Nabors Lux 2 Sarl

Nabors Lux 2

Andrew Gorrara

Ola Stengel

Siamak Shahipassand

Stig Bakke

Patrick Reiners

Peter James Clark

Knut-arve Johnsen

Tore Grenasberg

A harmonic gear drive includes an input shaft and an output shaft. The input shaft is mechanically coupled to a wave generator which has a varying diameter. The wave generator is positioned within a flex spline which includes external teeth. The external teeth of the flex spline engage with internal teeth of a fixed spline and an output spline when the major diameter of the wave generator is aligned therewith. The output spline has a different number of teeth from the input spline such that, as the wave generator is rotated and the flex spline rotates, the output spline is rotated relative to the fixed spline.

Harmonic gear drive

An antirotation stabilizer may include one or more antirotation pads extending from a stabilizer body. Each antirotation pad may be positioned at least partially within a recess formed in the stabilizer body. Each antirotation pad may be coupled to a torsion bar. The torsion bar may couple between the antirotation pad and the stabilizer body and may be under torsional loading such that the antirotation pad is extended from the stabilizer body. The antirotation stabilizer may include one or more rollers.

Device to resist rotational forces while drilling a borehole

A method of drilling a wellbore is described using a BHA including an RSS that comprises an adjustment mechanism movable between first and second configurations to alter a drilling direction of the BHA, BHA sensor(s), and a controller. The method includes drilling, using the BHA, the wellbore with the adjustment mechanism in the first configuration; receiving, by the first controller, real-time data including inclination and azimuth angle data from the BHA sensor(s); determining, by the first controller and based on the real-time data, a relationship between an actual measurement and a target measurement that is associated with a target well path; automatically moving, by the first controller and in response to the determination of the relationship, the adjustment mechanism from the first to the second configuration; and drilling, using the BHA, the wellbore while the adjustment mechanism is in the second configuration.

Automated steering of a drilling system using a smart bottom hole assembly

A method of surveying a wellbore continuously during drilling. The method includes using a drill string with a non-rotating sub-assembly. The non-rotating sub-assembly comprises three accelerometers oriented orthogonally to each other and three directional sensors also oriented orthogonally to each other. Sample measurements from the six sensors are used to calculate the attitude of the wellbore and more specifically used to create an accurate survey of wellbores within a subterranean formation while the drill string is drilling.

Method of providing continuous survey data while drilling

A downhole drilling device () may include a drill bit rotatable via a drill string (); a guiding device () provided between said drill bit and said drill string (), said guiding device () being connected to and operable independently from said drill string (); and a power source () for powering said guiding device (). The downhole drilling device () may include an inductive coupler (') having a primary side () and a secondary side (), said inductive coupler (&#x2032;) being adapted to transfer power from said power source (), connected to the primary side () of said inductive coupler (&#x2032;), to said guiding device (), connected to the secondary side () of said inductive coupler (&#x2032;).

Downhole drilling device

The present disclosure provides for a sensor assembly for use in a wellbore. The sensor assembly may include a rotating sub, the rotating sub coupled to a drill string and a drive shaft, the drive shaft coupled to the rotating sub. The sensor assembly may also include a nonrotating sub where the nonrotating sub is positioned generally around the drive shaft and shaft and rotatably coupled to the drive shaft and the rotating sub. The nonrotating sub may include an outer cover. The outer cover is generally tubular. The nonrotating sub may further include a sensor collar. The sensor collar is positioned within and coupled to the outer cover. The sensor collar may be coupled to the outer cover by a drive assembly. The drive assembly may include a motor adapted to rotate the sensor collar relative to the outer cover. The nonrotating sub also includes at least one positioning sensor coupled to the sensor collar.

Method and apparatus for orienting a downhole tool

A message to be sent from a downhole tool in a wellbore is modulated into a data uplink signal of pressure variations in the drill string. The pressure variations are generated by varying the torque on the rotor of the generator by varying the electric load on the generator. The pressure variation sequence of the data uplink signal may be selected from a look up table of known sequences. The message may be received by a surface receiver using one or more pressure sensors. The message may be demodulated from the detected pressure data using digital and analog signal processing. The frequency of the data uplink signal may be selected based in part on detected noise in the wellbore. The data uplink signal may be modulated using a spread spectrum protocol.

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Algard, Norway

Andrew Gorrara