The invention discloses an induced drilling method for inertial constraint implicated motion, which is characterized by comprising a motion step of separating weight on bit and torque. The induced drilling method of inertial constraint implicating motion comprises the following steps: step 1, model selection of induced drilling; step 2, potential energy storage of induced drilling, wherein step 2 includes: I, uniform cutting induced drilling under a steady condition; II, distribution of induced drilling shock wave propagation under a transient condition; III, potential energy release of torsion spring in induced drilling under the transient condition; IV, constrained buffer for induced drilling under transient conditions; and V, potential energy compensation for induced drilling under transient conditions. The invention also discloses an inertia constraint induced drilling device accompanying the PDC bit.

A transmission device including a body, an input member extending along the body, and having a rotational axis, a gear assembly connected to the input member, having an inner gear, one or more intermediate gears engaged with the inner gear; and an outer gear engaged with one or more intermediate gears, wherein in a first position the gear assembly is configured to rotate at substantially the same rate as the input member and axial movement of at least one component to a second position, in a direction substantially parallel to the axis of rotation, allows the gear assembly to provide to an output member a different output rate relative to the input member, and an actuator movable between a first position at which the gear assembly moves to its first position and a second position at which the gear assembly moves to its second position, the actuator moves under hydraulic pressure.

The present invention discloses a power drive system for a fracturing pump, the power drive system for the fracturing pump is driven by a turbine engine, which can use 100% natural gas as a fuel to replace the diesel consumption in diesel engine drive, lowering fuel costs for customers; the turbine engine itself has the advantages of small volume and light weight, greatly decreasing the volume and weight of the power drive system for the fracturing pump; the turbine engine is directly connected to an input end of the reduction gearbox of the fracturing pump, thus simplifying the transmission device between the fracturing pump and the turbine engine, that is, a transmission shaft or a coupling is omitted, greatly shortening the total length of the power drive system for the fracturing pump; in the present invention, the turbine engine is used as the power source, the transmission device is the reduction gearbox equipped on the fracturing pump itself, and the fracturing pump is the actuating element, so that the power drive system for the fracturing pump has a simple structure and is easy for maintenance.

The present invention discloses a drilling speed increasing device driven by a downhole motor for generating shock vibration. The device uses the rotational energy of a screw motor as power to drive a lower vibration starter to rotate. Vibration starting steel balls have the function of reducing friction in the interior. During axial reciprocating motion of the upper vibration starter, a spring matched with the upper vibration starter is periodically compressed to generate spring energy. The spring energy reacts on the lower vibration starter and a main shaft connected with a drill bit, so as to periodically provide drilling pressure for the drill bit. Periodic motion of the upper vibration starter and the spring produces periodic axial vibration on the tool.

A radial bearing for transmitting a radial load, including a first radial bearing component having an inner surface defining a bore and a second radial bearing component received within the bore of the first radial bearing component and having an outer surface. The first radial bearing component includes a plurality of first component wear resistant inserts arranged and mounted on the inner surface. The second radial bearing component includes a second component wear resistant coating on at least a portion of the outer surface. The first radial bearing component and the second radial bearing component interact to transmit the radial load between the first radial bearing component and the second radial bearing component.

A system for locking a bearing assembly to a rotating control device (RCD) housing is provided. The RCD housing can be coupled to a blowout preventer, and the bearing assembly can be received within the housing, and can comprise a stationary bearing housing having a perimeter channel. A plurality of locking block assemblies are each supported by the housing and are operable between a locked position and an unlocked position. Each locking block assembly comprises a movable block configured to interface with the perimeter channel when in the locked position, and at least one elastic component is situated between the housing and the movable block. The at least one elastic component is configured to automatically bias the movable block in the locked position. Upon supplying fluid pressure via a valve device, the movable block moves to the unlocked position and the at least one elastic component compresses to facilitate removal of the bearing assembly from the RCD housing. Associated systems and methods are provided.

The present disclosure is directed to improved downhole motor designs. In one illustrative embodiment, primary and secondary thrust bearings that are maintained in position by other structural components of the motor without compressive loading of the entire bearing assembly are positioned inside the motor housing for protection from cuttings and debris in the drilling fluid. In some illustrative embodiments, a drive train that features at least one multi-part sectional flex joint may allow for a shortened flex shaft while sufficiently converting eccentric forces from the power source to rotation of the mandrel.

Embodiments of a downhole drilling assembly generally include rotatable upper and lower drilling assemblies, and a drill bit, wherein an upper drilling assembly contains a mud motor adapted for clockwise stator rotation and counter-clockwise rotor rotation, whereby a lower drilling assembly is rotatable in the opposite direction of the upper drilling assembly or maintainable in a non-rotating state. The apparatus further includes sensors for continuously transmitting information relating thereto to the surface. Embodiments of a downhole clutch joint generally include a box end sub, a pin end sub, and a ratchet sleeve system containing a clutch joint mechanism, wherein the downhole clutch joint prevents rotation of a downhole drilling assembly in an undesired direction. Method embodiments generally include continuously measuring physical properties and/or drilling parameters, continuously transmitting information relating thereto, and controlling lower drilling assembly rotation in a non-rotating state or in the opposite direction of an upper drilling assembly.

Embodiments of the present disclosure are generally related to a method and apparatus for performing operations in subterranean wellbores. More specifically, the present disclosure provides a novel downhole tractor for use in a wellbore. The tractor includes a body and a plurality of wheels. The wheels are configured to convert rotation of the body into linear motion along the wellbore. In one embodiment, the tractor is hydraulically driven. Additionally, or alternatively, the tractor may be electrically driven. Optionally, rotation of a string of pipe interconnected to the tractor drives the tractor.

A lubrication system for a plunger/packing set of a fluid end has a lubricating fluid reservoir, a pump cooperative with the lubricating fluid reservoir so as to pump a lubricating fluid from the lubricating fluid reservoir toward the plunger/packing set, a primary pressure transducer cooperative with the pump so as to measure a pressure of the lubricating fluid exiting the fluid pump, a secondary pressure transducer cooperative with the fluid end so as to measure a pressure of the lubricating fluid exiting the plunger/packing set, and a controller connected to the second pressure transducer so as to obtain a representation of the pressure measured by the secondary pressure transducer.