WO1990012191A1 - Trepan triangulaire de forage de puits de petrole - Google Patents

Trepan triangulaire de forage de puits de petrole Download PDF

Info

Publication number
WO1990012191A1
WO1990012191A1 PCT/US1990/001886 US9001886W WO9012191A1 WO 1990012191 A1 WO1990012191 A1 WO 1990012191A1 US 9001886 W US9001886 W US 9001886W WO 9012191 A1 WO9012191 A1 WO 9012191A1
Authority
WO
WIPO (PCT)
Prior art keywords
tool body
blade
blade members
cut
drill string
Prior art date
Application number
PCT/US1990/001886
Other languages
English (en)
Inventor
Paul G. Walton
Original Assignee
Walton Paul G
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Walton Paul G filed Critical Walton Paul G
Publication of WO1990012191A1 publication Critical patent/WO1990012191A1/fr

Links

Classifications

    • 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
    • E21B10/42—Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits
    • E21B10/43—Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits characterised by the arrangement of teeth or other cutting elements
    • 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
    • E21B10/46—Drill bits characterised by wear resisting parts, e.g. diamond inserts
    • E21B10/54—Drill bits characterised by wear resisting parts, e.g. diamond inserts the bit being of the rotary drag type, e.g. fork-type bits
    • 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
    • E21B10/46—Drill bits characterised by wear resisting parts, e.g. diamond inserts
    • E21B10/54—Drill bits characterised by wear resisting parts, e.g. diamond inserts the bit being of the rotary drag type, e.g. fork-type bits
    • E21B10/55—Drill bits characterised by wear resisting parts, e.g. diamond inserts the bit being of the rotary drag type, e.g. fork-type bits with preformed cutting elements
    • 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
    • E21B10/602—Drill bits characterised by conduits or nozzles for drilling fluids the bit being a rotary drag type bit with blades

