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WO2005001234A1 - Reduction de tiges pour trains de tiges - Google Patents

Reduction de tiges pour trains de tiges Download PDF

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Publication number
WO2005001234A1
WO2005001234A1 PCT/AU2004/000869 AU2004000869W WO2005001234A1 WO 2005001234 A1 WO2005001234 A1 WO 2005001234A1 AU 2004000869 W AU2004000869 W AU 2004000869W WO 2005001234 A1 WO2005001234 A1 WO 2005001234A1
Authority
WO
WIPO (PCT)
Prior art keywords
bit sub
wear
bit
sub
drill
Prior art date
Legal status (The legal status 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 status listed.)
Ceased
Application number
PCT/AU2004/000869
Other languages
English (en)
Inventor
Todd Andrew Haines
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Individual
Original Assignee
Individual
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
Priority claimed from AU2003903315A external-priority patent/AU2003903315A0/en
Priority claimed from AU2003904177A external-priority patent/AU2003904177A0/en
Priority claimed from AU2003907130A external-priority patent/AU2003907130A0/en
Application filed by Individual filed Critical Individual
Publication of WO2005001234A1 publication Critical patent/WO2005001234A1/fr
Anticipated expiration legal-status Critical
Ceased legal-status Critical Current

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
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/10—Wear protectors; Centralising devices, e.g. stabilisers
    • E21B17/1085—Wear protectors; Blast joints; Hard facing
    • 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
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/02—Couplings; joints
    • E21B17/04—Couplings; joints between rod or the like and bit or between rod and rod or the like
    • E21B17/042—Threaded
    • 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
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/02—Couplings; joints
    • E21B17/04—Couplings; joints between rod or the like and bit or between rod and rod or the like
    • E21B17/042—Threaded
    • E21B17/043—Threaded with locking means
    • 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
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/02—Couplings; joints
    • E21B17/04—Couplings; joints between rod or the like and bit or between rod and rod or the like
    • E21B17/07—Telescoping joints for varying drill string lengths; Shock absorbers
    • E21B17/076—Telescoping joints for varying drill string lengths; Shock absorbers between rod or pipe and drill bit

