Abstract: A method and system for steering a rotary steerable tool in a borehole. A method includes determining an azimuthal angle between a reference direction and a reference point on a direction determination component of a tool string. The direction control component is remote from the rotary steerable tool. The azimuthal angle and a time at which the angle was determined are communicated to a rotary steerable tool direction control system. A steerable shaft of the rotary steerable tool is deflected based on the azimuthal angle and the time at which the angle was determined, thereby directing the rotary steerable tool in a predetermined direction.

Abstract: A cloud computing method for geosteering during directional drilling of a wellbore. The method includes a cloud processor, cloud data storage, and client devices in communication with the cloud processor through a network. The cloud processor receives data from directional drilling equipment and presents that data to users in an executive dashboard. Users can send data and/or commands to the directional drilling equipment. The executive dashboard can present: a portion of interest in a stratigraphic cross section for user identification of: the drill bit in the stratigraphic cross section, formations in the stratigraphic cross section, and other formation data. The method can be used to: identify a projected path for the drill bit, import data, compute wellbore profiles and stratigraphic cross sections, plot actual drilling paths, overlay the actual drilling path onto the projected path, and present control buttons to the user.

Abstract: A method for managing a drilling operation, including generating, by a first sensor and a second sensor of a bottom hole assembly (BHA), a first time based data log and a second time based data log, respectively, representing a borehole parameter along a drilling trajectory, determining, by a computer processor of the BHA and during the drilling operation, a time shift by comparing the first time based data log and the second time based data log, where offsetting the first and second time based data logs by the time shift maximizes a correlation factor of the first and second time based data logs, and determining, within a pre-determined time period from generating the first and second time based data logs, a drilling speed based on the time shift and a pre-determined distance between the first sensor and the second sensor.

Abstract: A method for drilling operation in a subterranean formation, including calculating, by a hardware processor and in response to determining that an magnitude of gyro data representing rotations of a drill bit in a bottom hole assembly (BHA) and a time derivative of the gyro data are within a pre-determined range, a drift parameter of the gyro data, analyzing, by the hardware processor, the gyro data based on the drift parameter to generate a stick-slip alert, and presenting the stick-slip alert.

Abstract: A system for drilling at least one well of interest proximate a reference well comprises at least one sensor in a drill string in the at least one well of interest to detect at least one parameter of interest related to a distance and a direction to the reference well. A controller is operatively coupled to the at least one sensor to determine the distance and the direction from the sensor to the reference well based at least in part on the at least one detected parameter of interest. A steerable assembly is operatively coupled to the controller to receive commands from the controller to adjust the path of the at least one well of interest being drilled based at least in part on the distance and direction from the sensor to the reference well.

Abstract: The present invention relates to apparatus and methods for remotely adjusting the drill bit hydraulic horse power per square inch (HSI). Varying the nozzle geometry remotely without the need to pull the drill string outside the hole has obvious advantage. Changing the nozzle glow geometry results in changing the nozzle HSI which is beneficial to optimize drilling different rock formations in different drilling environment. There are many concepts to vary the nozzle size while drilling. The drill bit nozzle geometry can be varied by causing a change of at least one physical property of the environment. The variable geometry nozzle is not limited to drill bit, it can be placed within the inner flow passage or between the inner flow passage and annular flow passage for controlling flow profile within a wellbore, a tubular string or a flow conduit.

Abstract: A control system and method for operating a well completion system utilizing at least one computer programmed in one embodiment to automatically operate the movement of pipe from a pipe tub to the mast and into the well and/or for movement of the pipe out of the well and/or back into the pipe tub. In one embodiment, the computer is programmed and/or configured to coordinate operation of a top drive, and/or a pipe tong, and/or a pipe moving member for moving pipe into and out of a mast, and/or a pipe transfer system for moving pipe to the pipe moving member. In one embodiment, at least a portion of the at least one computer is mounted within a control van which may be positioned so that an operator within the control van can oversee operation of the well completion system.

Abstract: A method of selectively actuating a downhole tool, wherein the downhole tool includes a tubular body with an axial borehole therethrough and at least one component, includes increasing a flow rate of a circulating fluid in the axial borehole of the downhole tool to reach a specified circulating fluid pressure, detecting an increased circulating fluid pressure in the borehole of the tool with at least one sensor, actuating a motor to operate a pump, and sending a fluid to operate a sliding sleeve. The method further includes operating the sleeve disposed in the axial borehole to open an actuation chamber port in response to the increased circulating fluid pressure in the borehole of the tool, thereby filling an actuation chamber with the drilling fluid, and moving the at least one expandable component radially outward.

