US3469642A - Hydraulic drilling bit and nozzle - Google Patents

Hydraulic drilling bit and nozzle Download PDF

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Publication number
US3469642A
US3469642A US771382A US3469642DA US3469642A US 3469642 A US3469642 A US 3469642A US 771382 A US771382 A US 771382A US 3469642D A US3469642D A US 3469642DA US 3469642 A US3469642 A US 3469642A
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Prior art keywords
nozzles
nozzle
inch
inches
bit
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Robert J Goodwin
Joseph L Pekarek
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Chevron USA Inc
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Gulf Research and Development Co
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Assigned to CHEVRON RESEARCH COMPANY, SAN FRANCISCO, CA. A CORP. OF DE. reassignment CHEVRON RESEARCH COMPANY, SAN FRANCISCO, CA. A CORP. OF DE. ASSIGNMENT OF ASSIGNORS INTEREST. Assignors: GULF RESEARCH AND DEVELOPMENT COMPANY, A CORP. OF DE.
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    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B10/00—Drill bits
    • E21B10/60—Drill bits characterised by conduits or nozzles for drilling fluids
    • E21B10/61—Drill bits characterised by conduits or nozzles for drilling fluids characterised by the nozzle structure
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B05—SPRAYING OR ATOMISING IN GENERAL; APPLYING FLUENT MATERIALS TO SURFACES, IN GENERAL
    • B05B—SPRAYING APPARATUS; ATOMISING APPARATUS; NOZZLES
    • B05B1/00—Nozzles, spray heads or other outlets, with or without auxiliary devices such as valves, heating means
    • B05B1/02—Nozzles, spray heads or other outlets, with or without auxiliary devices such as valves, heating means designed to produce a jet, spray, or other discharge of particular shape or nature, e.g. in single drops, or having an outlet of particular shape
    • B05B1/10—Nozzles, spray heads or other outlets, with or without auxiliary devices such as valves, heating means designed to produce a jet, spray, or other discharge of particular shape or nature, e.g. in single drops, or having an outlet of particular shape in the form of a fine jet, e.g. for use in wind-screen washers
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B10/00—Drill bits
    • E21B10/60—Drill bits characterised by conduits or nozzles for drilling fluids
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B7/00—Special methods or apparatus for drilling
    • E21B7/18—Drilling by liquid or gas jets, with or without entrained pellets

Definitions

  • FIG.60 lzzq United States Patent U.S. Cl. 175-393 13 Claims ABSTRACT ()F THE DISCLOSURE Nozzles for drill bits used in the hydraulic jet drilling of wells.
  • the nozzles have a long converging entrance section formed by a convex surface of large radius of curvature opening at its outlet end into a throat section of constant diameter. Data are presented showing reduced rates of wear of the nozzles and increased rates of penetration as compared with nozzles heretofore used.
  • This invention pertains to improvements in bits and nozzles for use in hydraulic jet drilling of wells by use of a high-velocity jet carrying an abrasive,
  • an abrasive-laden slurry is directed in narrow streams at extremely high velocities against the bottom of the hole from nozzles in the rotating bit to penetrate the formation by the abrasive action of the suspended particles, rather than by mechanical cutting or grinding elements.
  • Hydraulic jet drilling allows substantially higher penetration rates of hard formations than are obtainable with conventional bits.
  • the highly erosive nature of the process severe-1y limits the life of both the bit and the nozzles. When the nozzles become so eroded and enlarged that the pumping equipment is no longer able to develop the required cutting jet velocity through the nozzle exits because of the pressure losses associated with the higher flow rates through the drill pipe required to maintain the necessary high velocity through the enlarged nozzles, then the bit must be replaced.
  • the life of the bit is determined by the life of the nozzles.
  • Replacing a bit is an expensive operation because it requires pulling the entire string of drill pipe out of the hole, and the drill string can be thousands of feet long.