Definitions

  • the present invention relates to oil well drill bits, and more particularly relates to an improved unitary drill bit having particular utility when drilling in medium to hard unconsolidated formations.
  • bit balling is a common problem. This problem results from a heavy accumulation of clay-like material found in the formation which gathers around the bit as it rotates through the formation. The clay-like material actually adheres to the bit rather than flowing away after being cut.
  • Patents related to drill bits used in oil and gas drilling operations include U.S. Patent No. 4,683,965, as well as U.S. Patent Nos. 2,169,223; 1,733,241; 2,490,208; 2,169,223; 1,887,372; 2,838,284; 2,673,716; 2,756,023;
  • Drill bits having tooth-like projections are used in drilling medium to hard formations. Representative drill bits are shown in the 1984-85 General Catalog of Smith Tool, a Division of Smith International, Inc.
  • the present invention is an improvement over prior art drill bits, the preferred embodiment thereof providing a unitary drill bit having a generally triangular shaped cross- section which also narrows at its tip portion, providing three cutting blade portions at the apex of the triangular cross- section of the bit and three flat surfaces spanning between the cutting blades which enhance flow characteristics, i.e., the removal of cuttings through the use of drilling fluids as the well bore is drilled through the formation. Jets are provided between the blades and positioned on the flow surface. Jets may also be positioned on the uppermost flat surfaces of the drilling head which surfaces extend from the cylindrical portion of the drill bit that connects with the drill string.
  • Jets positioned on the upper surfaces of the drill head face away from the drill head and up the well bore toward the drill string so that the drilling fluids will blast even particularly gummy cuttings away from the cylindrical portion of the drill bit.
  • the blades are relatively short so that the close proximity of the jets to the formation enhances the blast of drilling fluids.
  • Each of the three blades carries tooth-like projections or inserts made of tungsten carbide, polycrystalline diamonds and the like.
  • the size of the projections or insets ranges from one-half inch (1.27 cm) to one inch (2.54 cm) wide.
  • the spacing between the projections or inserts generally range from one-half inch (1.27 cm) to three-guarters of an inch (1.905 cm), but may be increased to one inch (2.54 cm).
  • An object of the invention is to provide a drill bit which will perform in medium to hard unconsolidated formations and overcome the problem of "bit balling".
  • Another object of the present invention is to provide a drill bit carrying tooth-like projections or inserts spaced apart from one another and positioned on each blade so that each blade will make a one-third (1/3) cut in the formation during a rotation of the drill head.
  • Another object of the present invention is to provide a drill bit having relatively short blades so that the close proximity of the jets to the formation enhances the blast drilling fluids.
  • Figure 1 is a side view of the preferred embodiment of the apparatus of the present invention.
  • Figure 2 is a side view of the preferred embodiment of the apparatus of the present invention.
  • Figure 3 is a side view of the preferred embodiment of the apparatus of the present invention.
  • Figure 4 is an end view of the preferred embodiment of the apparatus of the present invention.
  • Figure 5 is an end view of the alternative embodiment of the apparatus of the present invention.
  • Figures 6 and 7 show various orientations of the inserts in relation to the surface of the cut.
  • Figure 8 is a side view of the alternative embodiment of the apparatus of the present invention.
  • FIGs 1 and 2 illustrate generally the preferred embodiment of the apparatus of the present invention designated generally by the numeral 10.
  • Drill bit 10 includes a tubular body 12 having at its upper end portion threaded section 14 which is adapted to threadably attach to a drill string D shown in phantom lines in Figure 1.
  • the tool body 12 can provide indentations 13 with flat surfaces, for example, so that a wrench, power tong or the like can be attached to the tool body 12 so that the tool body 12 can be tightened with respect to the drill string D.
  • the central longitudinal axis of tool body 12 is designated as X-X in Figure 1.
  • the center of cylindrical bore 11 (not shown) would coincide with the central longitudinal axis of tool body 12.
  • the lowermost end portion of tool body 12 carries the drill bit cutting portions.
  • Drilling head 15 includes three uppermost generally flat surfaces 16, 17, 18 which are tangent to the outer surface of tool body 12 ( Figures 1, 2, and 3). If tool body 12 were positioned vertically, surfaces 16-18 would define vertical planes tangent the tool body 12 outer surface.
  • the flat sides 16, 17, 18 of bit 15 define a generally triangular shape as shown in Figure 4.
  • a plurality of three cutting blades 22, 23, 24 are mounted generally as shown in Figure 4. Each cutting blade 22-24 carries tooth-like projections 20 spaced apart from one another and along the blades 31, 32, 33 ( Figure 4).
  • Projections 20 can be made of tungsten carbide or polycrystalline diamond material.
  • Projections 20 enhance the ability of bit 10 to drill in medium to hard unconsolidated formations, since projections 20 gouge and shear the formations. Projections 20 may be spaced apart from one another and positioned on blades 22-24, so that each blade 22, 23, 24 will.make a one-third (1/3) cut in the formation during a rotation of the drill head 15. When so positioned, projections 20 gouge the formation so that it breaks apart. Formation cuttings are swept away by blades 22-24.
  • the bottom tip of bit 10 provides a flat hexagonal surface 34 ( Figures 1, 2, and 4). Multiple surfaces 35-40 each respectively form an obtuse angle with lowermost surface 34. Surfaces 35, 37, 39 are smooth and uncoated surfaces having jet openings 41-43 which outcrop at surfaces 35, 37, 39. Each surface 35, 37, 39 is an inclined surface that forms an acute angle with horizontal.
  • Openings 41-44 communicate with jets 45-48 (see Figures 3 and 4).
  • Surfaces 36, 38, 40 contain projection 20. Jets 45-48 allow drilling fluids to flow across surfaces 36, 38, 40 and projections 20 and blast away even gummy formation cuttings.
  • each blade 22, 23, 24 terminates at smooth surfaces 62, 63, 64.
  • each blade 22, 23 is inclined an arcuate angle with respect to vertical as best seen in Figure 1.
  • Surfaces 65, 66, 67 extend from the cylindrical portion of tool body 12 toward the surfaces 62,
  • the entire drill bit 10 can be manufactured of any suitable structural material such as, for example, structural steel with tungsten carbide or polycrystalline diamond projections 20 bonded on each blade 22,23, 24 as shown in Figures 1, 2, 3, and 4.
  • the bonding process requires bores, not shown, to be drilled into blades 22, 23, 24 to receive a bonding material such as a nickel silver compound, not shown, and projections 20.
  • Blades 22, 23, 24, projections 20 and the bonding material are heated to approximately 600o Fahrenheit (320oC) .
  • the bonding material is poured into the bores on blades 22, 23, 24 and projections 20 are inserted into the bores.
  • projections 20 become an integral part of blades 22, 23, 24 and can withstand heat generated during the drilling of oil and gas well bores of up to 1200o Fahrenheit (650oC) without becoming separated from blades 22, 23, 24.
  • drill bit 110 includes a tubular body 112 having at its upper end portion threaded section 14 which is adapted to threadably attach to a drill string.
  • the tool body 112 can provide indentations 13 with flat surfaces, for example, so that a wrench, power tong or the like can be attached to the tool body 112 so that the tool body 112 can be tightened with respect to the drill string.
  • the center of cylindrical bore 11 (not shown) would coincide with the central longitudinal axis of tool body 112.
  • a plurality of three cutting blades 122, 123, 124 are mounted ⁇ generally as shown in Figure 5.
  • Each cutting blade 122, 123, 124 carries inserts 120 spaced apart from one another and along the blades 131, 132, 133 ( Figure 5) .
  • Inserts 120 can be made of tungsten carbide or, preferably, polycrystalline diamond material. Inserts 120 enhance the ability of bit 110 to drill in medium to hard unconsolidated formations, since inserts 120 gouge and shear the formations. Inserts - 120 may be spaced apart from one another and positioned on blades 122-124, so that each blade 122, 123, 124 will make a one-third (1/3) cut in the formation during a rotation of the drill head 115.
  • inserts 120 gouge the formation so that it breaks apart. Formation cuttings are swept away by blades 122-124.
  • the bottom tip of bit 110 provides a flat surface 134 ( Figures 5 and 8).
  • Surfaces 135, 137, 139 are smooth and uncoated surfaces having jet openings 141-143 which outcrop at surfaces 135, 137, 139, respectively.
  • Surfaces 136, 138, 140 contain inserts 120. Jets 145-147 allow drilling fluids to flow across surfaces 136, 138, 140 and inserts 120 and blast away even gummy formation cuttings.
  • blades 122, 123, 124 terminate at smooth surfaces 62, 63, 64, respectively.
  • each blade 122, 123, 124 is inclined an arcuate angle with respect to vertical as best seen in Figure 8.
  • Surfaces 65, 66, 67 extend from the cylindrical portion of tool body 112 toward the surfaces 62, 63, 64 and define the uppermost limits of the enlarged head 115 portion of tool body 112.
  • the entire drill bit 110 can be manufactured of any suitable structural material such as, for example, structural steel with tungsten carbide or polycrystalline diamond inserts
  • the bonding process requires bores 220 ( Figure 7) to be drilled into blades 122, 123, 124 to receive a bonding material such as a nickel silver compound, not shown, and inserts 120.
  • Blades 122, 123, 124, inserts 120 and the bonding material are heated to approximately 600o Fahrenheit (320oC) .
  • the bonding material is poured into the bores 220 on blades 122, 123, 124 and inserts 120 are inserted into bores 220.
  • inserts 120 become an integral part of blades 122, 123, 124 and can withstand heat generated during the drilling of oil and gas well bores of up to 1200o Fahrenheit (650oC) without becoming separated from blades 122, 123, 124.
  • Inserts 120 include a cylindrical cutting portion 222 and a cylindrical insert portion 223, the butting ends of portions 222 and 223 being mitered. Inserts 120 are preferably oriented such that the central axis 221 of the outcropping cylindrical portion 222 of insert 120 is generally parallel to the tangent 310 of the outer curved cut formed by drill bit 110 during use, rather than as shown in Figure 6. It has been found that the orientation of insert 120 shown in Figure 7 extends the useful life of inserts 120.