Abstract: Closed loop methods for drilling twin wells are disclosed. The disclosed method make use of a bottom hole assembly including a rotary steerable tool. An electrical current is induced in the target well. The corresponding magnetic field about the target well is measured in the twin well and used to guide drilling of the twin well.

Abstract: Methods and systems may be provided simulating forming a wide variety of directional wellbores including wellbores with variable tilt rates and/or relatively constant tilt rates. The methods and systems may also be used to simulate forming a wellbore in subterranean formations having a combination of soft, medium and hard formation materials, multiple layers of formation materials and relatively hard stringers disposed throughout one or more layers of formation material. Values of bit walk rate from such simulations may be used to design and/or select drilling equipment for use in forming a directional wellbore.

Abstract: A rock drilling rig and a method of driving a compressor, wherein the rock drilling rig is operated by a combustion engine and is provided with a flushing system including a compressor for producing pressurized air. The compressor is driven by an electric drive motor. The combustion engine is connected to drive a generator, which produces electric energy that is stored in an energy storage. The stored electric energy can be utilized in driving the compressor.

Abstract: A drilling system for directional drilling of a borehole includes a biasing mechanism having a pivot associated with a lower bearing assembly, an offset mechanism associated with an upper radial bearing assembly, and a toolface controller, whereby the angular relationship of a drill bit and its toolface angle may be actively managed.

Abstract: Various embodiments are directed to a method and apparatus for horizontal directional drilling with a tool library. Various methods include storing a plurality of operational tool profiles in memory, the operational tool profiles of the plurality respectively associated with a plurality of boring tools attachable to a drill string for HHD and each of the operational tool profiles of the plurality including operating parameters for the boring tool of the plurality with which the operational profile is associated, and selectively displaying the operational tool profiles on a display screen based on user input.

Abstract: A method of drilling a wellbore includes drilling the wellbore by injecting drilling fluid through a drill string extending into the wellbore from surface and rotating a drill bit of the drill string. The drill string further includes a circulation sub having a port closed during drilling. The drilling fluid exits the drill bit and carries cuttings from the drill bit. The drilling fluid and cuttings (returns) flow to the surface via an annulus formed between an outer surface of the tubular string and an inner surface of the wellbore. The method further includes after drilling at least a portion of the wellbore: halting drilling; sending a wireless instruction signal from the surface to a downhole portion of the drill string by articulating the drill string, acoustic signal, or mud pulse, thereby opening the port; and injecting drilling fluid through the drill string and into the annulus via the open port.

Abstract: A method for automated drilling of a borehole in a subsurface formation includes drilling the borehole using a set of drilling control variables assigned a set of values. An automated drilling index of the drilling is monitored. The automated drilling index of the drilling is a combination of a first index that depends on a rate of penetration of the drilling and a second index that depends on a mechanical specific energy of the drilling. The values assigned to the set of drilling control variables are selectively adjusted at least once during the drilling based on the monitoring of the automated drilling index.

Abstract: An electronically activated tool (50) comprising a tool body, cutter blocks and sensors with means for attachment to a drilling support and rotation so as to permit the simultaneous underreaming and measurement of the diameter of a wellbore (especially in oil and gas drilling) characterized by a means of activation using an electronic signal sent by mud-pulse, fibre-optics, wireless transmission or other means which may also communicate commands and receive data from the underreamer during drilling, at least one radially extendable cutter block (62) incorporating positional sensors adapted to measure the relative position of the cutter block to the tool, at least one calliper means (76) to measure wellbore diameter, all of which are inter-linked by a means of communication using receivers, sensors and microprocessors and a system that optimizes underreaming or expansion (22) by simultaneously comparing and correlating wellbore diameter data (22) and underreaming parameters in real-time or in memory.

Abstract: In one aspect, the invention provides a method for modeling the wear of a fixed cutter bit drilling earth formations. A method for determining wear of a fixed cutter drill bit includes simulating the fixed cutter drill bit drilling an earth formation; determining a cutter-formation interaction force and a relative sliding velocity of a selected area on a cutting surface on a cutter of the fixed cutter drill bit during the drilling; and calculating a wear rate of the selected area based on the cutter-formation interaction force and the relative sliding velocity.

