The present application discloses a push type rotary guide drilling system. The push type rotary guide drilling system includes: a drill bit and a rotating shaft, the rotating shaft including an upper rotating shaft and a lower rotating shaft; a steering portion, sleeving an outer side of the rotating shaft; a push assembly, including a plurality of push pieces spaced along a circumferential direction of the steering portion; a transmission device, including a transmission mechanism for driving the push pieces to extend out of the steering portion, the transmission mechanism including a driving electromagnetic gear arranged on the upper rotating shaft and a driven electromagnetic gear arranged on the steering portion and further including a motion conversion unit converting rotary motion of the driven electromagnetic gear into linear motion of the push pieces; and a control unit, configured to modulate a magnetic field to make the driving electromagnetic gear and the driven electromagnetic gear realize linkage through magnetic coupling and make the driving electromagnetic gear and the driven electromagnetic gear operate in an adjustable transmission ratio. According to the system in the present application, it is unnecessary for the steering portion to be provided with a circuit component, a conductive socket and the like, thereby simplifying a structure of the steering portion, effectively shortening a size of the steering portion, improving the flexibility of underground feed motion and reducing cost.

A drilling machine for a wellbore is provided. The drilling machine may include a dynamic lateral pad that is movable between an extended and retracted position. In the extended position, the pad moves the drill bit in a direction for drilling. The drilling machine may include a dynamic lateral cutter that is movable between an extended and retracted position. In at least the extended position, the cutter engages the wellbore and removes formation. The drilling machine may include a monolithic or integral drill bit/drive shaft to reduce the distance between a positive displacement motor and a distal end of the monolithic or integral drill bit/drive shaft. The drilling machine may include separate cutting structures that have different rotational speeds and can further utilize the integral drill bit/drift shaft and/or a bent housing that generates an off-axis rotation which helps optimize the formation removal in the center area of the wellbore.

A drill bit subsystem can include a drill bit, a processor, and a non-transitory computer-readable medium for storing instructions and for being positioned downhole with the drill bit. The instructions of the non-transitory computer-readable medium can include a machine-teachable module and a control module that are executable by the processor. The machine-teachable module can receive depth data and rate of drill bit penetration from one or more sensors in a drilling operation, and determine an estimated lithology of a formation at which the drill bit subsystem is located. The control module can use the estimated lithology to determine an updated location of the drill bit subsystem, and control a direction of the drill bit using the updated location and a drill plan.

A drill bit for removing subterranean formation material in a borehole comprises a bit body comprising a longitudinal axis, a plurality of blades extending radially outward from the longitudinal axis along a face region of the bit body and extending axially along a gauge region of the bit body, and an insert coupled to at least one blade in the gauge region. The insert comprises an elongated body having an upper surface, a lower surface, and a longitudinal axis extending centrally therethrough and intersecting the upper and lower surfaces. The upper surface comprises a bearing surface for supporting for the drill bit and providing a surface on which the subterranean formation being drilled rubs against the insert without exceeding the compressive strength of the selected formation. The insert is coupled to the blade such that the upper surface thereof extends radially beyond an outer surface of the blade and the lower surface thereof extends radially below the outer surface of the blade.

Measurement of the inclination and azimuthal direction of a borehole extending beneath an obstacle, such as a body of water, which utilizes magnetic and gravity sensors at the drill bit of a borehole being drilled. Embodiments of the present invention determine and remove remanent field components and the effects of ferromagnetic permeability prior to and during drilling of the borehole

A new horizontal directional drilling (HDD) bit comprising a bit body is provided with illustrated embodiments including a flat bit design and a cobble bit design. Cutter teeth may be cut (e.g. formed or machined) into the base steel material of the bit body. Additionally, a broken edge profile may be generated to avoid sharp corners for better receipt of hard facing material such as laser clad beads that may be applied in higher wear regions.

The present application provides an executing mechanism for a rotary guide device and the rotary guide device. The executing mechanism includes a driving valve core, a driven valve core, a first cavity, a second cavity and a high-pressure slurry driving channel, wherein the first cavity includes a first low-pressure port communicating with low-pressure slurry; the first cavity further includes a first high-pressure port communicating with high-pressure slurry; the driving valve core optionally opens and closes the first low-pressure port and the first high-pressure port to adjust a pressure in the first cavity; two sides of the driven valve core are respectively adjacent to the first cavity and the second cavity; the driven valve core moves in response to a pressure difference between the first cavity and the second cavity; the driven valve core is connected to the high-pressure slurry driving channel; and the high-pressure slurry driving channel switches between an open state and a close state in response to movement of the driven valve core. The executing mechanism according to the present application can effectively reduce the power consumption of a system on the basis of increasing response speed through the linkage action of the driving valve core and the driven valve core.

A system for controlling operations of a drill in a well environment. The system comprises a predictive engine, a ML engine, a controller, and a secure, distributed storage network. The predictive engine receives a variables associated with surface and sub-surface sensors and predicts an earth model based on the variables, predictor variable(s), outcome variable(s), and relationships between the predictor variable(s) and the outcome variable(s). The predictive engine is also configured to predict a drill path(s) ahead of the drill based on using stochastic modeling, an outcome variable(s), the predicted earth model, and a drilling model(s). The controller is configured to generate a system response(s) based on the predicted drill path(s) and a current state of the drill. The ML engine stores the earth model, the drill path(s), and the variables in the distributed storage network, trains data, and creates the drilling model(s).

A method for constructing a wellbore includes drilling a wellbore along a trajectory using a bit; reaming the diameter of a portion of the drilled wellbore to enlarge a portion of the wellbore; and altering the trajectory of the bit by applying a lateral force to the enlarged diameter wellbore. Reaming the diameter of the portion of the drilled wellbore increases the dogleg of the wellbore.

A downhole drilling apparatus may comprise a rotatable body with fixed cutting elements protruding from an exterior thereof. To form a subterranean borehole, the fixed cutting elements, spaced at a constant radius from a rotational axis of the body, may degrade an earthen formation as the body rotates. The body may also have a rotatable cutting element protruding from its exterior. To remove material from an interior wall of the borehole, the rotatable cutting element may be positioned in a first rotational orientation wherein it extends radially beyond the constant radius of the fixed cutting elements. An amount of material being removed may be altered by rotating the rotatable cutting element into a second rotational orientation wherein it remains radially within the constant radius.