Baker Hughes Corporation

Baker Hughes, a Ge Compnay, LLC

Thorsten Schwefe

Rudolf Carl Pessier

Chad J Beuershausen

Dan Raz

Anthony Phillips

Maurilio V Solano

Enis Aliko

Gregory Rinberg

Silvino M Ersan

Kenneth R Evans

Hatem Oueslati

Trung Quoc Huynh

Thomas Ganz

Cara D Weinheimer

Hanno Reckmann

Jayesh Rameshlal Jain

Leroy William Ledgerwood, Iii

Danielle M Fuselier

Bernhard Meyer-Heye

Henning Finke

Britney E Meckfessel

Mark Bruk

Chad J Beuerhausen

Earth-boring tools include a cutting element mounted to a body that comprises a metal or metal alloy, such as steel. A cutting element support member is mounted to the body rotationally behind the cutting element. The cutting element support member has an at least substantially planar support surface at a first end thereof, and a lateral side surface extending from the support surface to an opposing second end of the cutting element support member. The cutting element has a volume of superabrasive material on a first end of a substrate, and a lateral side surface extending from the first end of the substrate to an at least substantially planar back surface. The at least substantially planar back surface of the cylindrical substrate abuts an at least substantially planar support surface of the cutting element support member.

Cutting element retention for high exposure cutting elements on earth-boring tools

A drill bit includes one or more cutters on a surface thereon configured to penetrate into a formation, at least one pad at the surface, and an actuation device configured to supply a fluid under pressure to the pad to extend the pad from the surface. The drill bit also includes a relief device configured to drain fluid supplied to the pad to reduce the pressure on the at least one pad when the force applied on the at least one pad exceeds a selected limit.

Drill bit with hydraulically adjustable axial pad for controlling torsional fluctuations

A drill bit that includes one or more cutters on a surface thereon configured to penetrate into a formation. The drill bit includes at least one pad at the surface, an actuation device configured to supply a fluid under pressure to the pad to extend the pad from the surface. The drill bit also includes a relief device configured to drain fluid supplied to the pad to reduce the pressure on the at least one pad when the force applied on the at least one pad exceeds a selected limit.

A drill bit may include a bit body including at least one blade extending at least partially over a cone region of the bit body. Additionally, the drill bit may include a plurality of cutting structures mounted to the at least one blade and a rubbing zone within the cone region of the at least one blade, wherein cutting structures within the rubbing zone have a reduced average exposure. Additionally, a method of directional drilling may include positioning a depth-of-cut controlling feature of a drill bit away from a formation to prevent substantial contact between the depth-of-cut controlling feature and rotating the drill bit off-center to form a substantially straight borehole segment. The method may also include positioning the depth-of-cut controlling feature of the drill bit into contact with the formation to control the depth-of-cut and rotating the drill bit on-center to form a substantially nonlinear borehole segment.

Drill bits and tools for subterranean drilling including rubbing zones and related methods

A drill bit and method of making a drill bit. A bit body is provided having a plurality of blade profiles thereon. The blade profile includes a first plurality of cutting elements disposed on each blade such that at least one cutting element on a first section of each blade profile is offset relative to at least one cutting element on a second section of each blade profile. Lateral stability of the drill bit relative to a drill bit without an offset is increased.

Drill bit with a hybrid cutter profile

Drill bits and tools for subterranean drilling, methods of manufacturing such drill bits and tools and methods of directional and off center drilling

A drill bit is disclosed that in one embodiment includes a pad configured to extend and retract from a surface of the drill bit, a motor, a linearly movable member coupled to the motor, a hydraulic unit configured to apply force on the pad, and wherein motion of the motor in a first direction causes the linearly movable member in a first direction to cause the hydraulic unit to exert a force on the pad to extend the pad.

Drill bit with electrohydraulically adjustable pads for controlling depth of cut

A drill bit and method of drilling a wellbore. The drill bit includes a pad configured to extend and retract from a surface of the drill bit, and a force application device configured to extend and retract the pad. The force application device includes a screw driven by an electric motor that linearly moves a drive unit to extend and retract the pad from the drill bit surface. The drill bit may be conveyed by a drill string and the pad may be extended from the drill bit face to drill the wellbore.

Drill bit with a force application using a motor and screw mechanism for controlling extension of a pad in the drill bit

A method for presenting drilling information includes presenting a display including a graph having a first axis and a second axis. The first axis represents a rate of penetration (ROP) of a drill bit into a borehole and the second axis representing a mechanical specific energy (MSE) of a drilling system that includes the drill bit. The method also includes plotting time based or foot based data with a computing device for one or more drilling runs on the graph and overlaying the graph with lines of constant power.

Graph to analyze drilling parameters

In one aspect, a drill bit is disclosed that in one embodiment includes a pad configured to extend and retract from a surface of the drill bit and a force application device configured to extend and retract the pad, wherein the force application device includes a force action member that includes a lever action device configured to extend and retract the pad from the drill bit surface. In another aspect, a method of drilling a wellbore is provided that in one embodiment includes: conveying a drill string having a drill bit at an end thereof, wherein the drill bit includes a pad configured to extend and retract from a surface of the drill bit and a force application device that includes a lever action device configured to extend and retract the pad from the surface of the drill bit; and rotating the drill bit to drill the wellbore.

Drill bit with a force application device using a lever device for controlling extension of a pad from a drill bit surface

A drill bit includes a pad configured to extend and retract from a surface of the drill bit. A force application device extends and retracts the pad. The force application device includes a hydraulically-operated rotating member coupled to a speed reduction device configured to apply a force on drive unit that applies a force on the pad to cause the pad to extend from the drill bit face.

Drill bit with hydraulically-activated force application device for controlling depth-of-cut of the drill bit

A method of designing an earth-boring rotary drill bit includes designing a bit body and cutting elements of the drill bit such that features of the drill bit other than cutting elements engage and rub against a subterranean formation being drilled by the drill bit at depths-of-cut beyond, but close to, an intended median depth-of-cut, and such that the amount of rubbing area between such features and the formation increases at a relatively rapid rate as the depth-of-cut increases beyond the intended median depth-of-cut. Such methods may be employed to mitigate the occurrence of the 'stick-slip' phenomenon during drilling. A method of fabricating a drill bit includes configuring a bit body and cutting elements in accordance with such a design. Earth-boring drill bits include a bit body and cutting elements so configured.

Drill bit design for mitigation of stick slip

A reaming bit designed to operate with low torque fluctuation when driven with a turbine at speeds in the order of 300-600 RPM and above features a profile that is arcuate from the gauge dimension to the nose area or alternatively has a blunt straight taper section but with a ratio of profile length (PL) to bit size (BS) of under 0.75. The blades extend into a concave cone and the cutting structure continues along the blades towards the center. The blades have a step near the gauge section to increase the exposure of the blade cutting structure. An array of protrusions are disposed parallel to and behind the cutting structure to increase high speed stability and adjacent the blade step transition to protect outer casing on run in.

Growing community of inventors

Virginia Water, United Kingdom

Thorsten Schwefe