Abstract: A drilling assembly for drilling a subterranean wellbore includes an expandable reamer and an expandable stabilizer. The expandable reamer and the expandable stabilizer each have a tubular body with a longitudinal axis and a drilling fluid flow path extending therethrough. A plurality of blades is carried by the reamer and a plurality of bearing pads is carried by the stabilizer. The blades and bearing pads are outwardly movable from a retracted position to an extended position with respect to the longitudinal axes of the reamer and stabilizer, respectively. The reamer and stabilizer each include an actuation device for moving the blades and bearing pads, respectively, from the retracted position to the extended position.

Abstract: A system and method for controlling a downhole portion of a drill string is provided. The method includes receiving signals from a first sensor package mounted at a first position to the downhole portion, the signals indicative of an orientation of the first sensor package. The method also includes receiving signals from a second sensor package mounted at a second position to the downhole portion, the signals indicative of an orientation of the second sensor package. The method further includes calculating a first amount of bend between the first and second sensor packages in response to the signals and transmitting control signals to an actuator which responds by adjusting the downhole portion to have a second amount of bend between the first and second sensor packages.

Abstract: A method of drilling a wellbore can include drilling the wellbore with a continuous tubing drill string, and sensing at least one parameter with an optical waveguide in the drill string. A well system can include a continuous tubing drill string, and an optical waveguide in the drill string. The optical waveguide may sense at least one parameter distributed along the drill string.

Abstract: A system for drilling a borehole according to the present invention includes a drill rig and a control system. The control system receives information from the drill rig that relates to at least one drill parameter. The control system processes information relating to the drill parameter, determines whether the drill parameter is within a predetermined specification for the monitored drill parameter, chooses a hole defect mitigation routine based on the monitored drill parameter when the monitored drill parameter is outside the predetermined specification, and controls the drill rig to implement the chosen hole defect mitigation routine.

Abstract: A method of steering a drilling operation of a well using rock stress measurements. The method includes obtaining well data from at least one logging while drilling tool in the well, where the well data includes stress direction information, generating, using a central processing unit (CPU), a well trajectory using survey data from the well, where the well trajectory includes a borehole direction, determining, using the CPU, a direction of minimum horizontal stress using the well data, and comparing, using the CPU, the direction of minimum horizontal stress to the borehole direction to determine that a directional criteria is not satisfied. The method further includes in response to determining that the directional criteria is not satisfied, generating an updated well trajectory that satisfies the directional criteria and adjusting the drilling operation using the updated well trajectory.

Abstract: A method for controlling vibrations in a drilling system, the drilling system including an elongate body extending from surface into a borehole formed in an earth formation, and an associated drive system for driving the elongate body, the drive system comprising a torque controller, the method comprising obtaining a model of the drilling system; obtaining at least one input parameter for the model that relates to an uphole parameter of the drilling system; operating the drive system to provide a drive torque to the elongated body; obtaining at least one output parameter from applying the model using the at least one input parameter, the at least one output parameter including at least one modelled downhole parameter of rotational motion; using the modelled downhole parameter of rotational motion in the torque controller for determining an adjustment to the drive torque, so as to control vibrations; as well as a drilling system comprising a torque controller, which torque controller is adapted to use the mode

Abstract: A computerized boring system provides real-time monitoring and control of a bore head during boring operations to prevent inadvertent damage to buried objects such as utility cables. A boring machine with a shaft, a bore head on an end of the shaft, and one or more proximity sensors for detecting underground target objects is controlled manually and by a computer control system in communication with the sensors, a programmable logic computer and/or electrical relay system providing control of rotational and longitudinal movement of the bore head in response to data generated by the sensors.

Abstract: A drilling rig having continuous gas analysis can include a substructure, base, mast, pipe handler, mud pump, drilling rig power source, drawworks, cabling, rotating head, blowout preventer, drill string, and drill bit. A rig server of the drilling rig can have a rig processor and rig data storage for implementing rig operations. Piping can be in fluid communication between the blowout preventer and a gas analyzer system for real-time measurement of a concentration of gases in a drilling fluid. The gas analyzer system can include a sample chamber, means for agitating and creating a vortex, gas capturing chamber for receiving liberated fluid, gas analyzer for providing real-time gas speciation of the liberated fluid, suction pump for pulling the liberated fluid, filtration means, exhaust port, and exhaust line for flowing non-analyzed fluid to a drilling fluid storage chamber, drilling fluid conduit, or both.