  • drill bit replacement requires a large amount of time, which lost time costs many thousands of dollars, depending on the depth of the hole.
  • This invention comprises a novel bit for drilling wells with hydraulic jets of abrasive-laden fluid, comprising a hollow bit body closed at its lower end and having a plurality of nozzles extending through the lower end and opening downwardly in position to cut a plurality of concentric grooves in the bottom of the borehole as the bit is rotated.
  • Each of the nozzles comprises an elongated body formed with an internal profile embodying the invention which will operate in jet drilling bits for long periods of time without excessive erosion.
  • An important and essential feature of the present invention resides in the novel internal profile of the nozzles embodying the invention. This profile comprises an arcuate entrance section and a cylindrical throat portion tangent to the arcuate entrance section. The arcuate section is in the form of an arc of a circle of large diameter.
  • Nozzles embodying the invention will have an increased life characteristic to further increase the advantages of hydraulic jet drilling.
  • FIGv 1 is a diagrammatic view, partially in cross section, of apparatus for drilling wells with the drill bit and nozzle of this invention
  • FIG. 2 is a vertical sectional view of the drill bit attached to an adapter for connection to the lower end of drill pipe
  • FIG. 3, is a bottom view of the embodiment of the drill bit illustrated in FIG. 2
  • FIG. 4 is an outlet end view of a nozzle embodying the invention
  • FIG. 5 is a longitudinal, cross-sectional view taken on line 55 of FIG. 4
  • FIGS. 60 through 6d are diagrammatic representations of other nozzles not embodying the invention having various different internal profiles which were tested, and which show the improved life characteristic of nozzles embodying the present invention.
  • a derrick 10 is shown in place above a well having casing 14 and drill pipe 16 therein.
  • a drill bit 18 is connected to the lower end of drill pipe 16 and rests on the bottom of the well.
  • a discharge line 22 delivers drilling slurry carrying abrasive and entrained cuttings to apparatus labeled, Drilling Slurry Treatment.
  • Drilling Slurry Treatment consists of removal of cuttings and excessive fine particles, cooling, and adding slurry treating materials, fresh slurry to make up any losses, and fresh abrasive.
  • the slurry is then delivered to the High Pressure Pumps, and discharged by the pumps through line 26 into the upper end of drill pipe 16.
  • Means are provided to rotate the drill pipe in the usual manner.
  • the weight on the drill bit is not substantial; 1,000 pounds per inch of bit diameter, or less, approximately one-fifth the weight used in conventional rotary drilling, is adequate.
  • the drilling slurry contains an abrasive such as sand, ferrous grit, or ferrous shot which is discharged at extremely high velocities from the nozzles. This velocity is at least 500, and preferably 600 to 900 feet per second.
  • the particle size of abrasive depends upon the exit openings of the nozzles. It is desirable to use the largest abrasive particles that will pass through the nozzles and pumps because drilling rate is faster with larger particles. In a typical operation in which the nozzles have an internal diameter of inch, abrasive particles having a size in the range of to 80 mesh, and preferably to 40 mesh, can be used.
  • Bit 18 comprises a lower cylindrical section 28 joined to the lower end of a central adapter section 30 which is joined to the lower end of an upper cylindrical section 32. Bit 18 is closed at the lower end by a bottom member 34, and at the upper end by a top 36 having a threaded, centrally positioned, upwardly opening box 38 to receive the threaded lower end of drill pipe 16.
  • Bit 18 illustrated in FIG. 2 of the drawings comprises an elongated internal chamber 40 of relatively large diameter, provided with an internal strengthening web 42. Means are provided to permit flow of slurry and cuttings upwardly around the bit, and comprise diametrically opposed fiutes 44 in alignment with web 42.