Definitions

  • Field of the Invention relates to a sub-assembly for drill strings.
  • the invention is particularly suitable for, but not limited to, a hard-faced two-part bit sub-assembly for drill strings.
  • bit sub which is arranged to enable relatively easy separation of the two parts. It is a further preferred object to provide a bit sub which incorporates a connecting section, between the first-and-second parts of the bit sub, which is also provided with hard-facing protection. It is a still further preferred object to provide alternative types of hard-facing protection. Other preferred objects will become apparent from the following description.
  • the present invention resides in a two-part bit sub-assembly for drill strings, including: a first, or upper, part releasably engageable with a drill string; a second, or lower, part releasably engageable with a drill bit; releasable coupling means to interconnect the first and second parts; and one or more wear resistant plates, or wear-resistant faces, on an outer face of at least the first part.
  • the present invention resides in a two- part bit sub-assembly for drill strings, including: a first, or upper, part releasably engageable with a drill string; a second, or lower, part releasably engageable with a drill bit; releasable coupling means to interconnect the first and second parts; and at least one wear-resistant casting on or about an outer face of at least the first part.
  • the or each casting is annealed, machined and hardened before application to the first and/or second parts.
  • the or each casting may be formed integrally of the wear- resistant material, eg., tungsten carbide or chromium carbide, or may have a layer of the material about an inner shell, eg., of mild steel.
  • the present invention resides in a two-part bit sub-assembly for drill strings, including: a first, or upper, part releasably engageable with a drill string; a second, or lower, part releasably engageable with a drill bit; releasable coupling means to interconnect the first and second parts; and one or more layers of tungsten machine wear resistant material on an outer face of at least the first part.
  • the first, or upper part may be manufactured in two sections, being an upper cross over sub section connectable to the drill string and a connecting section connecting the upper cross over sub section to the second, or lower, part.
  • the connecting section may be manufactured from high tensile material with a hollow structure, with wear resistant material also applied to, or surrounding, the outer face thereof.
  • the or each casting preferably has a bore with one or more flats or projections which are operably engageable with complementary flats or grooves about the body of the first part to provide rotational driving connection therebetween.
  • the releasable coupling means is a pin-and-box coupling with multiple-start threads, operable to engage the release of the second part from the first part before release of the first part from the drill string.
  • FIG. 1 is a schematic side view of a typical drill string
  • FIG. 2 is a schematic sectional side view of an upper part of the bit sub of a first embodiment of the present invention
  • FIG. 3 is a similar view of a lower part of the bit sub
  • FIG. 4 is a schematic sectional side view of the lower part of the bit sub of a second embodiment
  • FIG. 5 is a similar view of a modified lower part of the bit sub
  • FIG. 6 is a schematic sectional side view of a conventional bit sub to which the present invention may be applied;
  • FIG. 7 is a schematic sectional side view of a bit sub of a third embodiment
  • FIG. 8 is a schematic sectional side view of a bit sub of a fourth embodiment
  • FIGS. 9 and 10 are respective end elevational and side sectional views of a wear-resistant casting for the bit sub
  • FIGS. 1 1 and 1 2 are similar views of a second casting
  • FIG. 1 3 is an end elevational view of the subs of FIGS. 7 and 8
  • FIG. 14 is a sectional side view of a portion of the upper part of a fifth embodiment
  • FIG. 1 5 is a sectional side view of a portion of the upper part fitted with wear-resistant castings
  • FIG . 1 6 is a sectional side view of a casting
  • FIG. 1 5 is a sectional side view of a portion of the upper part fitted with wear-resistant castings
  • FIG. 1 6 is a sectional side view of a casting
  • FIG. 1 5 is a sectional side view of a portion of the upper part fitted with wear
  • FIG. 1 7 is a sectional end view taken on line 1 7-1 7 on FIG. 1 5;
  • FIG. 1 8 is a sectional end view of a further alternative casting;
  • FIG. 1 9 is a schematic sectional side view of the bit sub of a fifth embodiment;
  • FIGS. 20 and 21 are respective end and side elevational views of a spacer ring of the bit sub of FIG. 1 9;
