Christensen, Inc.

Eastman Christensen Company

Norton Christensen, Inc.

Richard H Grappendorf

Louis K Bigelow

John S Davis

Jana L Brown

Alexander R Meskin

Gordon G Sirrine

Hydraulic flow may be rendered substantially uniform throughout the waterways on a rotating bit from the center of the bit to the outer gage. This is accomplished by defining waterways into the bit face below a primary surface of the bit face. A colinear land is then disposed into the waterway, but does not extend above the primary surface of the bit face. A plurality of teeth are then disposed on the colinear land and extend above the primary surface of the bit face. The flow of hydraulic fluid is prevented from dispersing as the fluid moves from the center of the bit to the outer gage. Cutting by kerfing is further optimized by arranging triads of cutters on each of the pads disposed in the waterways into a set. Each triad of cutters corresponds to additional triads of cutters in azimuthally subsequent and adjacent pads in the next subsequent waterway, thereby forming the set of associated triads of cutters. Each triad of cutters in the set is radially offset from the corresponding triads in the set. Therefore, while each triad cuts through a kerfing action individually, each triad relates to the preceding triad of cutters to cut into the kerfed lands made by that preceding triad of cutters and thus to cut through a kerfing action as well.

Bit design for a rotating bit incorporating synthetic polycrystalline

A drill bit having thermally stable PCD cutting elements includes a matrix body element having a plurality of spaced cutting elements supported in a body of matrix material such that a substantial portion of the cutter is above the body matrix and a minor portion is received within the body matrix. The cutters have side surfaces exposed and are so positioned that at least in some of the cutters more surface area of one side face is exposed as compared to the other side faces. The cutter support may include a small pad of matrix material to reduce the loading directly on the PCD. In a preferred form the PCD elements are mounted on pads or blades formed by spaced channels. The hydraulics are straight radial flow and improved hydraulic flow is achieved through the use of waterways which concentrate the fluid flow near the face of the cutters. In one form, improved hydraulics are obtained by having one fluid discharge port for each of the radially disposed fluid channels. Various forms and arrangements are disclosed.

Earth boring bit for soft to hard formations

Shortening of the bit life and premature failure of cutting elements on a rotating bit near or at the gage of the bit can be avoided by disposition of the cutting elements at or below a key level on the shoulder-to-gage transition. A first tooth is placed on the shoulder of a rotating bit at the key level. The key level is defined as that point on the shoulder of the rotating bit at which a tooth extends radially from the axis of the rotating bit by a distance substantially equal to the diameter of the bore drilled by the rotating bit as also defined by the gage diameter of the rotating bit. Below the key level the teeth are set on the pads in a staggered pattern that serve to increase effective cutting element concentration. The staggered pattern is repeated within a pad and between pads in selected areas. Distinguishable cutting elements are alternated within the pattern.

Cutter configuration for a gage-to-shoulder transition and face pattern

A polycrystalline diamond cutting element in an earth boring bit is affixed to the bit face by an improved tooth. The tooth includes a prepad extending from the face of the mining bit contiguous to and substantially congruous with that portion of a polycrystalline diamond element also extending from the bit face. A trailing support is provided behind the polycrystalline diamond element and is similarly contiguous and substantially congruous therewith so that a generally singular geometrically shaped body is formed by the prepad, the polycrystalline diamond element and the trailing support. The prepad and trailing support are integrally formed from the matrix material of the rotary bit and are generally arcuate about a radius centered on the bit face. The polycrystalline diamond element is thus securely retained on the bit face while exposing a maximum extent of the polycrystalline diamond element sandwiched between the prepad and trailing support.

Tooth configuration for an earth boring bit

An improved tooth for use in rotating diamond bits incorporating a generally triangular prismatic polycrystalline diamond element is devised by integrally forming an oval shaped base about the tooth or element extending from the face of the rotating bit, thereby providing a lateral reinforcing collar. The diamond element is also reinforced by a tapered trailing support having a leading surface contiguous and substantially congruous with the trailing surface of the diamond element. In one embodiment, a prepad provides reinforcement or support for the leading surface of the diamond element.

Diamond cutting element in a rotating bit

A drill bit (10) comprises a cast body (12) with full length wide overlapping integral spiral stabilizer lands (14) between intervening spiral grooves (16), integral short, strong, stubby spiral fingers (18) reinforced by additional web portions (12a) angularly spaced about a short core receiving bore (b) and the longitudinal axis of the body (21). An inclined core ejection passage (P) extends radially outwardly from a spherical inlet end thereof connected to the core receiving bore (b) and at which an inclined hard core cutter breaker inserted within a pocket is situated. The leading sides of the fingers have support surfaces (18a) and shoulders (18b) for supporting engagement with composite abrasive compact cutters comprised of a carbide backing (30a) bonded to the support surfaces (18a) and layers of bonded polycrystalline abrasive particles at opposite cutting sides (30b) inclined at a negative rake angle. The body is also provided with flushing fluid passages (24) and a central bore at its drive end adapted with means (22) to connect drive means, with a flushing fluid passage therein to drive the drill bit (10).

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Riverton, UT, United States of America

Richard H Grappendorf