A system including an elevator to move a tubular, the elevator including two or more remotely operable latches that can configure the elevator to handle various tubular diameters. A portion of the latches can be laterally offset from each other and another portion can overlap adjacent latches. The elevator can be Atmosphere Explosible (ATEX) certified or International Electrotechnical Commission for Explosive Atmospheres (IECEx) certified according to explosive (EX) Zone 1 requirements with an electronics enclosure contained within a sealed chamber. The elevator can be rotated greater than 90 degrees relative to a pair of links that support the elevator. The elevator can use rotary actuators to operate the latches and rotate the housing of the elevator.

A system including an elevator to move a tubular, the elevator including two or more remotely operable latches that can configure the elevator to handle various tubular diameters. A portion of the latches can be laterally offset from each other and another portion can overlap adjacent latches. The elevator can be Atmosphere Explosible (ATEX) certified or International Electrotechnical Commission for Explosive Atmospheres (IECEx) certified according to explosive (EX) Zone 1 requirements with an electronics enclosure contained within a sealed chamber. The elevator can be rotated greater than 90 degrees relative to a pair of links that support the elevator. The elevator can use rotary actuators to operate the latches and rotate the housing of the elevator.

A polished rod elevator has a top lift platform defining a polished rod passage and a mouth to laterally receive a polished rod into the polished rod passage; a plurality of linear actuators depending below the top lift platform and radially spaced from an axis of the polished rod passage to define a production tree receiving gap; and a plurality of arcuate wellhead flange mounting base plates connected to base ends of the plurality of linear actuators. Related methods of use and kits are discussed.

A polished rod elevator has a top lift platform defining a polished rod passage and a mouth to laterally receive a polished rod into the polished rod passage; a plurality of linear actuators depending below the top lift platform and radially spaced from an axis of the polished rod passage to define a production tree receiving gap; and a plurality of arcuate wellhead flange mounting base plates connected to base ends of the plurality of linear actuators. Related methods of use and kits are discussed.

A drilling rig is adapted to perform drilling and/or other wellbore related activities. The drilling rig includes a drilling tower, a drill floor with a well center, a slip device arranged at the well center, a tubulars connection makeup and breaking device near the well center, and a top drive system. The top drive system includes a traveling carriage that is vertically mobile along one or more vertical rails of the drilling tower by a vertical motion drive. The system also includes a top drive unit supported by said carriage and including a top drive motor and a rotary torque output member. The system further includes a tripping operation elevator that is adapted to be engageable with a drilling tubulars string or drilling tubulars stand, e.g. with the top end thereof, in order to perform tripping operations. The top drive unit and the tripping operation elevator are each mobile relative to the traveling carriage, and wherein the top drive system is provided with one or more actuators adapted to cause said relative motion of the top drive unit and of the tripping operation elevator so as to provide a drilling mode and a tripping mode.

A drilling rig is adapted to perform drilling and/or other wellbore related activities. The drilling rig includes a drilling tower, a drill floor with a well center, a slip device arranged at the well center, a tubulars connection makeup and breaking device near the well center, and a top drive system. The top drive system includes a traveling carriage that is vertically mobile along one or more vertical rails of the drilling tower by a vertical motion drive. The system also includes a top drive unit supported by said carriage and including a top drive motor and a rotary torque output member. The system further includes a tripping operation elevator that is adapted to be engageable with a drilling tubulars string or drilling tubulars stand, e.g. with the top end thereof, in order to perform tripping operations. The top drive unit and the tripping operation elevator are each mobile relative to the traveling carriage, and wherein the top drive system is provided with one or more actuators adapted to cause said relative motion of the top drive unit and of the tripping operation elevator so as to provide a drilling mode and a tripping mode.

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.

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.

An improved external trap apparatus 570 and a method for safely controlling drilling tool string components during oil field drilling operations includes a collar clamp 72 affixed to a drilling tool string lubricator 80 and configured with laterally spaced first and second vertical rails 120, 122 depending therefrom. Lubricator 80 also carries a lubricator clamp assembly 572 which is affixed to Lubricator 80 with inward clamping surfaces defining a non-circular or slightly elliptical central bore 574. Laterally spaced first and second vertical rails 120, 122 are configured to support a reinforced catcher plate assembly 164 carrying a tool-end receiving funnel receptacle 202 and first and second energy absorbing crush cylinders 160, 162. When the drill string 82 is raised or withdrawn from the well 28, the funnel receptacle 202 can be rotated into coaxial alignment to catch the drill string's end or downhole tool, in the event of an inadvertent loss of control of the drill string 82. Further disclosed is a sleeve/guide assembly to work in conjunction with the lubricator collar clamp, catcher plates, and crush cylinders.

An improved external trap apparatus 570 and a method for safely controlling drilling tool string components during oil field drilling operations includes a collar clamp 72 affixed to a drilling tool string lubricator 80 and configured with laterally spaced first and second vertical rails 120, 122 depending therefrom. Lubricator 80 also carries a lubricator clamp assembly 572 which is affixed to Lubricator 80 with inward clamping surfaces defining a non-circular or slightly elliptical central bore 574. Laterally spaced first and second vertical rails 120, 122 are configured to support a reinforced catcher plate assembly 164 carrying a tool-end receiving funnel receptacle 202 and first and second energy absorbing crush cylinders 160, 162. When the drill string 82 is raised or withdrawn from the well 28, the funnel receptacle 202 can be rotated into coaxial alignment to catch the drill string's end or downhole tool, in the event of an inadvertent loss of control of the drill string 82. Further disclosed is a sleeve/guide assembly to work in conjunction with the lubricator collar clamp, catcher plates, and crush cylinders.