Landscapes

  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Mechanical Engineering (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Earth Drilling (AREA)

Abstract

Un trépan de forage (10) utilisé dans des formations non consolidées comprend une section généralement triangulaire qui est évasée vers l'extrémité inférieure (34) de la pointe de l'outil (10). Les sommets de la section triangulaire portent des lames (22, 23, 24) qui coupent et définissent la dimension du trou de forage. Des ajutages (45, 46, 47, 48) positionnés entre les lames (22, 23, 24) sur la partie évasée (66) de l'outil et sur la surface supérieure de la tête de l'outil de forage cassent et décomposent le matériau de formation non consolidé qui a été découpé. Des saillies en forme de dent (20) ou des éléments d'insertion (120) constitués en des matériaux tels que le carbure de tungstène et des diamants polycristallins et autres sont ancrés sur les lames et espacés entre eux de sorte que chaque lame fait une entaille d'un tiers dans la formation lorsque la tête de forage accomplit une rotation.
PCT/US1990/001886 1989-04-06 1990-04-06 Trepan triangulaire de forage de puits de petrole WO1990012191A1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US33410089A 1989-04-06 1989-04-06
US334,100 1989-04-06

Publications (1)

Publication Number Publication Date
WO1990012191A1 true WO1990012191A1 (fr) 1990-10-18