Abstract: A method of controlling a direction of drilling of the drill string used to form an opening in a subsurface formation, comprises varying a speed of the drill string during rotational drilling such that the drill string is at a first speed during a first portion of the rotational cycle and at a second speed during a second portion of the rotational cycle wherein the first speed is higher than the second speed, and wherein operating at the second speed in the second portion of the rotational cycle causes the drill string to change the direction of drilling.

Abstract: A down hole tool includes a tool body, a fluid cavity, a magnetorheological fluid disposed in the fluid cavity, and an electrical control unit in communication with the MR fluid. The electrical control unit is configured to adjust a viscosity of the MR fluid by varying a magnetic field.

Abstract: Control device (100) controlling a drilling operation and methods by which the dynamics of the continuum in question can be divided into superimposed waves, of which the wave traveling in the direction of the actuator and/or drive (10) is compensated by the actuator. This prevents reflection of the energy on the actuator. By using two sensors (30, 40) the wave traveling towards the actuator (10) and the wave traveling away from the actuator (10) can be calculated separately from one another, so that both the parameters of the wave traveling toward the actuator and the parameters of the wave traveling away from the actuator can be determined in order to be able to perform a control of the driving device of the drill string (20) on this basis.

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: This disclosure relates in general to a method and a system for directionally drilling a borehole with a rotary drilling system. More specifically, but not by way of limitation, methods and system provide for controlling motion of the rotary drilling system in the borehole when a side force is applied to the drilling system to bias or focus the motion so that the drilling system directionally drills the borehole through an earth formation. In certain aspects, side cutting of a sidewall of the borehole by a drill bit under an applied side force is controlled by a geostationary element to provide for directional side cutting and, as a result, directional drilling of the borehole through the earth formation. In other aspects, a non-concentrically coupled gauge pad assembly may rotate with the drilling system and bias or focus the applied side force.

Abstract: A method, apparatus, and program product facilitate the automation of an oil & gas process, e.g., a drilling process, through the use of a dynamic phase machine incorporating multiple autonomous agents. An agent may be used to perform automated acceptance of a survey performed by a downhole survey device, e.g., so that an oil & gas drilling process may proceed for an accepted survey.

Abstract: An apparatus for use in a wellbore is provided that in one embodiment includes a load, a motor coupled to the load to provide electrical power to the load and an alternator directly coupled to the motor driving the motor. In one aspect, the apparatus further includes a switch between the alternator and the motor that in a first position connects the alternator to the motor in a first configuration that rotates the motor in the clockwise direction and in a second configuration that rotates the motor in the counterclockwise direction.

Abstract: A prog analysis and execution system and method. The system includes a computer control system, an interface engine in communication with the computer control system, the interface engine being configured to receive prog information, and an action item development engine in communication with the control system, the action item development engine being configured to analyze received prog information and to determine corresponding action items. The system further includes a sensor engine in communication with the computer control system, the sensor engine being configured to receive input from at least one sensor for use in controlling a well drilling operation, and an operational equipment engine in communication with the computer control system, the operational equipment engine being configured to receive input from the computer control system and to control the well drilling operation in accordance with the determined action items in the prog.

Abstract: A technique facilitates controlling the direction of drilling when using a rotary steerable system to drill a borehole. The method comprises processing parameters related to operation of a rotatable collar of the rotary steerable system. The parameters are used in cooperation with characteristics of actuators to control the positioning of an actuator tool face which, in turn, controls the drilling orientation of the rotary steerable system.

Abstract: Various embodiments are directed to a method and apparatus for horizontal directional drilling with a tool library. Various methods include storing a plurality of operational tool profiles in memory, the operational tool profiles of the plurality respectively associated with a plurality of boring tools attachable to a drill string for HHD and each of the operational tool profiles of the plurality including operating parameters for the boring tool of the plurality with which the operational profile is associated, and selectively displaying the operational tool profiles on a display screen based on user input.