  • Stand-off bars 48 Protruding downwardly from the lower surface of plate 46, and preferably integral therewith, are a pair of standofi bars 48 which determine the distance between the outlets of the nozzles and the bottom of the borehole. Stand-off bars 48 project downwardly a distance of about 4 inch to about 1% inches, and preferably a distance in the range of about inch to about 1 inch. At lower thicknesses, erosion of the bottom and side walls of the bit is severe because of backsplash from the hole bottom, and at thicknesses greater than about 1% inches, the rate of cutting is seriously reduced because the nozzles are too far from the hole bottom.
  • Nozzles 50 are substantially entirely within the bit body in that the outlet ends of the nozzles are substantially flush with the bottom surface of the backsplash plate.
  • the nozzles are positioned and oriented in the drill bit to accomplish several purposes. The total number of nozzles and their individual location and orientation is dependent upon the size of borehole to be drilled. Some nozzles are positioned to cut a groove having an outer diameter about to /2 inch larger than the largest diameter of the drill bit. For this purpose, outwardly slanting nozzles 50a are positioned near the outer edge of the backsplash plate. Other nozzles are positioned to cut grooves in the bottom of the borehole spaced apart a small enough distance to allow the stand-off bars to break the intervening ridges.
  • a plurality of outwardly slanting nozzles 50b are positioned at a smaller distance from the center of rotation of the drill bit than nozzles 50a, see FIG. 3. Still closer to the center of rotation are outwardly slanting nozzles 50c adapted to cut a groove spaced inwardly from the groove cut by nozzles 50b. Still nearer the center of rotation is a nozzle 50d slanting inwardly to cut a hole in the center of the borehole extending outwardly beyond the inner ends 52 of the stand-off bars 48. Nozzle 50d is positioned to direct the slurry between the inner ends of the stand-off bars so as not to erode them.
  • a vertical nozzle 50e is positioned to cut a groove between the groove cut by nozzles 50c and the hole cut by nozzles 50d to reduce the width of the ridge created by nozzles 50d and 500.
  • the number of nozzles at any particular radial distance from the center of rotation of the bit increases, but not necessarily directly, as the radial distance increases because of the larger amount of rock that must be removed in the outer grooves, to cut grooves of substantially the same depth below the bit.
  • the extension of nozzles 50 above the upper surface of bottom member 34 has been found to reduce nozzle plugging.
  • the extension also positions the inlet ends of the nozzles nearer the center of the bit body to cause flow at substantially uniform rates through all the nozzles. In this manner, the depth of grooves cut can be made substantially the same, and optimum stand-ofif from the bottom of the hole for all of the nozzles is obtained to give a high rate of penetration.
  • FIGS. 4 and 5 there is shown one nozzle 50, which could be any one of nozzles 50a to 50a, which is not drawn to scale, and represents a relatively large family of nozzles embodying the invention and which have been found to be particularly advantageous.
  • Nozzles embodying the invention and having the greatly increased life characteristic comprise an internal profile, which consists of an entrance section whose profile is an arc of a circle, the outlet end of which iS tangent to the inlet end of a cylindrical throat section.
  • the combination of the arcuate entrance section profile, and the cylindrical throat with its entrance end tangent to the exit end of the entrance section, imparts increased life to nozzles embodying the invention. It is thought that this advantageous result at least partially resides in the provision of a particular radius of curvature in the entrance section which prevents the creation of localized areas of high wear which prematurely end the life of the nozzle.
  • the arcuate entrance section thus increases life by causing the entire entrance section of the nozzle to wear uniformly.
  • the provision of the cylindrical throat tangent to the exit end of the entrance section aids in increasing life by delaying the time at which the wearing action of the abrasive particles reaches the exit diameter in the outlet face of the nozzle.
  • the nozzle can function with reasonable wear rearwardly of that exit diameter
  • Nozzle 50 is cylindrical and comprises an entrance diameter D, an exit diameter d, an entrance length L, a cylindrical throat portion of diameter d and length T, an outside diameter OD, and an external taper 15, described above.