  • FIG. 21 is a schematic sectional side view of a fabricated bit sub of a sixth embodiment.
  • a drill string 1 0 incorporates a top sub 1 1 , one or more drill steels 1 2, a bit sub (or stabilizer) 1 3 and a drill bit 14 adapted to be connected together and passed through a rotating deck bush 1 5.
  • the top sub 1 1 is connected to a suitable rotary drive (not shown) .
  • the conventional bit sub 13 is replaced by a two-part bit sub shown in FIGS. 2 and 3, where the upper part 20 is connected to the drill steel 12 via screw threads 21 on pin 22 and the lower part 40 is connected to the bit 14 via screw-threads 41 in box 42.
  • the bodies 23, 43 of the upper and lower parts are machined from suitable high-tensile steel, with a central air passage 24, 44 therethrough.
  • the upper and lower parts 20, 40 are releasably connectable via pin-and-box-coupling coupling members 45, 25, with threads 46, 26.
  • a typical bit sub 13 would be 1 100mm long and the hydraulic pipe wrench would normally contact the lower part 40 of the bit sub 13 when breaking out the bit 14. To ensure the torque applied to the lower part 40 of the bit sub 13 is effective in unscrewing the bit 14, there can only be one connection between the bit basket and the pipe wrench.
  • the threads 46, 26 connecting the lower and upper parts 40, 20 of the bit sub 13 must be above the pipe wrench when the bit 14 is in the bit basket ready to be removed. As the lower part 40 of the bit sub 13 cannot be hard-faced in the area that the pipe wrench grabs, this part 40 will tend to wear at a higher rate than the protected areas. It is estimated that after 4-7 bits 14 have been worn out, while screwed into the same lower bit sub part 40, the diameter that the pipe wrench grabs will be worn to an unserviceable level. On a Driltech D90 (trade mark) drill, the pipe wrench can only be effective until wear on diameter is around 1 6mm.
  • Both these elements could cause the face ring to bind up in its housing and prevent its function of rotating in housing, acting as a thrust bearing.
  • a nylon ring 460 fitted between the mating faces of the upper and lower parts 20, 40 of the bit sub 1 3 will assist in the easy breaking of the connection.
  • the disclosure of WO 02/08566 forms part of the present description by reference.
  • Heat could possibly be used to expand the female thread 26 on the bottom of the upper part 20 as well as melting the nylon ring 46a, therefore creating additional clearances in the tapered thread.
  • a flat 29 is machined into the upper bit sub part 20 to enable it to be locked into the deck spanner so the drill steel 1 2 immediately above the bit sub can be unscrewed from it.
  • the section of the drill steel 1 2 where the pipe wrench grabs is not hard-faced to enable the dies to grab effectively.
  • the complete outer surface of the drill steel 12 is to be hard-faced, otherwise the life of the drill steel 12 would be compromised and the steel may only last two times longer than a standard component, as the majority of the drill steel has not worn, the area where pipe wrench grabs may be undersized.
  • the pin thread 21 at the top of the upper part 20 would be identical to the pin thread 46 on the top of the lower part, but without the nylon face ring 46a. The idea is for the bit sub to break apart before the connection from the bit sub 13 to the drill steel 12.
  • the connections on the drill steels 12 would be the same as the top thread 21 on the bit sub for standardisation purposes.
  • the process of hard-facing requires application to a round surface.
  • the wrench flats 29 are a problem in this regard and would ideally be machined after hard-facing - however, the hard-facing is too hard to enable a milling cutter to machine the flats 29 after the process. It is, therefore, proposed to mill the flats 29 and fit a steel rectangular block set into the flat which would then be seal-welded to an appropriate depth to prevent expanding gases bubbling through the hard-facing process. The welded blocks would then be machined to blend with the bit sub diameter.
  • a small identifying flat could be milled onto one end of the bit sub section to enable accurate marking out of the location of the flats after hard-facing for an arc-air gouger to remove the temporary blocks.
  • the wear resistant material eg., tungsten carbide, chromium carbide or the like, could be applied by welding to the body 23 of the upper part 20 of the bit sub 13.
  • the wear resistant material eg., tungsten carbide, chromium carbide or the like.
  • an abrasion resistant, eg., chromium carbide casting 47 (that has been annealed, machined and then hardened) is fitted onto a reduced diameter portion 48 of the body 43 - see FIGS. 4 and 5.
