Search Images Maps Play YouTube News Gmail Drive More »
Sign in
Screen reader users: click this link for accessible mode. Accessible mode has the same essential features but works better with your reader.

Patents

  1. Advanced Patent Search
Publication numberUS3207241 A
Publication typeGrant
Publication dateSep 21, 1965
Filing dateApr 8, 1963
Priority dateApr 8, 1963
Publication numberUS 3207241 A, US 3207241A, US-A-3207241, US3207241 A, US3207241A
InventorsNeilson William J
Original AssigneeSmith Tool Co
Export CitationBiBTeX, EndNote, RefMan
External Links: USPTO, USPTO Assignment, Espacenet
Jet bits
US 3207241 A
Abstract  available in
Images(2)
Previous page
Next page
Claims  available in
Description  (OCR text may contain errors)

Sept. 21, 1965 w. J. NElLsoN 3,207,241

JET BITS 2 Sheets-Sheet l Filed April 8, 1965 MyW/4% SePt- 21, 1965 w. J. NElLsoN 3,207,241

JET BITS Filed April a, 196s 2 Sheetsheet 2 BY @ZM/7M# United States Patent O 3,207,241 JET BITS William J. Neilson, Whittier, Calif., assigner to Smith Tool Co., Compton, Calif., a corporation of California Filed Apr. 8, 1963, Ser. No. 271,307 1 Claim. (Cl. 175-340) This invention relates to improvements in well drilling bits, and in particular to that class of bits commonly referred to as jet bits.

One form of conventional well drilling bit consists of a body having three downwardly extending legs on which are formed inwardly extending journals. Cutters which are usually toothed are rotatably mounted on the journals and as the body is rotated these cutters penetrate and remove fragments of the formation being drilled. Circulation fluid is pumped down the drill stem and is discharged through one or more circulation ports which circulation fluid performs a number of functions including washing the cuttings upwardly, cooling the bit, and washing the teeth of the cutters.

During recent years it has been proposed to constrict or reduce the size of the circulation ports so that by forcing the circulation fluid down the drill stern at high velocity and under high pressure, jet streams will be discharged downwardly toward the bottom of the hole being drilled. These jet streams are intended to wash away the formation being penetrated as much as possible, thus reducing the work that must be done by the roller cutters. However, in the usual roller cutter bit having three or four roller cutters, as these are equally spaced around the bottom of the bit they occupy so much of the available space that the nozzles through which the circulation uid is discharged must be located at considerable distance above the bottom of the well bore. This distance heretofore has been in excess of six-nozzle diameters. When the bottom of the well bore is lled with circulation fluid and a jet stream is discharged from a nozzle that is spaced more than six-nozzle diameters from the bottom of the hole, the effectiveness of the jet stream is largely dissipated. The stream of circulation uid that emerges from the nozzle becomes dissipated due to the fact that it accelerates and entrains the surrounding circulation fluid that is present in the well bore. When the nozzle is spaced from the bottom of the well bore more than six diameters its effectiveness to hydraulic away the formation becomes lost quite rapidly, see the article entitled, Keys to Successful Competitive Drilling, by Roy A. Bobo and Robert S. Hoch that appeared in World Oil for November 1957.

It is consequently highly desirable to provide a well drilling bit which is so designed that circulation fluid will be conducted from the drill stem through a confined passage and emerge through a nozzle that is located very close to the bottom surface of the well hole that is being drilled. For most eflicient operation, the spacing of the nozzle from the bottom surface of the well hole should be less than six diameters.

A primary object of the present invention is to provide an improved well drilling bit which will accomplish the above-mentioned desiderata.

With the foregoing and other objects in view, which will be made manifest in the following detailed description and specifically pointed out in the appended claim, reference is had to the accompanying drawings for an illustrative embodiment of the invention, wherein:

FIGURE l is a bottom plan view of one form of well drilling bit embodying the present invention;

FIG. 2 is a vertical section taken substantially upon the line 2-2 upon FIG. 1;

FIG. 3 is a partial view in vertical section similar 3,207,241 Patented Sept. 2.1, 1965 Ice ' Istruction; and

FIG. 4 is a vertical section through a well bore illustrating how the bit embodying the present invention may be used in directional drilling.

Referring to the accompanying drawings wherein similar reference characters designate similar parts throughout, the improved bit comprises a hollow body 10 having a threaded pin 11 by which it may be attached to the drill collars of a drill string of a rotary well drilling apparatus. Three legs are shown as extending downwardly from the body 10 which are equally spaced from each other circumferentially. Two of these legs indicated at 12, terminate in downwardly and inwardly extending journals 13 on which toothed roller cutters 14 are rotatably mounted. These are shown as equipped with anti-friction radial and thrust bearings generally indicated at 15. The particular design of the roller cutters and of the bearings that rotatably mounted the cutters on the journals is immaterial insofar as the present invention is concerned.