  • the cross-sectional shape of the nozzle between the entrance end of the throat and the entrance diameter D is an arc of a circle having a radius R. One end of this are is tangent to the cylindrical throat at its entrance end, and the other end intersects the entrance diameter D.
  • the internal profile will approach a cylinder, which profile is not as long lived as the profile of the invention, as will appear more clearly from the test data below.
  • the pressure loss increases, which comprises another practical limitation on length L. Lengths L within the range of about 1% inches to about 4 /2 inches are suitable, and length L in the range of about 2%. inches to about 3 /2 inches are preferred.
  • Throat T increases nozzle life as explained above. However, there appears to be a maximum length of throat T for any particular nozzle beyond which the nozzle wears permaturely. The reason for this is thought to be that in such long throats, the abrasive particles bulfet about, which causes them to lose momentum, and which also causes them to enlarge diameter throughout throat T as well as in the outlet face of the nozzle. It is also thought that the flow stream passing through an overly long throat may experience a vena contracta, and the resultant downstream expansion will cause excessive wear at the outlet face, the most critical area. Throat lengths T in the range of about /2 inch to about 1V2 inch are suitable, and throat lengths T in the range of about 4 inch to about 1% inches are preferred for nozzles having an outlet diameter of inch.
  • the drill bit carries a plurality of nozzles, as described above.
  • the number of nozzles ranges from 12 to 30. The total flow is thus broken into a relatively large number of relatively small jets.
  • exit diameters d in the range of about inch to about A inch have been found to be suitable, and exit diameters d in the range of about of an inch to about of an inch are preferred.
  • the entrance diameter D is the largest internal opening of the nozzle. Entrance diameters D in the range of about inch to about /2 inch are suitable, and entrance diameters D in the range of about inch to /2 inch are preferred. Dimension OD, described below, determines an upper limit to dimension D'.
  • the profile of the entrance section of the nozzle is a circular arc tangent to the cylindrical throat T where it joins length L, and which passes through entrance diameter D.
  • the radius R of this circle is shown in FIG. 5.
  • Nozzles having values of R within the range of about 30 inches to 175 inches are suitable.
  • Nozzles having values of R between about 50 inches and about 140 inches are preferred in nozzles restricted to lengths L in its preferred range.
  • the interrelationship between d, D, L, and R is such that if any three of these parameters are selected, the fourth parameter can have but one value.
  • the principal parameters in the design of a nozzle are d, T, L, and R.
  • OD is the dimension OD. It is desirable to have OD as small as possible to avoid interference between nozzles in the drill head, and to conserve the material of which the nozzle is fabricated.
  • the dimension OD is controlled by the internal configuration or profile of the nozzle and by manufacturing considerations; for example, an excessively high slimness ratio will cause warping of the nozzle during manufacture.
  • a cylindrical external shape is preferred because of ease of insertion into the bit, and because of economy of use of material. ODs in the range of about A inch to about inch are suitable, and ODs in the range of about inch to about /2 inch are preferred. In some cases, where the entrance diameter D is large, the entrance end can be made somewhat bell-shaped, with the remainder of the nozzle remaining cylindrical.
  • Tapered portion 15 may describe a relatively small included angle; an angle of from 6 to 8 has been found satisfactory. This tapered portion is used to hold the nozzle wedged in the drill bit, as described above. As will be clear to one skilled in the art, other means, such as cooperating shoulders, sealants, or the like, could be used to hold the nozzle in the bit.
  • a nozzle 121 which comprises a cylinder.
  • the outside diameter was about /2 inch
  • d was about /a inch
  • L was about 1 inch.
  • Nozzle 121 and all the nozzles in the following figures were fabricated from the same grade of sintered tungsten carbide. This nozzle was tested for 60 minutes by discharging water containing 6% of 20-40 mesh sand through the nozzle at a rate resulting in a pressure drop through the nozzle of 5000 psi. Measurements were taken about every 5 minutes for the first l5, and about every 15 minutes thereafter.