  • the benefits of this casting are twofold. Firstly, the casting 47 will have better wear resistance than the hard facing. Secondly, the casting can be replaced at any time the rotary bit 14 is changed as the bit 14 is the mechanism to retain the casting. The ability to renew the lower part 40 in the field will decrease wear above this section as the air flow is sliding past the pipe rather than attacking relatively soft steel directly onto a curve ranging from a 45 degree contact angle to 0 degrees.
  • the weld overlay preferably used on the upper part 20 is a chromium carbide product.
  • the material preferably used for the wear resistant castings 47 is a chromium carbide (white metal) casting that cannot be welded due to its mechanical properties. Other wear-resistant materials may be used to produce the castings. As shown in FIG. 5, the casting 47 may be releasably secured to the body 43 via a locking ring 47a engaged in a groove 48a above the reduced portion 48. As shown in FIG. 6, the annular casting 47 could be applied to a relieved portion 13b in a conventional one-piece bit sub 13.
  • FIGS. 7 and 8 examples 1 13, 213 are illustrated in FIGS. 7 and 8.
  • the determining factor in taking the bit sub 1 13, 213 out of service is the remaining wall thickness. All design efforts to maximise life of the bit sub 1 1 3, 21 3 are focussed on this area.
  • the embodiment hereinbefore described utilises a chromium carbide welded overlay on the upper part 20 of the bit sub 13. At this stage, current technology only allows a thickness of 6-1 2mm of chromium carbide overlay to be applied onto external round surfaces such as pipe and drill string components. In the embodiment of FIGS.
  • bit sub 1 1 3 has a plurality of wear- resistant castings 1 30, 1 31 about the body 1 23 of the upper part 1 20.
  • a wear resistant casting 1 47 is provided adjacent the drill bit 1 4 on the body 143 of the lower part 140 and a wear resistant casting wearing ring 149 is provided between the upper and lower parts 1 20, 140.
  • a tungsten matrix 1 33/1 34 is provided adjacent the wrench flats 1 29.
  • casting 234 is substituted for the wear resistant material 1 33, 1 34.
  • the upper bit sub part 1 20, 220 will have 2, 4, 6 or more flats machined onto its outer diameter (see FIG. 1 3) complementary to the flats 1 39, 239 in the castings (see FIGS. 9 to 1 2).
  • one or more grooves 337 are machined along the body 323 of the upper part 320 of the bit sub 31 3.
  • the castings 330 surround the body 332 - see FIG.
  • FIGS. 7, 8 and 14 an example of assembly of the upper part 1 20, 220, 320 will now be described, particularly in reference to the upper part 220 of FIG. 8.
  • the casting 234 goes on first to provide access to wrench flats 239 and this would be followed by a number of 230 castings. It is an option not to use castings around sections of the wrenching area but rather to deposit a deep layer of hardfacing such as a tungsten matrix or a chromium carbide overlay - see FIGS. 7 and 1 4.
  • the castings 230 will be surface ground parallel to ensure the shoulder of the pin thread 221 on the upper part 220 and the last casting loaded are parallel to within a suitable tolerance. These castings would be retained initially by a locking ring 235 pushing onto casting 231 and then more forcefully by the body 1 42 of the lower part 1 40 when it is screwed into the body 1 23 of the upper part 1 20.
  • the locking ring 235, 1 20 is not intended to axially locate the castings 230 forcefully but rather to stop the castings 230 from sliding off the upper part 1 20 when lower part 140 is changed out when worn to its service limit.
  • An alternate mechanism to retain the castings would be to have a groove machined on the end of the bit sub upper part and then heat up a ring that would expand over a lip and then shrink into the groove as it cools thus providing a very positive simple retainer.
  • the castings 230 could also be retained by two or more grub screws pushing the sleeve in a similar fashion as a taper lock pulley assembly. It is intended for the castings 230 to protrude slightly past the end faces of upper part 1 20 so that when the lower part 140 is tightened onto upper part 1 20, the castings 1 30 will be forced together.
  • the chromium carbide castings for the present invention can be divided into two categories: (i) Castings that, when annealed, can be machined on various machine tools using tungsten carbide inserts.
  • Type 1 castings Another type of Chromium Carbide Casting must be ground to size in specialised grinding machines as they are too hard to machine even in their annealed state. These castings are normally hardened before being ground. They are able to be ground on their faces, outside diameters and inside diameters but they are expensive to grind to complex shapes dur to the constraints in the grinding process. These castings do not suffer distortion after grinding as they do not have to go through a hardening process as they have already been hardened. These castings are categorised as Type 2 castings.
