Baker Hughes Corporation

Rudolf C O Pessier

Mark William Dykstra

Christopher C Beuershausen

Danny Eugene Scott

Roland Illerhaus

James A Norris

Roger W Fincher

Michael P Ohanian

Michael L Doster

Robert James Costo, Jr

Steve R Matson

Matthias Meister

Matthew Ray Isbell

William Heuser

Ronny D McCormick

Sean K Berzas

John R Spaar

Lawrence Allen Sinor

Ralf Duerholt

A superabrasive cutter-equipped rotary drag bit especially suitable for directional drilling in subterranean formations is provided. The bit may employ PDC cutters in an engineered cutter placement profile exhibiting optimal aggressiveness in relation to where the cutters are positioned along the profile of the bit extending from a cone region laterally, or radially, outward toward a gage region therefore. The engineered cutter placement profile may include cutters exhibiting differing degrees of aggressiveness positioned in order to maximize rate-of-penetration and minimize torque-on-bit while maintaining side cutting capability and steerability.

Rotary drill bits exhibiting cutting element placement for optimizing bit torque and cutter life

A PDC-equipped rotary drag bit especially suitable for directional drilling. Cutter chamfer size and backrake angle, as well as cutter backrake, may be varied along the bit profile between the center of the bit and the gage to provide a less aggressive center and more aggressive outer region on the bit face, to enhance stability while maintaining side cutting capability, as well as providing a high rate of penetration under relatively high weight on bit.

Rotary drill bits for directional drilling exhibiting variable weight-on-bit dependent cutting characteristics

A cutting assembly comprised of first and second superabrasive cutting elements including at least one rotationally leading cutting element having a cutting face oriented generally in a direction of intended rotation of a bit on which the assembly is mounted to cut a subterranean formation with a cutting edge at an outer periphery of the cutting face, and a rotationally trailing cutting element oriented substantially transverse to the direction of intended bit rotation and including a relatively thick superabrasive table configured to cut the formation with a cutting edge located between a beveled surface at the side of the superabrasive table and an end face thereof. A rotationally trailing cutting element may be associated with and disposed at a location on the bit at least partially laterally intermediate locations of two rotationally leading cutting elements. Drill bits equipped with the cutting assembly are also disclosed.

Superabrasive cutting assemblies including cutters of varying orientations and drill bits so equipped

A cutter comprising a superabrasive volume including a cutting face portion extending transversely across a leading face of a supporting substrate and a contiguous jacket portion extending rearwardly over the supporting substrate along a portion of its side periphery. Interfaces between the respective superabrasive volume cutting face and cap portions and adjoining surfaces of the supporting substrate are each irregular. The leading face of the substrate includes grooves extending toward the jacket at least partially across the leading face from the side of the substrate opposite the jacket. The side periphery of the substrate defining the location of the jacket is grooved at a plurality of laterally-adjacent locations with substantially axially-oriented grooves extending rearwardly from the leading face of the substrate to a position closer to the trailing face of the substrate. At least one ridge intermediate the side grooves may not extend radially outwardly to a full diameter of the substrate so that the superabrasive material of the jacket extends not only into the circumferential grooves but also circumferentially therebetween, providing a continuous, arcuate superabrasive surface which may have substantially the same exterior diameter as that of the substrate itself. Rotary drill bits for subterranean drilling bearing cutters according to the present invention are also disclosed.

Cutter with complex superabrasive geometry and drill bits so equipped

An array of chisel-shaped cutting elements are mounted to the face of a fixed cutter bit. Each cutting element has a crest and an axis which is inclined relative to the borehole bottom. The cutting elements have a hardened diamond exterior on all surfaces in contact with the formation. The chisel-shaped cutting elements may be arranged on a selected portion of the bit, such as the center of the bit, or across the entire cutting surface. In addition, the crest on the cutting elements may be oriented generally parallel or perpendicular to the borehole bottom. The chisel shape and crest orientation increase the initial contact area while reducing aggressiveness. These advantages are achieved without increasing cutter density, reducing back rake, or adding depth of cut limiters. Chisel-shaped cutting elements having crests which are oriented perpendicular to the borehole bottom have the added advantage of displacing the material in a plane that is parallel to the bit face. This reduces the likelihood of harmful bit balling, particularly on heavy set bits with small open face volume.