Abstract: A method controls motions of a mechanical arm using an electronic device. The mechanical arm includes an x-axis, a y-axis, and a z-axis. The method sets a step angle of a motor installed in line with the z-axis, and predefines angles of rotation as reference points regarding orientation of the rotating arm when rotated. The method further calculates a rotation angle of the rotating arm in a polar coordinate system, calculates coordinate motions of the x-axis and the y-axis if a free end of the rotating arm orientates to one of the reference points, and calculates an offset correction value of a pole origin position of the polar coordinate system. After correcting each of the coordinate motions and the pole origin position, the method controls the mechanical arm to move, and drives the rotating arm to reach another reference point according to a multiple of the step angle.

Abstract: A method for performing an oilfield operation of an oilfield having a subterranean formation. The method includes collecting oilfield data and deploying a first plug-in including a first oilfield technology functionality into an oilfield hosting application. The method further includes performing an oilfield analysis on the collected oilfield data in the oilfield hosting application using the first oilfield technology functionality of the first plug-in to generate an oilfield output and adjusting an oilfield operation based on the oilfield output.

Abstract: The present invention relates to a method for controlling a power source (9) at a rock drilling apparatus, said power source (9) being arranged to drive at least a first load (8,10,15) at the rock drilling apparatus, wherein said first load (8,10,15), in operation, provides power to a first consumer (11,21), and where the power that can be delivered by- said first load (8,10,15) depends on the rotation speed of the power source. The method includes, by means of a representation of said first consumer (11,21), determining a power demand of said first consumer (11,21), and based on said determined power demand, determine a rotation speed demand of said first load (8,10,15). The rotation speed of said power source is then controlled based at least on said determined rotation speed demand of said first load (8, 10, 15 ). The invention also relates to a system and a rock drilling apparatus.

Abstract: The present invention provides a lubrication system for a drilling apparatus. The drilling apparatus includes a drill string and a drill bit, and it is driven by a working fluid circulated through a working fluid circuit. The lubrication system uses a reservoir of a lubricating fluid for supply to a drilling apparatus during a drilling operation; and a pump for supplying lubricating fluid from said reservoir to the drilling apparatus during the drilling operation. The pump is controlled to supply lubricating fluid from the reservoir at a determined rate to a lubrication circuit formed by the working fluid circuit of the drilling apparatus.

Abstract: A method and a device for controlling a drill rig (1) which includes a carrier vehicle with at least one feed-beam (3), wherein a drill machine (2) is movable to-and-fro, wherein rig parameters are set by a control unit (6) and wherein each one of a plurality of operating modes (M1-M6) includes specified operating settings for different operating parameters of the rig. Each operating mode (M1-M6) is selectable such that operation of the rig is related to a particular type of rock, in which drilling is to be performed, and each operating mode (M1-M6) includes operating settings that are adapted to the prevailing type of rock. The invention also concerns a drill rig.

Abstract: Processes and systems for drilling a borehole wherein a gravitational energy term, a torsional energy term, a hydraulic energy term and a hydromechanical specific energy which is the sum thereof may be determined using real-time data and compared against corresponding setpoints. The hydraulic energy term may include a hydraulic energy reduction factor so as to account for the distance between the fluid nozzle of the drill bit and the rock and may include the kinematic viscosity of drilling fluid. One or more drilling parameters, such as weight on bit, revolutions per minute, drilling fluid flow rate, or combinations thereof, may be adjusted based upon such comparison to approximate the least amount of energy required to destroy and remove a given unit volume of rock. The setpoints may be changed manually or automatically at the direction of the user.

Abstract: A boring tool that is moved by a drill string to form an underground bore. A transmitter transmits a time varying dipole field as a homing field from the boring tool. A pitch sensor detects a pitch orientation of the boring tool. A homing receiver is positionable at a target location for detecting the homing field to produce a set of flux measurements. A processing arrangement uses the pitch orientation and flux measurements with a determined length of the drill string to determine a vertical homing command for use in controlling depth in directing the boring tool to the target location such that the vertical homing command is generated with a particular accuracy at a given range between the transmitter and the homing receiver and which would otherwise be generated with the particular accuracy for a standard range, different from the particular range. An associated system and method are described.

Abstract: A method and a storage device including a software product for designing a drilling pattern, and further a rock drilling rig, in the control unit of which a software product may be executed for designing the drilling pattern. For a group of holes of the drilling pattern, at least one master hole can be determined which comprises at least one dominating factor. The properties of at least one other drill hole are determined on the basis of the dominating properties of the master hole. A master hole may be a hole location master, hole depth master or hole direction master.

