Abstract: A drilling system includes a hull, an open cantilever mounted on the hull, a blowout preventer stack supported by the open cantilever, a plurality of beams installed horizontally and supported on the open cantilever, and a conductor tension unit cage including a conductor tension unit. The conductor tension unit cage is installed below the blowout preventer stack, and is supported by the plurality of beams. The conductor tension unit is configured to apply tension to a conductor pipe extending through the blowout preventer stack when the open cantilever is skidded out from the hull.

Abstract: A hydraulic workover unit includes a work platform and a jacking table assembly disposed adjacent to the work platform. The jacking table assembly includes a jacking table and multiple adjustable legs, and each adjustable leg of the multiple adjustable legs includes multiple telescopic cylinders that provide variable jacking capacity to adjust a position of the jacking table relative to the work platform.

Abstract: An energy conversion system includes a power takeoff system, a fin connected to the power takeoff system, and a control system on board the fin. The fin is submerged below a surface of the sea, and the fin is configured to use subsurface wave motions to extract energy.

Abstract: A hoisting system of this disclosure includes a drawworks, a crown block or a compensator, a traveling block and at least one sheave assembly connected to the crown block or compensator in “Low Load/High Speed” mode and connected to the traveling block in “High Load/Low Speed” mode. A method to lift a load using a hoisting system of this disclosure uses a drawworks, a crown block or a compensator, a traveling block and at least one sheave assembly connected to the crown block or compensator in “Low Load/High Speed” mode and connected to the traveling block in “High Load/Low Speed” mode.

Abstract: A device for handling a tubular member includes a gripping assembly configured to grip the tubular member. The gripping assembly includes a first arm and a second arm, which are configured to pivot between an open position and a closed position. The device also includes a first plurality of rollers coupled to the first arm and a second plurality of rollers coupled to the second arm. The first plurality of rollers and the second plurality of rollers are configured to grip the tubular member at different locations around a circumference of the tubular member when the first arm and the second arm are in the closed position, and the first plurality of rollers and the second plurality of rollers are configured to rotate the tubular member while the tubular member is being gripped by the gripping assembly.

Abstract: A device for handling a tubular member includes a gripping assembly configured to grip the tubular member. The gripping assembly includes a first arm and a second arm, which are configured to pivot between an open position and a closed position. The device also includes a first plurality of rollers coupled to the first arm and a second plurality of rollers coupled to the second arm. The first plurality of rollers and the second plurality of rollers are configured to grip the tubular member at different locations around a circumference of the tubular member when the first arm and the second arm are in the closed position, and the first plurality of rollers and the second plurality of rollers are configured to rotate the tubular member while the tubular member is being gripped by the gripping assembly.

Abstract: A system for handling a tubular member includes a gripping assembly configured to grip the tubular member. The system also includes a horizontal actuator configured to move the gripping assembly and the tubular member horizontally between a rack and alignment with a wellbore while the tubular member is gripped by the gripping assembly. The system also includes a vertical actuator coupled to the gripping assembly, the horizontal actuator, or both. The vertical actuator is configured to move the gripping assembly and the tubular member vertically while the tubular member is gripped by the gripping assembly and in alignment with the wellbore. The system also includes a rotating assembly coupled to the gripping assembly and configured to rotate the tubular member while the tubular member is gripped by the gripping assembly and in alignment with the wellbore.

Abstract: A vertical pipe handling system comprising a bellyboard with at least one automated guide for leading tubulars between the fingers of the bellyboard. A method to move a tubular on or above a rig floor comprising automatically moving the tubular with a racking system comprising a bellyboard with at least one automated guide for leading tubulars between the fingers of the bellyboard.

Abstract: A fingerboard has a first portion configured to receive a first pipe and a second portion configured to receive a second pipe. The fingerboard includes a fixed section and a movable section, each having fingers and latches that define a pipe receiving space. The pipe receiving space of the fixed section is sized for drill pipe while the pipe receiving space of the movable section may be the same size as the pipe receiving space of the fixed section or a different size than the pipe receiving space of the fixed section. The movable section has a first and a second pipe receiving spaces. The second pipe receiving space may be larger than the first pipe receiving space. A hinge moves the movable section to selectively locate the first pipe receiving portion and the second pipe receiving portion adjacent to the fixed section. A mover, such as a hydraulic cylinder, is affixed to the movable section.