  • Type 2 castings are significantly harder than Type 1 castings and also more resistant to wear. Note the casting product used in following components - see FIG. 8. 247 - Type 1 243 - Type 2 249 - Type 2 230 - Type 2 231 - Type 1 Various alternative materials and heat treatments can be used to produce wear resistant castings - chromium carbide is but one or many materials that could be used. It is possible to produce castings 430 that have a very hard tungsten (carbide) outer section 430a and a mild steel inner section 430b. FIG. 1 9 schematically illustrates a two-part bit sub 51 3, where a wear-resistant tungsten matrix 533 is applied to the upper part 520.
  • the connecting section 560 can be manufactured from high tensile 41 40 hollow bar.
  • a female thread 561 will be cut into the lower end of the connecting section 560 and a male tapered thread or connection will be cut into the upper end.
  • This section 560 will have flats or grooves machined longitudinally into its body 563 to stop wear castings 530 from spinning when under load as previously described.
  • the upper crossover sub section 550 now has a female thread 551 on the bottom and a male thread 552 on the top that screws into the first drill steel 1 2.
  • the upper cross-over sub section 550 will have multiple layers 533 of hard facing applied to the outside diameter to maximise the life of the component.
  • the castings 530 will be located axially by a split groove ring 570 (see FIGS. 20 and 21 ) .
  • the bit sub 520 will be assembled by firstly expanding and fitting the slit retainer ring 570 onto the bottom end of the connecting section 560.
  • the castings 530 will then be slid over the connecting section 560 and up against retainer ring 570.
  • the lower part 540 and the upper crossover sub 550 will then be fitted onto the connecting section 560 and tightened up.
  • the pin connection of the connecting section 560 and the box connection of the upper cross-over sub 550 will have a "super thread locker" Loctite (TM) type product coated on the threads to ensure corrosion is kept out of threads during the months of drilling with compressed air and water being forced down the centre of the pipes and also to lock the threads together during service life.
  • the cavity between the inside of castings 530 and connecting section 560 will then be pumped up with a Loctite (TM) or alternative product to bond castings to middle section.
  • TM Loctite
  • FIG. 22 illustrates a sixth embodiment of the bit sub 61 3, where the upper and lower parts 620, 640 are fabricated.
  • the body 643 of the lower part 640 (eg., manufactured from 440 steel) has, eg., 14mm thick hard facing 647, 649 at the ends of the body 643.
  • the outer face of the body 623, intermediate the hard-faced sections 647, 649, enables the pipe-wrench to grab the body without slipping. Threads 621 in the box-formation 622 allow connection to the drill bit (not shown) .
  • the upper and part 620 has a body with a pin tool joint 623a and a box tool joint 623b (eg., both of 41 40 steel) connected by a connecting pipe section 623c (eg., of 41 06GB steel)
  • a pair of packing rings 623d, 623e assist the welding of the tool joints 623a, 623b, respectively, to the connecting pipe section 623c.
  • Wrench flats 629 are provided on the pin tool joint 623a.
  • Hard-facing 633 eg., 14mm deep, is provided along the body 623 of the upper part 620.
  • the upper part 620 is approximately 3050mm long and the lower part 640 is approximately 3050mm long and the lower part 640 is approximately 650mm long.
  • the threads 646 on the pin 645 on the lower part 640 and the threads 626 in the box 625 of the upper part 620 may be 3- or 4-start threads of the type of WO 02/08566 and a nylon ring 646a, eg., 34mm thick, may be provided between the opposed faces of the upper and lower parts 620, 640 to further aid the release of the parts.
  • bit subs 613 can be manufactured in a wide range of lengths by changing the length of the connecting pipe sections 623c.
  • the hard facing portions 633, 647 and 649 can be substituted by the wear- resistant castings, eg., 230, 230, 247, 249, as hereinbefore described.
  • the present invention provides a drill sub when the first, or upper, part, connected to the drill steel, has a very long life, and the second, or lower, part is consumable and can be replaced more often than the first part, eg., every fifth to tenth drill bit change.
  • Various changes and modifications may be made to the embodiments described and illustrated without departing from the present invention.