  • FIG. 60 In FIG. 60 is shown a nozzle 123, having an internal profile which was generated by a quarter section of an ellipse, the remainder of the ellipse being indicated by the dotted line.
  • Nozzle 123 had a d of about A; inch, D about inch, and L about inch. This nozzle was run for minutes, and measurements were taken as for nozzle 121'.
  • wear refers to the enlargement of dimension d in the outlet face of the nozzle.
  • Nozzle Wear rate, mils/ hr. 121 15.2 122 103.0 123 12.3
  • the two sets of figures can accurately be compared by merely doubling: the wear rates for the nozzles 50, or halving the wear rates for the three nozzles above. Making this correction, it can be seen that the nozzles embodying the internal profile of the invention have significantly lower Wear rates than the other internal profiles tested.
  • nozzles used had a T equal to about /2 inch, L equal to about 2 /2 inches, and d equal to about A; inch.
  • the arcuate profile nozzles had an R of about inches.
  • the slurry used was water based, and comprised 2% to 3% Flosal (a type of asbestos fiber), and 3% to 4% Bentonite, under a working pressure across the nozzle of 5,000 p.s.i. Two percent of each of the abrasives was included.
  • the abrasive was 5-230 cast iron shot, having a hardness of about 63 on the R scale, and a size of 20 to mesh.
  • Linear Arcuate Material Material A B A B Time, Minutes Min. Max. Min. Max. Min. Max. Min Max.
  • the wear rate for the linear taper is about 71% greater than that for the arcuate profile with material B, and about 26% for material A.
  • the linear taper wears approximately 110% and 91% faster for the two materials, and when shot plus sand is used as the abrasive, the linear taper wears about 40% and 35% faster for the A and B materials, respectively.
  • the wear rates of nozzles embodying the invention were significantly lower than those of the other profiles tested, although slightly diiferent abrasives were used. It can also be seen that the type of material has an etfect on life, but this parameter does not form a part of the present invention.
  • the wear rate of arcuate profile nozzles can be reduced below those rates obtained during the tests reported by increasing the radius R of the arcuate profile.
  • nozzles 50 used in bit 18 have as high a cutting or penetration rate as possible.
  • the two factors of wear rate and cutting rate are basically independent yet interrelated. That is, a nozzle must both run for a reasonable time without excessive Wear, and also cut a reasonable speed, to be economically practical. Either a high cutting rate or a low wear rate alone is not sufficient.
  • a nozzle having the arcuate profile of nozzle 50 of FIGS. 4 and 5 was tested against three other nozzles having other internal profiles, and the results are reproduced below:
  • test constants were: Black Granite target, nozzle rotated at 26 r.p.rn. on 1 /2 inch radius thus cutting 3 inch circle, working pressure of 5 000 p.s.i., /2 inch standoff nozzle to target, slurry was Flosal Bentonite with a 1% concentration of abrasive, and the abrasive was .028 inch average diameter steel shot with a hardness of 63.8 R
  • a nozzle for use in hydraulic jet drilling comprising an elongated body, said body being formed with a longitudinal opening extending through its length, the inlet end of said opening comprising an entrance orifice, the outlet end of said opening comprising an exit orifice having a diameter in the range of to 7 inch, said entrance orifice being of larger cross-sectional area than said exit orifice, said opening comprising a constant cross-sectional area throat portion extending from said exit orifice for a predetermined distance in the range of /2 inch to 1 /2 inches toward said entrance orifice, the profile of said opening between said entrance orifice and the inlet end of said throat portion being formed by a convex curved surface having a length in the range of 1 /2 inches to 4 /2 inches that is substantially an arc of a circle having one end tangent to the inlet end of said throat portion, and the radius of said are being in the range of about 30' inches to about 175 inches.
