Douglas CarawayHouston, TX

6371226, Apr 16, 2002

Nov 22, 1999

09/447059

Douglas Caraway - Kingwood TX

Camco International Inc. - Houston TX

F21B 1036

1754202, 175415, 175434

There is provided a rotary drag-type drill bit comprising a bit body having a leading surface comprising a plurality of pads, at least some of the pads each having a wearable abrasive surface including particles of superhard material and defining an outer profile of the pad, at least a part of the outer profile of at least one of the pads being disposed inwardly or outwardly of the outer profile of the other pads. With this arrangement, during initial drilling through softer formation, most of the removal of formation will be effected by the outermost of the abrasive pads and little or no formation will be removed by the more inward pads. Accordingly, the bit will act as a lighter set bit and good rates of penetration may be achieved. As drilling proceeds and the bit wears, which may occur more rapidly as the bit meets harder formations, the more outwardly disposed pads will wear down more than the inwardly disposed pads so that the inwardly disposed pads will begin to contribute more to the cutting action of the bit, so that the bit effectively becomes heavier set. As drilling progresses to a point where all of the pads wear down to the same level, the bit will then act as a conventional heavy set bit where all the abrasive surfaces lie on the same profile.

7025156, Apr 11, 2006

Nov 18, 1997

08/972781

Douglas Caraway - Kingwood TX, US

E21B 29/06
E21B 7/04

175426, 166 551, 175431

A rotary drill bit is used both for milling a casing window and drilling a lateral borehole into subterranean earthen materials, without the prior need of having separate drill bits for milling of the casing and for drilling of the borehole. The rotary drill bit is lowered into a casing set within a borehole; and the drill bit is rotated to engage an inner surface of the casing. A first set of cutting elements on the drill bit remove casing material to mill a casing window. The drill bit is then moved through the casing window so that a second set of cutting elements on the drill bit create a lateral wellbore in subterranean earthen material.

2002011, Aug 22, 2002

Jan 22, 2002

10/054759

Douglas Caraway - Kingwood TX, US

E21B010/26

175/385000, 175/391000, 175/406000

A drill bit for use in horizontal boring includes a bit body with a central axis of rotation including a forwardmost pilot section, a reaming section rearwardly of the pilot section including a forwardly inclined arcuate steering surface and a plurality of gauge cutting teeth disposed rearwardly of the pilot section in opposed relationship to the inclined steering section, the gauge teeth extending farther from the central axis in a radial direction than the steering section such the arcuate steering section lies entirely within a circular profile corresponding to the path of the gauge teeth when the bit is rotated 360 and a coupling section at a rear end portion of the body configured for attachments to an adjacent component of the drill sting.

2004010, Jun 10, 2004

Aug 12, 2003

10/604714

Iain Cooper - Linton, GB
Craig Ivie - Spring TX, US
Douglas Caraway - Kingwood TX, US

E21B021/08

175/026000, 175/038000, 175/317000

A method for optimizing drilling fluid hydraulics when drilling a well bore is disclosed. The drilling fluid is supplied by a surface pump through a drill string to a drill bit. The method has the step of adjusting the flow rate of a surface pump and a fluid pressure drop across the drill bit while drilling such that the drilling fluid hydraulics are optimized for a given drilling condition. In order for the flow through all the devices in the drill string to also be optimized, the flow through the devices is adjusted, thereby setting the pressure drop and the fluid flow rate through each device. As required for the overall system, the flow from the surface pump is increased or decreased as necessary.

2011003, Feb 10, 2011

Aug 6, 2009

12/536624

Harold Sreshta - Conroe TX, US
Eric F. Drake - Galveston TX, US
Douglas B. Caraway - Conroe TX, US

E21B 10/00
B32B 3/26
B22F 1/00
B21D 22/00

175425, 4283044, 75252, 72352

A hardmetal composite used as wear-resistant surfaces and inlays in earth-engaging equipment includes more than one hardphase. At least one hardphase has a high average particle size, for example, from 100 μm to 2000 μm. The hardphases vary in terms of particle size, hardness, and binder content, and at least one hardphase includes a particulate constituent capable of plastic deformation that comprises at least 1% residual porosity.

2011021, Sep 1, 2011

Aug 14, 2008

12/672927

John Michael Fuller - Bristol, GB
Douglas Caraway - Conroe TX, US
Graham Richard Watson - Gloucester, GB

B24D 3/00
B32B 3/02

428157, 428172, 428167, 428213

A PCD cutting element for use in earth boring drill bits where the interstices remote from the working surface are filled with a catalyzing material and the interstices adjacent to the working surface are substantially free of the catalyzing material is described. An intermediate region between the substantially free portion and filled portion has a plurality of generally conically sectioned catalyst-free projections which taper down, extending to a second depth from the planar working surface, preferably about 0.5 times or more of the first depth.

6193000, Feb 27, 2001

Nov 22, 1999

9/444072

Douglas Caraway - Kingwood TX
Robin Macmillan - Caracas, VE

Camco International Inc. - Houston TX

E21B 1046

175431

There is provided a rotary drag-type drill bit comprising a bit body having a leading surface comprising a plurality of pads, at least some of the pads each having a wearable abrasive surface including particles of superhard material and defining an outer profile of the pad, at least a part of the outer profile of at least one of the pads being disposed inwardly or outwardly of the outer profile of the other pads. With this arrangement, during initial drilling through softer formation, most of the removal of formation will be effected by the outermost of the abrasive pads and little or no formation will be removed by the more inward pads. Accordingly, the bit will act as a lighter set bit and good rates of penetration may be achieved. As drilling proceeds and the bit wears, which may occur more rapidly as the bit meets harder formations, the more outwardly disposed pads will wear down more than the inwardly disposed pads so that the inwardly disposed pads will begin to contribute more to the cutting action of the bit, so that the bit effectively becomes heavier set. As drilling progresses to a point where all of the pads wear down to the same level, the bit will then act as a conventional heavy set bit where all the abrasive surfaces lie on the same profile.

5992547, Nov 30, 1999

Dec 9, 1998

9/208197

Douglas Caraway - Kingwood TX
John Hayward - Minchinhampton, GB
Malcolm R. Taylor - Gloucestershire, GB
Tom Scott Roberts - Quedgeley, GB
Steven Taylor - Cheltenham, GB
Graham R Watson - Frampton-on-Severn, GB

Camco International (UK) Limited - Stonehouse

E21B 1026

175385

A rotary drill bit for use in drilling holes in subsurface formations comprises a bit body having a leading face and a gauge region, a number of blades formed on the leading face of the bit and extending outwardly away from the axis of the bit so as to define between the blades a number of fluid channels leading towards the gauge region, a number of cutting elements mounted side-by-side along each blade, and a number of nozzles in the bit body for supplying drilling fluid to the fluid channels for cleaning and cooling the cutting elements. In each of the fluid channels, adjacent the gauge region, is an opening into an enclosed passage which passes internally through the bit body to an outlet which, in use, communicates with the annulus between the drill string and the wall of the borehole being drilled. The gauge region of the drill bit comprises a substantially continuous bearing surface which extends around the whole of the gauge region.