic, and NMR measurement sensors.

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

Abstract: An apparatus to update data in a well control system includes a central control unit in communication with a communications network, the central control unit comprising a first display database, an end device in communication with the communications network, the end device comprising a local hardware database, and an operator's panel in communication with the communications network, the operator's panel comprising a second display database, wherein the local hardware database is configured to automatically update data to a primary display database designated from one of the first and the second display databases, wherein the primary display database is configured to automatically update the data to the other of the first and the second display databases.

Abstract: A system for damping vibration in a drill string can include a magnetorheological fluid valve assembly having a supply of a magnetorheological fluid. A remanent magnetic field is induced in the valve during operation that can be used to provide the magnetic field for operating the valve so as to eliminate the need to energize the coils except temporarily when changing the amount of damping required The current to be supplied to the coil for inducing a desired magnetic field in the valve is determined based on the limiting hysteresis curve of the valve and the history of the magnetization of the value using a binary search methodology. The history of the magnetization of the valve is expressed as a series of sets of current and it resulting magnetization at which the current experienced a reversal compared to prior values of the current.

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

Abstract: A drilling system includes a downhole well control device that can be used to control out-of-norm wellbore conditions. The downhole well control device can control one or more selected fluid parameters. The well control device in cooperation or independent of surface devices exerts control over one or more drilling or formation parameters to manage an out-of-norm wellbore condition. An exemplary well control device hydraulically isolates one or more sections of a wellbore by selectively blocking fluid flow in a pipe bore and an annulus. The control device also selectively flows fluid from the pipe bore to the annulus. A communication device provides on-way or bidirectional signal and/or data transfer between the controller(s), surface personnel and the well control device. Exemplary application of the well control device include controlling a well kick, controlling drilling fluid being lost to the formation and controlling a simultaneous kick and loss.

Abstract: A downhole telemetry system for use in a wellbore including borehole fluid. The system includes a stator including flow channels though the stator and a rotor including flow channels though the rotor. The rotor is rotatable on a drive shaft by the force of the borehole fluid flowing through the rotor. The rotation of the rotor creates pressure variations in the borehole fluid related to the movement of the rotor channels relative to the stator channels, thus forming a carrier wave. A regulating system adjusts the amount of fluid force on the rotor for a given flow rate of borehole fluid to maintain the frequency of the carrier wave within a range of a target frequency. Also, an alternator drivable by the rotation of the drive shaft provides power to the system. The system also includes an encoder capable of adjusting the rotation of the rotor to modulate the carrier wave.

Abstract: A system for monitoring a drilling rig operation includes a drilling rig assembly and at least one sensor coupled to a member of the drilling rig assembly to sense a parameter related to operation of the drilling rig assembly. A client device coupled to the at least one sensor includes a data acquisition device for receiving data from the at least one sensor. The client device also includes a first radio, which is coupled to the data acquisition device. A base station located a distance from the client device comprises a second radio that communicates wirelessly with the first radio in order to transfer data between the data acquisition device and the base station.

Abstract: An apparatus to remotely archive data from a blowout preventer includes a first system controller in communication with the blowout preventer and a communications network, and a second system controller in communication with the blowout preventer and the communications network. A first remote server and a second remote server are connected to the communications network. The first remote server is configured to archive the data from the blowout preventer through the first local controller and the communications network. The first remote server is also configured to archive the data from the blowout preventer through the second system controller upon a failure of the first system controller resulting from damage in an oilfield component.

Abstract: A rock drilling apparatus with several actuator units, a user interface control unit, and at least one control means connected to the user interface control unit for controlling the functions of the rock drilling apparatus, and for each actuator unit, a control element connected under the control of the user interface control unit for controlling the operation of the actuator unit in accordance with control signals provided by the user interface control unit, and a method for controlling the rock drilling apparatus. When the control element of an actuator unit of the rock drilling apparatus turns faulty, the control element of another actuator unit is connected to control the first actuator unit when the other actuator unit need not be controlled.

Abstract: Some embodiments of the invention concern HDD in an automatic drilling mode. Such embodiments can include maintaining a constant output parameter while performing a drilling operation using an HDD rig (20) having a thrust pump, generating hydraulic fluid pressure measurements from one or more pumps of the HDD rig, comparing the hydraulic fluid pressure measurements to a variable pressure limit, calculating a derivative value using the measured hydraulic fluid pressure measurements, comparing the derivative value to a derivative threshold, decreasing the variable pressure limit when the derivative value exceeds the derivative threshold, wherein the amount that the variable pressure limit is decreased is based on one or more of the hydraulic fluid pressure measurements, and reducing output of the thrust pump when the comparison of the hydraulic fluid pressure measurements to the variable pressure limit indicates that one or more of the hydraulic fluid pressure measurements exceed the variable pressure limit.