Abstract: A method for controlling a downhole pressure during drilling comprises continually sensing in real-time at least one real-time fluid property of an input fluid to a well and of a return fluid from the well. A wellhead setpoint pressure is calculated in real-time that results in a predetermined downhole pressure at a predetermined location in the well, where the calculation based, at least in part, on the at least one continually sensed real-time fluid property. The flow of the return fluid is controllably regulated to maintain the calculated wellhead setpoint pressure.

Abstract: A well drilling system can include a hydraulics model which determines a modeled fluid friction pressure and a calibration factor applied to the modeled friction pressure, and a flow control device which is automatically controlled in response to a change in the calibration factor. A well drilling method can include drilling a wellbore, a fluid circulating through the wellbore during the drilling, determining a calibration factor which is applied to a modeled fluid friction pressure, and controlling the drilling based at least in part on a change in the calibration factor.

Abstract: An attitude hold controller method includes receiving at a navigable apparatus a demand inclination and a demand azimuth with respect to a global coordinate system and determining at the navigable apparatus a demand attitude vector according to the received demand inclination and the demand azimuth. Determining at the navigable apparatus a current navigable apparatus attitude vector. Evaluating a control law using the current navigable apparatus vector and the navigable apparatus demand attitude to derive a control law tool face, converting the control law tool face to an equivalent tool face, and applying the equivalent tool face with the navigable apparatus to control the navigable apparatus attitude.

Abstract: Disclosed is an apparatus, method, and program product for steering a drill bit within a pay zone in a lateral well. The method includes receiving acoustic signature data from a downhole processor assembly. The acoustic signature data includes an amplitude spectrum and one or more acoustic characteristics evaluated from an acoustic signal provided by a sensor arranged adjacent to a drill bit and generated in real-time as a result of rotational contact of the drill bit with encountered rock in the lateral well during drilling. The method further includes comparing the received real-time acoustic signature data to predetermined acoustic signatures determined for a plurality of rock samples, and identifying a lithology type of the rock being encountered by the drill bit based on the comparison. Further, the method includes steering the drill bit in a predefined direction, in real-time, based on the identified lithology type of the rock, for maintaining the drill bit within the pay zone of the lateral well.

Abstract: Disclosed is an apparatus, method, and program product for steering a drill bit within a pay zone in a lateral well. The method includes receiving acoustic signature data from an acoustic signal analyzing apparatus. The acoustic signature data includes an amplitude spectrum and one or more acoustic characteristics evaluated from an acoustic signal provided by a sensor attached to at least one of a drive shaft and a packing box of a drill rig, and generated in real-time as a result of rotational contact of the drill bit with encountered rock in the lateral well during drilling. The method further includes comparing the received real-time acoustic signature data to predetermined acoustic signatures determined for a plurality of rock samples, and identifying a lithology type of the rock being encountered by the drill bit based on the comparison.

Abstract: Various methods are disclosed, comprising obtaining a plurality of raw depth measurements for a wellbore; obtaining survey data about a bottom hole assembly; obtaining depth compensation information; calculating a plurality of compensated depth measurements from the raw depth measurements and the depth compensation information and one or more additional corrections for residual pipe compliance, tide, and rig heave; calculating sag angle and correcting the survey data with the sag angle; determining a high fidelity wellbore trajectory from the compensated depth measurements and the survey data; and then employing the high fidelity wellbore trajectory in various drilling, formation evaluation, and production and reservoir analysis applications. Depth compensation information may comprise at least one of weight on bit, a friction factor, temperature profile, borehole profile, drill string mechanical properties, hookload, and drilling fluid property. The surveys may include both static and continuous surveys.

Abstract: A device for cleaning and doping (lubrication) equipment for threads (3b, 4b) of the type used to join pipes (4) to a pipe string (3), especially in connection with petroleum production, where cleaning fluid and dope (lubricant) are sprayed at the threads (3b, 4b) at relatively high pressure from at least one nozzle (5, 6) mounted in the rotatable make-up section (1) of a power tong, and where at least one injection pump (7, 8) arranged to supply cleaning fluid or dope to the at least one nozzle (5, 6) is located in the rotatable make-up section (1).