Schlumberger Technology Corporation

Services Petroliers Schlumberger

Schlumberger Holdings Limited

Cedric Perrin

Christopher C Bogath

Geoffrey Charles Downton

Spyro J Kotsonis

Eric Lavrut

Henri Denoix

Oleg Polyntsev

Michael Pearce

Didier Fouillou

Bertrand Lacour

Paul Crerar

A stabilizer assembly comprising a tubular member, a stabilizer sleeve slidably disposed about the tubular member, and a plurality of round members each disposed between the stabilizer sleeve and the tubular member. The stabilizer sleeve may comprise a plurality of round cavities each located in an inner surface of the stabilizer sleeve. Each of the plurality of round members may be disposed within a corresponding one of the plurality of round cavities. The stabilizer assembly may be coupled between opposing first and second portions of a downhole drill string.

Stabilizer assembly

A technique facilitates drilling of wellbores or other types of bore holes in a variety of applications. A steerable system is designed with a main shaft coupled to a drill bit shaft by a universal joint to provide steering functionality. A sensor system is mounted on the steerable system and comprises at least one sensor positioned to measure desired parameters, such as weight on bit and/or torque on bit parameters during drilling.

Instrumented drilling system

A technique facilitates drilling of wellbores or other types of bore holes in a variety of applications. A steerable system or other well tool is designed with a plurality of actuators which are positioned to provide controlled steering during a drilling operation. Each actuator includes at least one loose element or ball slidably mounted in a corresponding sleeve. Pressurized fluid is used to provide controlled movement of the elements along the corresponding sleeves of the actuators. The controlled movement of the elements assists in the provision of steering or other control over the well tool during the drilling operation.

Directional drilling system

A pressure compensated sensor assembly for determining loads near a drill bit may include a body member having an inner diameter and an outer diameter, a sleeve member having an inner diameter and an outer diameter, the sleeve member being coupled to the body member, a first gap having a thickness and a length dimension formed between the body member and the sleeve member, and one or more sensors coupled to the sleeve member. The one or more sensors may measure axial and torsional loads on the sleeve member without measuring parasitic strain induced on the body member.

Dry pressure compensated sensor

A drilling system, comprising a non-rotating conveyance system; a tool connected to the non-rotating conveyance system and including anchors by which the tool can be anchored in position when located in a borehole; a drill bit connected to the tool; a motor for rotating the drill bit; and a directional control system interposed between the tool and the drill bit; wherein, in use, whit the drilling system located in a borehole, the directional control system can be operates so as to displace the drill bit away from the axis of the borehole.

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Forcelles Saint Gorgon, France

Cedric Perrin