Systems and methods determine friction in a borehole during drilling operations. A drilling system applies oscillatory angular movement at the top of a drill string in a wellbore during drilling by the drilling system, and measures a torque applied to the drill string and an angular position of the drill string. Based on the measured torque and the measured angular position, the drilling system computes a friction between the borehole and the drill string. This can be repeated during drilling of the wellbore to determine multiple friction values, corresponding to various depths of the borehole. Based on the computed friction, the drilling system can perform one or more actions resulting in modified drilling operation. The systems and methods also include oscillating a casing in the borehole, measuring the torque and angular position of the casing, and determining a friction value, which can be repeated to develop a wellbore friction profile.

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 method may include communicating a command into a wellbore from the surface. The method may include determining a command to be sent to a downhole tool, and translating the command into a message, the message including a sequence of codes. The method may include rotating the drill string substantially at the set point RPM for a predetermined duration and measuring the rotation rate of the drill string. The method may include identifying the received set point RPM and rotating the drill string consistent with a first code value of a first code of the message as encoded. The method may also include decoding the first code and rotating the drill string consistent with a second code value of a second code of the message as encoded. The method may also include decoding the second code, identifying the command from at least one of the decoded first and second code and executing the command.

A method may include communicating a command into a wellbore from the surface. The method may include determining a command to be sent to a downhole tool, and translating the command into a message, the message including a sequence of codes. The method may include rotating the drill string substantially at the set point RPM for a predetermined duration and measuring the rotation rate of the drill string. The method may include identifying the received set point RPM and rotating the drill string consistent with a first code value of a first code of the message as encoded. The method may also include decoding the first code and rotating the drill string consistent with a second code value of a second code of the message as encoded. The method may also include decoding the second code, identifying the command from at least one of the decoded first and second code and executing the command.

A system for drilling a subterranean borehole. In an embodiment, the system includes a mast, and a pipe rotator coupled to the mast. The pipe rotator includes a stem that is configured to be coupled to an end of a drillstring and a motor that is configured to rotate the stem. In addition, the system includes a guide beam coupled to the mast. The guide beam includes a longitudinal axis and is configured to guide vertical motion of the pipe rotator. The guide beam includes a plurality of elongate sections configured to be generally aligned along the longitudinal axis. In addition, the guide beam includes a plurality of coupling assemblies configured to interconnect the plurality of elongate sections and align the plurality elongate sections along the longitudinal axis.

A system for drilling a subterranean borehole. In an embodiment, the system includes a mast, and a pipe rotator coupled to the mast. The pipe rotator includes a stem that is configured to be coupled to an end of a drillstring and a motor that is configured to rotate the stem. In addition, the system includes a guide beam coupled to the mast. The guide beam includes a longitudinal axis and is configured to guide vertical motion of the pipe rotator. The guide beam includes a plurality of elongate sections configured to be generally aligned along the longitudinal axis. In addition, the guide beam includes a plurality of coupling assemblies configured to interconnect the plurality of elongate sections and align the plurality elongate sections along the longitudinal axis.

A method sequence for handling tubulars into or out of a wellbore, the method comprising: moving a tubular string into or out of a wellbore via a top drive; moving tubular stands to and from a setback position and a stand handoff position via a transfer bridge racker and a setback guide arm; moving tubular stands to and from the stand handoff position and a well center position via a tubular delivery arm and a lower stabilizing arm; building stands and breaking down stands offline via a mousehole and operating a roughneck on joints between the tubular stands and the tubular string.

The present invention relates to an attachment for drilling and/or foundation work, in particular a casing oscillator or casing rotator, comprising a receiving apparatus for clamping at least one pipe and a drive for generating a rotational movement of the clamped pipe, wherein the attachment comprises at least one integral control unit for an independent carrying out of control functions of the attachment.

The present invention relates to an attachment for drilling and/or foundation work, in particular a casing oscillator or casing rotator, comprising a receiving apparatus for clamping at least one pipe and a drive for generating a rotational movement of the clamped pipe, wherein the attachment comprises at least one integral control unit for an independent carrying out of control functions of the attachment.

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.