Abstract: A system for handling a tubular member includes a gripping assembly configured to grip the tubular member. The system also includes a horizontal actuator configured to move the gripping assembly and the tubular member horizontally between a rack and alignment with a wellbore while the tubular member is gripped by the gripping assembly. The system also includes a vertical actuator coupled to the gripping assembly, the horizontal actuator, or both. The vertical actuator is configured to move the gripping assembly and the tubular member vertically while the tubular member is gripped by the gripping assembly and in alignment with the wellbore. The system also includes a rotating assembly coupled to the gripping assembly and configured to rotate the tubular member while the tubular member is gripped by the gripping assembly and in alignment with the wellbore.

Abstract: Embodiments of a top-mounted hoisting system include a single-layer winch drum located at an uppermost end of a derrick or drilling mast, a drill string handling tool, and one or more drill lines extending from the single layer winch drum to the drill string handling tool. The drill string handling tool may be a top drive. When the drill line is connected directly to the lifted load, the drill line experiences far less load cycles than when the line runs through crown and travelling blocks. If the drum diameter is large enough, cut-and-slip operations may be eliminated, and the drill line may be replaced at longer time intervals. Embodiments provide for lower weight and may provide lower cost as a result. The top-mounted drum does not take up any space on the drill floor and less total length of drill line is also required than if the drum was floor-mounted.

Abstract: A hoisting system of this disclosure includes a drawworks, a crown block or a compensator, a traveling block and at least one sheave assembly connected to the crown block or compensator in “Low Load/High Speed” mode and connected to the traveling block in “High Load/Low Speed” mode. A method to lift a load using a hoisting system of this disclosure uses a drawworks, a crown block or a compensator, a traveling block and at least one sheave assembly connected to the crown block or compensator in “Low Load/High Speed” mode and connected to the traveling block in “High Load/Low Speed” mode.

Abstract: Embodiments of a top-mounted hoisting system include a single-layer winch drum located at an uppermost end of a derrick or drilling mast, a drill string handling tool, and one or more drill lines extending from the single layer winch drum to the drill string handling tool. The drill string handling tool may be a top drive. When the drill line is connected directly to the lifted load, the drill line experiences far less load cycles than when the line runs through crown and traveling blocks. If the drum diameter is large enough, cut-and-slip operations may be eliminated, and the drill line may be replaced at longer time intervals. Embodiments provide for lower weight and may provide lower cost as a result. The top-mounted drum does not take up any space on the drill floor and less total length of drill line is also required than if the drum was floor-mounted.

Abstract: A fingerboard has a first portion configured to receive a first pipe and a second portion configured to receive a second pipe. The fingerboard includes a fixed section and a movable section, each having fingers and latches that define a pipe receiving space. The pipe receiving space of the fixed section is sized for drill pipe while the pipe receiving space of the movable section may be the same size as the pipe receiving space of the fixed section or a different size than the pipe receiving space of the fixed section. The movable section has a first and a second pipe receiving spaces. The second pipe receiving space may be larger than the first pipe receiving space. A hinge moves the movable section to selectively locate the first pipe receiving portion and the second pipe receiving portion adjacent to the fixed section. A mover, such as a hydraulic cylinder, is affixed to the movable section.

Abstract: A vertical pipe handling system comprising a bellyboard with at least one automated guide for leading tubulars between the fingers of the bellyboard. A method to move a tubular on or above a rig floor comprising automatically moving the tubular with a racking system comprising a bellyboard with at least one automated guide for leading tubulars between the fingers of the bellyboard.

Abstract: Various hoisting systems with heave compensation are provided. In one embodiment, an apparatus includes a hoisting system having a crown block and a drawworks. The drawworks includes a rotatable drum for reeling in and reeling out a hoisting line that is wound on the rotatable drum and reeved over the crown block. The hoisting system includes active heave control at the drawworks and a passive heave compensation system. Additional systems, devices, and methods are also disclosed.

Abstract: Various hoisting systems with heave compensation are provided. In one embodiment, an apparatus includes a hoisting system having a crown block and a drawworks. The drawworks includes a rotatable drum for reeling in and reeling out a hoisting line that is wound on the rotatable drum and reeved over the crown block. The hoisting system includes active heave control at the drawworks and a passive heave compensation system. Additional systems, devices, and methods are also disclosed.

Abstract: A pipe handling assembly in connection with an oil derrick comprises two pivotable and vertically movable arms having a grab head in the form of a U-shaped claw intended for transporting a stand of pipe, a drill collar or the like from the well center to a rack, and vice versa. The grab head on one arm, preferably the lower arm, is subdivided vertically into a lower U-shaped member fixedly connected to the arm via a housing and an upper U-shaped member rotatably relative to the lower member and provided with locking means for retaining the pipe, drill collar or the like. The two members are provided with rotation means intended to bring the upper, rotatable member from an arbitrary angular position into a locked position in which its claw aperture is in alignment with the claw aperture of the lower member.