As will be observed from an inspection of FIG. 1, the two cutters 14 occupy approximately two-thirds of the bottom surface of the bit and in conformity with general practice, nozzles 16 are arranged in the body 10 and communicate with passages leading to its interior through which circulation lluid is discharged downwardly adjacent the sides of the cutters. These nozzles, due to the presence of the cutters, are usually required to be spaced more than six-nozzle diameters from the bottom hole surface B, and because of the spacing their effectiveness to wash away or hydraulic away the formation at the bottom hole surface B is largely dissipated. The jets issuing from the nozzle 16 while they may perform this function to a slight extent, nevertheless are largely used for washing cuttings upwardly and also for washing the teeth on the cutters.

In accordance with the present invention the third leg 17 does not terminate in a downwardly and inwardly extending journal as in conventional practice, but extends downwardly to a point approximately even with the bottoms of the journals 13. In this leg there is provided a confined passage 18 that communicates with the hollow interior of the body 10, and this passage may be formed in part by a tube 19 that is welded as at 20 to the leg and located inwardly of the outer surface of the leg. This tube may have in its lower end a nozzle holder 21 that is pressed or otherwise secured in position and which holds a nozzle 22 that is retained in position by a nozzle retainer 23. The nozzle 22 may be formed of hard metal, such as tungsten carbide, or a hard ceramic to resist its being cut by the circulation uid that is discharged therethrough under high velocity and at high pressure. This nozzle is directed downwardly against the bottom hole surface B, and the point at which the stream of circulation fluid issues from the nozzle is spaced from the surface B only a short distance. In the preferred form of construction this distance is less than six diameters of the nozzle. The closer that the nozzle may be to the surface B the less the stream will be dissipated on emerging from the nozzle and encountering the surrounding circulation fluid that is in the well bore. The stream is so directed as to encounter the bottom hole surface in the tracks of the cutters. This stream on encountering the bottom hole surface B will wash away a substantial amount of the formation as the bit is rotated, thus relieving to a large extent in many formations the work that must be done by the cutters 14.

Increased liuid velocity across the bottom of hole also improves the removal of cuttings cut by the cutters. Higher velocity permits the lifting of larger cuttings which otherwise would require recutting, thereby increasing drilling eiciency.

It will be apprecated that with this type of bit that the bit is non-symmetrical with relation to a vertical central axis. Consequently, the leg 17 may be left relatively broad or may be made broader than the leg 12 so that it may function as a stabilizing pad when it engages the vertical walls of the well bore. To this end, the lower end of leg 17 is preferably externally coated with hard facing metal 24 applied thereto, such as by welding, so as to resist abrasion. In the form shown in FIG. 2 the axis of the stream that emerges from the nozzle 22 is directed against the bottom hole surface B inwardly of the walls of the hole. In the construction shown in FIG. 3 the construction is the same as that disclosed in FIG. 2, except that the axis of the tube 19 and of the nozzle held therein is such that the emerging stream is directed against the juncture J between the bottom hole surface B and the well wall.

During normal operations the bit is rotated by the drill string in the conventional manner. Where the formation that is being drilled is such that it can be washed away or hydrauliced away by the stream of circulation uid most of this is accomplished by the jet that issues from the nozzle. 22. Where this cannot be accomplished by the jet the formation may be drilled -by means of the cutters 14 in the conventional manner. Either construction can be advantageously employed in directional drilling. Thus, as illustrated in FIG. 4, if it is desired to drill'the well in a designated direction, either form of bit may be lowered into the well to the well bottom and oriented by conventional surveying equipment so that the nozzle 22 will be directed in the direction that it is desired that the Well bore proceed. The bit and drill string can be left stationary in this position while circulation uid is pumped down the drill string and discharged through the nozzle. This will cause a cavity C to be Washed in this side of the well hole and after such a cavity has been formed, the bit and drill string are again rotated as in conventional drilling. Due to the reduced resistance occasioned by the cavity C, the bit and drill string will be diverted from vertical and proceed along the path P.

From the above-described construction it will be appreciated that an improved well drilling bit has been provided which enables circulation fluid to be discharged from a nozzle located very close to the surface of the formation that is to be drilled. By reason of the fact that the jet is so close to the bottom hole surface its effectiveness is not dissipated or lost by the surrounding circulation Huid as would be the case if the nozzle were most remotely located with reference to the bottom hole surface.

While the invention has been disclosed as incorporated in a bit having three downwardly extending legs, two of which have journals and rotatable cutters, it will be appreciated that it may be incorporated in a bit employing four equally spaced, downwardly extending legs. In the latter event, three of the legs may have cutters rotatably mounted thereon and the fourth may be employed to provide the confined, `downwardly extending circulation passage terminating near the bottom hole surface cut by the bit.

Various changes may be made in the details of construction without departing from the spirit and scope of the invention as defined by the appended claim.