  • a drill bit for use in hydraulic jet drilling comprising a hollow drill bit body closed at its lower end by a bottom member having a plurality of nozzles extending through the bottom member, each of said nozzles comprising an elongated body, said body being formed with a longitudinal opening extending through its length, the inlet end of said opening comprising an entrance orifice, the outlet end of said opening comprising an exit orifice having a diameter in the range of inch to inch, said entrance orifice being of larger cross-sectional area than said exit orifice, said opening comprising a constant crosssectional area throat portion extending from said exit orifice for a predetermined distance in the range of /2 inch to 1 /2 inches toward said entrance orifice, the profile of said opening between said entrance orifice and the inlet end of said throat portion being formed by a convex curved surface having a length in the range of 1 /2 inches to 4 /2 inches that approximates an arc of a circle having one end tangent to the inlet end of said throat portion, and
  • a drill bit for use in hydraulic jet drilling comprising a bit member having a plurality of nozzles mounted in the lower end thereof, said bit member comprising an elongated tubular body adapted to be connected to the lower end of a drill string, said tubular body having a central opening extending downwardly therethrough cornmunicating with the drill string and with said nozzles, each of said nozzles comprising an elongated nozzle body, said nozzle body being formed with a longitudinal opening defining an entrance orifice at its inlet end and an exit orifice having a diameter in the range of inch to 7 inch at its outlet end, said opening further comprising a constant cross-sectional area throat portion extending for a predetermined distance in the range of /2 inch to 1 /2 inches from said exit orifice toward said entrance orifice, the profile of said opening between said entrance orifice and the inlet end of said throat portion being formed by a convex curved surface having a length in the range of 1 /2 inches to 4 /2 inches that is substantially an

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US771382A 1968-10-15 1968-10-15 Hydraulic drilling bit and nozzle Expired - Lifetime US3469642A (en)

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Cited By (25)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4111261A (en) * 1977-03-14 1978-09-05 Halliburton Company Wellhead isolation tool
US4262743A (en) * 1979-09-04 1981-04-21 Halliburton Company Diffuser for wellhead isolation tool
US4852800A (en) * 1985-06-17 1989-08-01 Flow Systems, Inc. Method and apparatus for stablizing flow to sharp edges orifices
US5199512A (en) * 1990-09-04 1993-04-06 Ccore Technology And Licensing, Ltd. Method of an apparatus for jet cutting
US5251817A (en) * 1991-09-16 1993-10-12 Ursic Thomas A Orifice assembly and method providing highly cohesive fluid jet
US5291957A (en) * 1990-09-04 1994-03-08 Ccore Technology And Licensing, Ltd. Method and apparatus for jet cutting
US5542486A (en) * 1990-09-04 1996-08-06 Ccore Technology & Licensing Limited Method of and apparatus for single plenum jet cutting
US5862871A (en) * 1996-02-20 1999-01-26 Ccore Technology & Licensing Limited, A Texas Limited Partnership Axial-vortex jet drilling system and method
US20060011386A1 (en) * 2003-04-16 2006-01-19 Particle Drilling Technologies, Inc. Impact excavation system and method with improved nozzle
US20060016622A1 (en) * 2003-04-16 2006-01-26 Particle Drilling, Inc. Impact excavation system and method
US20060180350A1 (en) * 2003-04-16 2006-08-17 Particle Drilling Technologies, Inc. Impact excavation system and method with particle trap
US20060191717A1 (en) * 2003-04-16 2006-08-31 Particle Drilling Technologies, Inc. Impact excavation system and method with two-stage inductor