Fixed cutter bit with chisel or vertical cutting elements

A chip breaker for use in a fixed-cutter, rotary-type drill bit used in drilling subterranean formations is disclosed. The chip breaker includes a knife-like protrusion positioned proximate a cutting element and adjacent or in a fluid course defined by the drill bit body. As formation chips, shavings, or cuttings are generated during drilling, the chips move over the protrusion and are split or scribed by the protrusion. Drilling fluid breaks the split or scribed chips away from the surface of the fluid course adjacent the cutting element and transports them through the junk slots. Additionally, chip splitters may be positioned on ramped surfaces that further lift the formation chips away from the surface of the fluid course.

Drill bit having a fluid course with chip breaker

A rotary drag bit suitable for directional drilling. The bit includes a bit body from which extend radially-oriented blades carrying PDC cutters. The blades extend to primary gage pads, above which secondary gage pads are either longitudinally spaced or rotationally spaced, or both, defining a gap or discontinuity between the primary and secondary gage pads through which drilling fluid from adjacent junk slots may communicate laterally or circumferentially. Longitudinally leading edges of the secondary gage pads carry cutters for smoothing the sidewall of the borehole. The cutters are preferably configured and oriented so as to provide a relatively aggressive cutting edge to the formation in both longitudinal and rotational directions of bit movement, the cutting edges lying adjacent cutting surfaces preferably disposed at negative rake angles to the formation material of the borehole wall for enhanced durability. Cutters may likewise be disposed on the trailing ends of the secondary gage pads to provide an up-drill capability to facilitate removal of the bit from the borehole. The tandem primary and secondary gage pads provide enhanced bit stability and reduced side cutting tendencies. The discontinuities between the primary and secondary gage pads enhance fluid flow from the bit face to the borehole annulus above the bit, promoting formation cuttings removal. The tandem gage arrangement also has utility in conventional bits not designed specifically for directional drilling.

Rotary drill bits for directional drilling employing tandem gage pad arrangement with cutting elements and up-drill capability

A rotary drag bit suitable for directional drilling. The bit includes a bit body from which extend radially-oriented blades carrying PDC cutters. The blades extend to primary gage pads, above which secondary gage pads are either longitudinally spaced or rotationally spaced, or both, defining a gap or discontinuity between the primary and secondary gage pads through which drilling fluid from adjacent junk slots may communicate laterally or circumferentially. Longitudinally leading edges of the secondary gage pads carry cutters, such as chisel-shaped cutters for smoothing the sidewall of the borehole. The cutters are preferably configured and oriented so as to provide a relatively aggressive cutting edge to the formation in both longitudinal and rotational directions of bit movement. Cutters may likewise be disposed on the trailing ends of the secondary gage pads to provide an up-drill capability to facilitate removal of the bit from the borehole.

A PDC-equipped rotary drag bit especially suitable for directional drilling. Cutter chamfer size and backrake angle, as well as cutter backrake, may be varied along the bit profile between the center of the bit and the gage to provide a less aggressive center and more aggressive outer region on the bit face to enhance stability while maintaining side cutting capability, as well as providing a high rate of penetration under relatively high weight on bit.

Rotary drilling bits for directional drilling exhibiting variable weight-on-bit dependent cutting characteristics

A rotary drill bit suitable for directional drilling. The bit includes a bit body from which extend legs carrying rotatable cutters. The body carries primary gage pads, above which secondary gage pads may be either longitudinally spaced or rotationally spaced, or both. Longitudinally leading edges of the gage pads may carry cutting structure for smoothing the sidewall of the borehole. Cutting structure may likewise be disposed on the trailing ends of the gage pads to provide an up-drill capability to facilitate removal of the bit from the borehole. The gage pads provide enhanced bit stability and reduced side cutting tendencies, as well as reducing lateral loading on the rotatable cutters and associated bearing structure and seals. The invention also has utility in bits not specifically designed for directional drilling.

Rotary drill bits for directional drilling employing movable cutters and tandem gage pad arrangement with active cutting elements and having up-drill capability

Growing community of inventors

Houston, TX, United States of America

Rudolf C O Pessier