I claim:

A well drilling bit comprising a body having three equally spaced legs extending downwardly therefrom approximately the same distances, journals on the lower ends of two of the legs extending downwardly and inwardly therefrom, roller cutters rotatably mounted on the journals, the third leg having a circulation fluid passage associated therewith terminating approximately even with the lower end of the third leg and directed downwardly therebeneath, a nozzle of hard abrasion resisting material in the lower end of said passage having an internal diameter smaller than that of the remainder of the passage, said nozzle being located not more than six of its internal diameters above the bottom hole surface cut by the cutters and being directed against the tracks of the cutters on the bottom hole surface, the body having additional circulation iluid passages terminating above the cutters and directed downwardly adjacent the sides of the cutters.

References Cited by the Examiner UNITED STATES PATENTS `1,121,573 12/14 Wetzel 175-399 2,066,671 1/37 Catland 175-339 2,335,929 12/43 Fortune 175-340 2,754,091 7/56 Kucera 175-340 2,873,092 2/59 Dwyer 175-340 2,901,223 8/59 Scott 175-340 3,104,726 9/63 Davis 175-341 v3,113,630 12/63 Williams 175-340 CHARLES E. OCONNELL, Primary Examiner.

BENJAMIN HERSH, Examiner.

Patent Citations
Cited PatentFiling datePublication dateApplicantTitle
US1121573 *Oct 23, 1913Dec 15, 1914 Well-drilling bit.
US2066671 *Oct 5, 1935Jan 5, 1937Globe Oil Tools CoRoller bit
US2335929 *Jul 13, 1942Dec 7, 1943Reed Roller Bit CoRoller bit
US2754091 *Oct 22, 1948Jul 10, 1956Reed Roller Bit CoDrill bit
US2873092 *Nov 14, 1957Feb 10, 1959Dwyer Roy PJet deflection method of deviating a bore hole
US2901223 *Nov 30, 1955Aug 25, 1959Hughes Tool CoEarth boring drill
US3104726 *Feb 9, 1962Sep 24, 1963 Rotary blt stabilizing structure
US3113630 *Nov 8, 1960Dec 10, 1963David B WilliamsDrill bit
Referenced by
Citing PatentFiling datePublication dateApplicantTitle
US3329222 *Nov 23, 1964Jul 4, 1967Smith Ind International IncJet bit
US3363706 *Jul 20, 1965Jan 16, 1968Shell Oil CoBit with extended jet nozzles
US3419220 *Nov 30, 1966Dec 31, 1968Gulf Research Development CoNozzles for abrasive-laden slurry
US3509952 *Dec 11, 1968May 5, 1970Hughes Tool CoPassageway extension for drilling tools
US3599733 *Dec 15, 1969Aug 17, 1971R F Varley Co IncMethod for directional drilling with a jetting bit
US3746108 *Feb 25, 1971Jul 17, 1973Hall GFocus nozzle directional bit
US3823789 *May 18, 1973Jul 16, 1974Smith InternationalDrill bit center jet
US4068731 *Nov 17, 1976Jan 17, 1978Smith International, Inc.Extended nozzle and bit stabilizer and method of producing
US4077482 *Sep 27, 1976Mar 7, 1978Rolen Arsenievich IoannesianThree cone rock bit
US4185706 *Nov 17, 1978Jan 29, 1980Smith International, Inc.Rock bit with cavitating jet nozzles
US4301877 *Mar 10, 1980Nov 24, 1981Hughes Tool CompanyClad mud nozzle
US4381825 *Aug 27, 1981May 3, 1983Strata Bit CorporationDrill bit nozzle
US4391339 *Dec 1, 1980Jul 5, 1983Hydronautics, IncorporatedCavitating liquid jet assisted drill bit and method for deep-hole drilling
US4400024 *Jul 31, 1981Aug 23, 1983Hughes Tool CompanyNozzle retaining ring with crushed O-ring
US4611672 *Jun 18, 1984Sep 16, 1986Vereinigte Edelstahlwerke AktiengesellschaftDrill bit
US4706765 *Aug 11, 1986Nov 17, 1987Four E Inc.Drill bit assembly
US4730681 *Aug 29, 1986Mar 15, 1988Rock Bit Industries U.S.A., Inc.Rock bit cone lock and method
US7316281Sep 10, 2004Jan 8, 2008Smith International, Inc.Two-cone drill bit with enhanced stability
US20060054361 *Sep 10, 2004Mar 16, 2006Mohammed BoudrareTwo-cone drill bit with enhanced stability
US20060266557 *May 31, 2005Nov 30, 2006Roy EstesDirectable nozzle for rock drilling bits
WO1988008070A1 *Apr 6, 1988Oct 20, 1988Flowdril CorporationFluid jet assisted cone-type drill bit assembly and method
Classifications
U.S. Classification175/340, 175/376
International ClassificationE21B7/06, E21B7/04, E21B7/18, E21B10/08, E21B10/18
Cooperative ClassificationE21B7/065, E21B10/18, E21B7/18
European ClassificationE21B7/18, E21B7/06F, E21B10/18