Nabors Drilling Technologies USA, Inc.

Nabors Industries, Inc.

Other

Canrig Robotic Technologies as

Magnuson Patents, LLC

Christopher Magnuson

Alex Kunec

Steven K Deel

Eric Deutsch

Predrag Radovanovic

Mark Docherty

Mario Sazo

Miodrag Djuric

Vladimir Scekic

Enrique Abarca

Keith Hager

Kent Hulick

Godwin Simanjuntak

Markus Buchholz

Djuric Miodrag

Pedrag Radovanovic

Marvin Brown

Dejan Pavlovic

A linear actuator assembly that can include a drive shaft, and a piston, where rotation of the drive shaft extends or retracts the piston at a speed that automatically changes based on an opposing force applied to the piston. A system that can include a piece of rig equipment configured to engage an object, with one or more linear actuator assemblies incorporated into the piece of rig equipment, where the linear actuator assemblies selectively engage the object and each of the linear actuator assemblies can include a drive shaft, and a piston, and where rotation of the drive shaft extends or retracts the piston at a speed that automatically changes based on an opposing force applied to the piston.

Dual speed linear actuator assembly

A system with a wrench coupled to a rig floor, and the wrench can include a plurality of grippers, a linkage mechanism that couples the plurality of grippers together, and a plurality of actuators coupled to the linkage mechanism, with the plurality of actuators used to apply a force to the linkage mechanism in opposite directions, and with the linkage mechanism configured to evenly distribute the force between the plurality of grippers. The wrench can support a torque wrench or a backup tong of an iron roughneck.

Torque wrench

A system including a spinner assembly that includes a spinner subassembly which includes a spinner configured to engage a tubular, and a drive gear coupled to the spinner, with the drive gear configured to drive rotation of the spinner, and the encoder configured to count teeth of the drive gear as the drive gear rotates. A controller configured to determine a number of revolutions of a tubular that are needed to thread the tubular to a tubular string based on data from the encoder. The controller is also configured to determine when the tubular is unthreaded from the tubular string based on data from the encoder.

Spinner wear detection

A system for conducting a subterranean operation can include a retention feature in a drill floor with the retention feature configured to suspend a tubular string from the drill floor via engagement of the retention feature with the tubular string, an imaging system configured to capture images of a visible feature on a portion of the tubular string that extends above the drill floor; and a processor configured to detect a change in a position of the visible feature while the tubular string is engaged with the retention feature, and the processor being configured to calculate a wear status of the retention feature based upon the change in the position of the tubular string.

Slip wear detection

A carrier assembly for a catwalk assembly includes a carrier. The carrier assembly includes a skate to move a tubular member along the carrier. The carrier assembly includes a proximity sensor positioned to detect the end of the tubular member as it moves along the carrier. The carrier assembly includes a skate position sensor. The length of the tubular member may be determined by measuring the position of the skate relative to the proximity sensor when the end of the tubular member passes the proximity sensor.

Catwalk tubular measurement and method of use

The systems, devices, and methods described herein relate to tubular detection on a gripperhead system for a drilling rig. The gripperhead system includes a grabber and a gripper each having first and second grabber arm and pistons connected to the first and second arms. Each arm may also include an inwardly facing gripping surface forming at least a portion of a chamber sized to receive a portion of a cylindrical tubular. One or more sensors may be disposed on the gripperhead system, including proximity sensors disposed on the arms, inductive sensors disposed within the pistons, and ultrasonic sensors disposed on other features of gripperhead system. The one or more sensors may be configured to determine the position of the tubular in relation to the arms, measure the size of the tubular, measure the compression force of the grabber, and ensure that the tubular is secured within the grabber.

Systems, devices, and methods to detect pipe with a gripperhead

A system with multiple spinners in a spinner assembly, each spinner comprising a drive shaft, a sleeve with arcuate segments surrounding the drive shaft, a first cap that receives a first end of the sleeve and a second cap that receives a second end of the sleeve, which secures the sleeve to the drive shaft. A system with two spinner subassemblies in a spinner assembly, and with a coupling assembly that moves the subassemblies a same distance in opposite directions relative to a center axis of the spinner assembly. A method can include securing multiple arcuate segments of the sleeve to a drive shaft of the spinner by inserting a first end of the sleeve into a first recess of a first cap and inserting a second end of the sleeve into a second recess of a second cap.

Spinner with consumable sleeve

A system for monitoring a drill string comprising: a plurality of image capture devices disposed around a wellbore and adapted to record images of a portion of the drill string; and a logic device adapted to determine linearity of the portion of the drill string based on a form factor deviation. A method of monitoring a drill string comprising: capturing images of a portion of the drill string with an image capture device; assessing a form factor deviation of the portion of the drill string; and determining a linearity of the portion of the drill string based on the form factor deviation.

Systems and methods for monitoring drill strings

A device and method for subterranean operations comprising a latch adapted to be coupled with a fingerboard of a drilling rig, the fingerboard including at least two fingers, wherein: the latch is selectively moveable between an open configuration and a closed configuration, the latch is adapted to selectively permit entrance of a first tubular into a tubular storage area between the at least two fingers when the latch is in the open configuration, and selectively maintain the first tubular in the tubular storage area when the latch is in the closed configuration, and the latch is spaced apart from the fingerboard.

Apparatus and method for securing tubulars on a drilling rig

A drilling assembly that can include a first mast, a second mast, a water table coupled between the first and second masts, and a plurality of sheaves coupled to the water table and adapted to translate along a plane oriented generally perpendicular to a height of at least one of the first or second mast. A drilling assembly that can include a mast having a generally C-shaped support structure, as viewed from a top view, and an opening disposed within the support structure, where the mast is disposed adjacent to a wellbore, and where the opening is adapted to permit passage of tubulars from an external position to the wellbore through the mast. A drilling assembly that can include a mast, a water table coupled to the mast, and a drawworks disposed adjacent to the mast, where the drawworks is adapted to laterally translate relative to the mast.

Drilling assemblies

A pipe handler comprising a body defining an axis; a slide adapted to translate in a direction parallel with the axis; and a plurality of grippers, wherein at least one of the plurality of grippers is adapted to translate in a direction generally perpendicular to the axis upon translation of the slide and selectively contact a threaded interface of an inner surface of a tubular.

Pipe handler

An apparatus for moving a tubular may include a column vertically extending from a drill floor, the column defining an axis; a lower carriage connected to the column and configured to carry the column along the drill floor; an upper arm assembly movable along the column, the upper arm assembly being configured to connect with a tubular; and a lower arm assembly having a lower gripper head configured to attach to the tubular, the lower arm assembly being movable to displace the lower gripper head between a position on a first side of the axis and a position on a second side of the axis.

Pipe handling column racker with retractable arm

Systems and methods for operating a land-based drilling rig apparatus include a dual-activity mast having a first fingerboard supported by the mast and disposed on a first side of the well center bore, and include a second fingerboard supported by the mast and disposed on a second side of the well center bore. The first and second fingerboards may permit simultaneous operations, such as tripping and casing stand assembly.

Growing community of inventors

Houston, TX, United States of America

Christopher Magnuson