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Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/US1990/001886 WO1990012191A1 (fr) 1989-04-06 1990-04-06 Trepan triangulaire de forage de puits de petrole

Country Status (1)

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WO (1) WO1990012191A1 (fr)

Cited By (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP0502610A1 (fr) * 1991-02-01 1992-09-09 Camco Drilling Group Limited Taillants de fleuret et procédé pour la création de tels taillants de fleuret
US7207401B2 (en) 1996-05-03 2007-04-24 Smith International, Inc. One trip milling system
US7455125B2 (en) 2005-02-22 2008-11-25 Baker Hughes Incorporated Drilling tool equipped with improved cutting element layout to reduce cutter damage through formation changes, methods of design and operation thereof
CN103696698A (zh) * 2013-11-12 2014-04-02 湖北中南勘察基础工程有限公司 一种注浆扫孔钻头

Citations (10)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US1923488A (en) * 1931-10-05 1933-08-22 Globe Oil Tools Co Well bit
GB585709A (en) * 1944-08-08 1947-02-20 John Hurditch Improvements in or relating to boring tools
US3043384A (en) * 1958-09-19 1962-07-10 Gault Thomas Glenn Rotary earth drilling bit
SU468987A1 (ru) * 1973-04-13 1975-04-30 Буровое лопастное долото
SU840272A1 (ru) * 1978-09-06 1981-06-23 Новочеркасский Ордена Трудовогокрасного Знамени Политехнический Институтим. Серго Орджоникидзе Инструмент дл вращательного бурени СКВАжиН
US4515227A (en) * 1983-04-27 1985-05-07 Christensen, Inc. Nozzle placement in a diamond rotating bit including a pilot bit
US4683965A (en) * 1986-07-07 1987-08-04 Walton Paul G Triangular oil well drill bit for use in unconsolidated formations
US4711144A (en) * 1984-01-31 1987-12-08 Nl Industries, Inc. Drill bit and method of manufacture
US4733734A (en) * 1984-06-27 1988-03-29 Institut Francais Du Petrole Method and improvement to drilling tools comprising water passages providing great efficiency in cleaning the cutting face
EP0295045A2 (fr) * 1987-06-09 1988-12-14 Reed Tool Company Trépan racleur rotatif avec des buses de nettoyage

Patent Citations (10)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US1923488A (en) * 1931-10-05 1933-08-22 Globe Oil Tools Co Well bit
GB585709A (en) * 1944-08-08 1947-02-20 John Hurditch Improvements in or relating to boring tools
US3043384A (en) * 1958-09-19 1962-07-10 Gault Thomas Glenn Rotary earth drilling bit
SU468987A1 (ru) * 1973-04-13 1975-04-30 Буровое лопастное долото
SU840272A1 (ru) * 1978-09-06 1981-06-23 Новочеркасский Ордена Трудовогокрасного Знамени Политехнический Институтим. Серго Орджоникидзе Инструмент дл вращательного бурени СКВАжиН
US4515227A (en) * 1983-04-27 1985-05-07 Christensen, Inc. Nozzle placement in a diamond rotating bit including a pilot bit
US4711144A (en) * 1984-01-31 1987-12-08 Nl Industries, Inc. Drill bit and method of manufacture
US4733734A (en) * 1984-06-27 1988-03-29 Institut Francais Du Petrole Method and improvement to drilling tools comprising water passages providing great efficiency in cleaning the cutting face
US4683965A (en) * 1986-07-07 1987-08-04 Walton Paul G Triangular oil well drill bit for use in unconsolidated formations
EP0295045A2 (fr) * 1987-06-09 1988-12-14 Reed Tool Company Trépan racleur rotatif avec des buses de nettoyage

Cited By (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP0502610A1 (fr) * 1991-02-01 1992-09-09 Camco Drilling Group Limited Taillants de fleuret et procédé pour la création de tels taillants de fleuret
US7207401B2 (en) 1996-05-03 2007-04-24 Smith International, Inc. One trip milling system
US7455125B2 (en) 2005-02-22 2008-11-25 Baker Hughes Incorporated Drilling tool equipped with improved cutting element layout to reduce cutter damage through formation changes, methods of design and operation thereof
US7703558B2 (en) 2005-02-22 2010-04-27 Baker Hughes Incorporated Drilling tool for reducing cutter damage when drilling through formation changes, and methods of design and operation thereof
CN103696698A (zh) * 2013-11-12 2014-04-02 湖北中南勘察基础工程有限公司 一种注浆扫孔钻头

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