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

Abstract: Apparatus and methods for estimating a downhole property are provided. The apparatus may include a downhole tool having a predetermined temperature calibration based at least in part on an expected downhole temperature and a temperature controller in communication with the downhole tool that maintains a downhole tool temperature substantially within the predetermined temperature calibration. A method may include conveying a downhole tool having a predetermined temperature calibration based at least in part on an expected downhole temperature in a well borehole and adjusting the temperature of the downhole tool during downhole operation to maintain a downhole tool temperature substantially within the predetermined temperature calibration.

Abstract: A steering tool has a controller configured to provide closed-loop control of blade pressure and position. In one embodiment, the controller is configured to execute a directional control methodology in which the drilling direction is controlled via control of the blade position. The pressure in each blade is further controlled within a predetermined range of pressures. This embodiment tends to prevent excessive borehole friction while at the same time reducing undesirable rotation of the blade housing. In another embodiment, the controller is configured to correlate blade pressure measurements and blade position measurements during drilling. The correlation is utilized as part of a secondary directional control scheme in the event of a downhole failure of a blade position and/or pressure sensor.

Abstract: A wired pipe signal transmission testing apparatus is provided. The apparatus includes a core having a plurality of threads formed on a surface thereof and a plurality of slots cutting through crests and roots of at least a portion of the threads, thereby creating an escape route for debris that may enter in between the threads. The apparatus includes an inductive transducer coupled to the core.

Abstract: Drill bits and methods for sampling sensor data associated with a state of a drill bit are disclosed. A drill bit for drilling a subterranean formation comprises a bit configured for receiving a data analysis module. The data analysis module comprises at least one sensor, a memory, and a processor. The processor is configured for executing computer instructions to filter information derived from sensor data in the drill bit to develop a piecewise polynomial curve of the sensor data. Filtering information derived from the sensor data comprises approximating a first derivative of a sensor data waveform, calculating a plurality of zeros for the first derivative of the sensor data waveform, and fitting a cubic polynomial between adjacent zeros calculated from the first derivative of the sensor data waveform resulting in a piecewise cubic polynomial.

Abstract: In one aspect of the present invention, a method of excavation with pointed cutting elements, comprising the steps of providing a excavating assembly with at least one pointed cutting element, the pointed cutting element comprising a rounded apex that intersects a central axis, the pointed cutting element further has a characteristic of having its highest impact resistance to resultant forces aligned with the central axis; engaging the at least one pointed cutting element against a formation such that the formation applies a resultant force against the pointed cutting element; determining an angle of the resultant force; and modifying at least one excavating parameter to align the resultant force with the pointed cutting element's central axis.

Abstract: A system for damping vibration in a drill string can include a magnetorheological fluid valve assembly having a supply of a magnetorheological fluid, a first member, and a second member capable of moving in relation to first member in response to vibration of the drill bit. The first and second members define a first and a second chamber for holding the fluid. Fluid can flow between the first and second chambers in response to the movement of the second member in relation to the first member. The valve assembly can also include a coil for inducing a magnetic field that alters the resistance of the magnetorheological fluid to flow between the first and second chambers, thereby increasing the damping provided by the valve.

Abstract: Drill bits and methods of measuring drill bit conditions are disclosed. A drill bit for drilling a subterranean formation comprises a bit bearing at least one cutting element and adapted for coupling to a drill string. The drill bit may also comprise a chamber formed within the bit and configured for maintaining a pressure substantially near a surface atmospheric pressure while drilling the subterranean formation. In addition, the drill bit may comprise at least one optical sensor disposed in the chamber and configured for sensing at least one physical parameter exhibited by the drill bit while drilling a subterranean formation.

Abstract: In one aspect, an apparatus for use in a wellbore is provided that in one embodiment includes a drill bit having a bit body that is susceptible to corrosion when the drill bit is utilized in wellbore, an anode placed at a selected location on the bit body, a cathode associated with the bit body and a power source configured to provide electrical power to the anode to complete an electrical circuit between the anode and the bit body, wherein the supply of the electrical power to the anode arrests corrosion of the bit body when the drill bit is in the wellbore.

Abstract: A method and apparatus for determining formation parameters including a seismic array for receiving seismic waves at plurality of depth simultaneously, thereby enabling a determination of a formation velocity by using a difference in the seismic waves received by the various portions of the array.

Abstract: A drill bit string has an internal steering module for measurement while drilling. A chassis is inserted into a modified drill collar from the axial end, rather than through the side. The chassis has external pockets machined into it from its outer diameter. The size of the longitudinally milled slots in the chassis is determined by the size of the components. The mud flow path is positioned off-center because of the component slots. The geometric shape of the flow path through the tool is shaped to optimize the flow area and maintain a wall thickness that can withstand the mud pressure. The wall thickness surrounding the flow area is proportional to the maximum hydrostatic pressure and the circulation pressure.