US7383896B2 (en) 2003-04-16 2008-06-10 Particle Drilling Technologies, Inc. Impact excavation system and method with particle separation
US20080230275A1 (en) * 2003-04-16 2008-09-25 Particle Drilling Technologies, Inc. Impact Excavation System And Method With Injection System
US20090038856A1 (en) * 2007-07-03 2009-02-12 Particle Drilling Technologies, Inc. Injection System And Method
US20090126994A1 (en) * 2007-11-15 2009-05-21 Tibbitts Gordon A Method And System For Controlling Force In A Down-Hole Drilling Operation
US20090200084A1 (en) * 2004-07-22 2009-08-13 Particle Drilling Technologies, Inc. Injection System and Method
US20090200080A1 (en) * 2003-04-16 2009-08-13 Tibbitts Gordon A Impact excavation system and method with particle separation
US20090205871A1 (en) * 2003-04-16 2009-08-20 Gordon Tibbitts Shot Blocking Using Drilling Mud
US20100155063A1 (en) * 2008-12-23 2010-06-24 Pdti Holdings, Llc Particle Drilling System Having Equivalent Circulating Density
US7798249B2 (en) 2003-04-16 2010-09-21 Pdti Holdings, Llc Impact excavation system and method with suspension flow control
US20100294567A1 (en) * 2009-04-08 2010-11-25 Pdti Holdings, Llc Impactor Excavation System Having A Drill Bit Discharging In A Cross-Over Pattern
US7987928B2 (en) 2007-10-09 2011-08-02 Pdti Holdings, Llc Injection system and method comprising an impactor motive device
US8037950B2 (en) 2008-02-01 2011-10-18 Pdti Holdings, Llc Methods of using a particle impact drilling system for removing near-borehole damage, milling objects in a wellbore, under reaming, coring, perforating, assisting annular flow, and associated methods
US20230133889A1 (en) * 2021-10-29 2023-05-04 National Oilwell DHT, L.P. Particle impact drill bits and associated methods

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US1104965A (en) * 1913-11-17 1914-07-28 Walter H Coles Nozzle.
US2583726A (en) * 1948-01-26 1952-01-29 Chalom Joseph Aaron Nozzle
US3066735A (en) * 1960-05-25 1962-12-04 Dow Chemical Co Hydraulic jetting tool
US3112800A (en) * 1959-08-28 1963-12-03 Phillips Petroleum Co Method of drilling with high velocity jet cutter rock bit
US3178121A (en) * 1962-04-24 1965-04-13 Du Pont Process for comminuting grit in pigments and supersonic fluid energy mill therefor
US3300142A (en) * 1963-06-25 1967-01-24 Whittaker Corp Rocket nozzle capable of inducing flow separation

Patent Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US1104965A (en) * 1913-11-17 1914-07-28 Walter H Coles Nozzle.
US2583726A (en) * 1948-01-26 1952-01-29 Chalom Joseph Aaron Nozzle
US3112800A (en) * 1959-08-28 1963-12-03 Phillips Petroleum Co Method of drilling with high velocity jet cutter rock bit
US3066735A (en) * 1960-05-25 1962-12-04 Dow Chemical Co Hydraulic jetting tool
US3178121A (en) * 1962-04-24 1965-04-13 Du Pont Process for comminuting grit in pigments and supersonic fluid energy mill therefor
US3300142A (en) * 1963-06-25 1967-01-24 Whittaker Corp Rocket nozzle capable of inducing flow separation

Cited By (40)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4111261A (en) * 1977-03-14 1978-09-05 Halliburton Company Wellhead isolation tool
US4262743A (en) * 1979-09-04 1981-04-21 Halliburton Company Diffuser for wellhead isolation tool
US4852800A (en) * 1985-06-17 1989-08-01 Flow Systems, Inc. Method and apparatus for stablizing flow to sharp edges orifices
US5199512A (en) * 1990-09-04 1993-04-06 Ccore Technology And Licensing, Ltd. Method of an apparatus for jet cutting
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US5542486A (en) * 1990-09-04 1996-08-06 Ccore Technology & Licensing Limited Method of and apparatus for single plenum jet cutting
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FR2020716A6 (enrdf_load_stackoverflow) 1970-07-17
DE1951964A1 (de) 1970-09-17
GB1266050A (enrdf_load_stackoverflow) 1972-03-08
BE739981A (enrdf_load_stackoverflow) 1970-03-16

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