Abstract: A method, system and apparatus for testing properties of a rock formation surrounding a wellbore in situ. The apparatus includes a tool body, one or more indenters, and one or more acoustic sensors. The body includes an outer surface that defines one or more cavities therein. Each cavity extends into the body. Each indenter is positioned within a corresponding cavity and is positionable into an operating position and a non-operating position. The acoustic sensor is positioned within the cavity and adjacent to the indenter. The indenter is positioned at least partially beyond the outer surface when in the operating position. The acoustic sensor senses one or more acoustic events occurring when the indenter is in the operating position. The apparatus is inserted into the wellbore. Once inserted, the indenter applies a load onto the rock formation causing cracking and the sensor receives the generated acoustic transmissions. The transmissions are analyzed.

Abstract: An apparatus and a process for wellbore characterization are disclosed, including: separating, in a separation vessel, drilling mud from gas produced during drilling of a wellbore; transporting the separated produced gas from the separation vessel to a downstream process; and measuring at least one of a temperature, a pressure, a mass flow rate, and a volumetric flow rate of the separated produced gas during transport using one or more sensors. Properties of the gas separated from the mud may be used to determine characteristics of a wellbore.

Abstract: A computer usable medium including computer usable program code for determining an oilfield parameter for a drilling operation. The computer usable program code when executed causing a processor to identify first decision factors and second decision factors about the drilling operation, where each of the first decision factors is contained within first nodes, and where each of the second decision factors is contained within second nodes, where the first and second nodes contain common nodes. The computer usable program code further causing the processor to associate the first nodes to create a first belief network and associate the second nodes to create a second belief network, associate the common nodes of the first belief network with the common nodes of the second belief network to form a multinet belief network, and generate at least one oilfield parameter from the multinet belief network.

Abstract: Methods of using resistivity ahead of a drill bit measurements obtained while drilling a subterranean well using a drilling mud. Resistivity data ahead of the bit is gathered during drilling and prior to penetrating a region of interest of a known subterranean formation using the drill bit and the drilling mud. The drill string progresses at known dip and azimuth angles toward the subterranean formation. The resistivity data is used to determine pore pressure ahead of the drill bit in the formation as a function of resistivity ahead of the drill bit in the formation while the drill bit advances toward but before the bit penetrates the formation while drilling.

Abstract: Apparatus and methods for establishing electrical communication between an instrument subsection disposed below a mud motor and an electronics sonde disposed above the mud motor in a drill string conveyed borehole logging system. Electrical communication is established via at least one conductor disposed within the mud motor and connecting the instrument sub section to a link disposed between the mud motor and the electronics sonde. The link can be embodied as a current coupling link, a magnetic coupling ling, an electromagnetic telemetry ling and a direct electrical contact link. Two way data transfer is established in all link embodiments. Power transfer is also established in all but the electromagnetic telemetry link.

Abstract: The present invention relates to a method for controlling a rock drilling process, in which an impulse-generating device comprising an impact element transmits a shock wave to a tool connected to the impulse-generating device, whereby a portion of the energy of the shock wave is transmitted to the rock by means of the tool and a portion of the energy of the shock wave is reflected and brought back to the impulse-generating device as reflected energy. The method comprises steps of generating at least one parameter value representing the reflected energy, and regulating the interaction of said impact element with said tool at least partially based on said value or values to control the rise time and/or length of said shock wave. The invention also relates to a regulation device, an impulse-generating device and a drilling rig.

Abstract: Job monitoring methods and apparatus for logging-while-drilling equipment are disclosed. A disclosed example method includes obtaining a fluid associated with an underground geological formation, analyzing the fluid with one or more sensors to form respective ones of sensor outputs, identifying a downhole scenario associated with the fluid based on the sensor outputs, the identifying being performed while the sensors are within the underground geological formation, and selecting a telemetry frame type based on the identified downhole scenario.

Abstract: A wireless transceiver for transmitting data across a pipe joint is described herein. At least some illustrative embodiments include a wireless communication apparatus including a housing configured to be positioned inside/proximate of/to an end of a drill pipe. The housing includes an antenna with at least one RF signal propagation path parallel to the axis of the housing, and an RF module (coupled to the antenna) configured to couple to a communication cable, and to provide at least part of a data retransmission function between an antenna signal and a communication cable signal. A material (transparent to RF signals within the RF module's operating range) is positioned along the circumference, and at/near an axial end, of the housing closest to the antenna. At least some RF signals, axially propagated between the antenna and a region near said axial end, traverse the radiotransparent material along the propagation path.

Abstract: What is claimed is a downhole tool string component comprising a generator. The generator may comprise a toroidal stator comprising an interior channel formed between inward extending stator poles. A coil of wire is disposed within the interior channel, and a plurality of magnets are rotatably disposed proximate each pole. A downhole tool string component comprises a bore to receive a flow of drilling fluid comprising a central passage and at least one peripheral passage. A compliant member is disposed within the bore and forms an internal diameter of the central passage, and at least one opening. The at least one opening comprises an internal area within the compliant member to divert the flow of drilling fluid into the at least one peripheral passage. The compliant member comprises a compliant property allowing the internal area of the at least one opening to change thus changing the amount of diverted drilling fluid.