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  • 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

L'invention concerne une réduction de tiges en deux parties (13) destinée à un train de tiges (10) et comprenant une partie supérieure (20) possédant des surfaces/pièces coulées résistantes à l'usure permettant d'obtenir une durée de vie relativement importante, ainsi qu'une partie inférieure (40) pouvant s'user. Cette réduction de tiges permet un raccordement libérable lorsque la vie utile de la partie inférieure (40) arrive à son terme à cause de l'usure.
PCT/AU2004/000869 2003-06-30 2004-06-30 Reduction de tiges pour trains de tiges Ceased WO2005001234A1 (fr)

Applications Claiming Priority (6)

Application Number Priority Date Filing Date Title
AU2003903315 2003-06-30
AU2003903315A AU2003903315A0 (en) 2003-06-30 2003-06-30 Sub-assembly for drill strings
AU2003904177 2003-08-08
AU2003904177A AU2003904177A0 (en) 2003-08-08 2003-08-08 Sub-assembly for drill strings
AU2003907130A AU2003907130A0 (en) 2003-12-24 Sub-assembly for drill strings
AU2003907130 2003-12-24

Publications (1)

Publication Number Publication Date
WO2005001234A1 true WO2005001234A1 (fr) 2005-01-06

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Application Number Title Priority Date Filing Date
PCT/AU2004/000869 Ceased WO2005001234A1 (fr) 2003-06-30 2004-06-30 Reduction de tiges pour trains de tiges

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WO (1) WO2005001234A1 (fr)

Cited By (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2009021955A1 (fr) 2007-08-13 2009-02-19 Novo Nordisk A/S Analogues de l'insuline à action rapide
CN103510876A (zh) * 2013-09-30 2014-01-15 无锡中地地质装备有限公司 钻杆的内管与短节的连接结构
US9562404B2 (en) 2008-12-05 2017-02-07 Titus Tools, Inc. Well tubing hanger adapted for use with power tongs and method of using same
WO2017044175A1 (fr) * 2015-09-10 2017-03-16 Hunting Energy Services, Inc. Multi-conducteur à connexion filetée rapide
CN107989557A (zh) * 2017-12-08 2018-05-04 中国石油集团长城钻探工程有限公司 一种页岩气大位移井钻井用井下钻具分离工具
CN110871586A (zh) * 2018-08-31 2020-03-10 安德里茨股份公司 填塞螺杆
WO2024031147A1 (fr) * 2022-08-11 2024-02-15 Todd Haines Accessoire pour trépan

Citations (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2589534A (en) * 1947-07-28 1952-03-18 Ralph Q Buttolph Drill guiding assembly
US3978933A (en) * 1975-01-27 1976-09-07 Smith International, Inc. Bit-adjacent stabilizer and steel
US3993368A (en) * 1975-07-21 1976-11-23 Christensen Diamond Products Company Tool joint wear protectors
GB2164358A (en) * 1984-09-13 1986-03-19 Saipem Spa Method for the surface hardening of drill rod couplings
US6439618B1 (en) * 1998-05-04 2002-08-27 Weatherford/Lamb, Inc. Coiled tubing connector
WO2002097233A1 (fr) * 2001-06-01 2002-12-05 Tubular Protection Systems As (Tps As) Protecteur de tiges
US6530440B1 (en) * 1999-04-26 2003-03-11 Sandvik Ab Percussive drilling apparatus

Patent Citations (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2589534A (en) * 1947-07-28 1952-03-18 Ralph Q Buttolph Drill guiding assembly
US3978933A (en) * 1975-01-27 1976-09-07 Smith International, Inc. Bit-adjacent stabilizer and steel
US3993368A (en) * 1975-07-21 1976-11-23 Christensen Diamond Products Company Tool joint wear protectors
GB2164358A (en) * 1984-09-13 1986-03-19 Saipem Spa Method for the surface hardening of drill rod couplings
US6439618B1 (en) * 1998-05-04 2002-08-27 Weatherford/Lamb, Inc. Coiled tubing connector
US6530440B1 (en) * 1999-04-26 2003-03-11 Sandvik Ab Percussive drilling apparatus
WO2002097233A1 (fr) * 2001-06-01 2002-12-05 Tubular Protection Systems As (Tps As) Protecteur de tiges

Cited By (9)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2009021955A1 (fr) 2007-08-13 2009-02-19 Novo Nordisk A/S Analogues de l'insuline à action rapide
US9562404B2 (en) 2008-12-05 2017-02-07 Titus Tools, Inc. Well tubing hanger adapted for use with power tongs and method of using same
CN103510876A (zh) * 2013-09-30 2014-01-15 无锡中地地质装备有限公司 钻杆的内管与短节的连接结构
WO2017044175A1 (fr) * 2015-09-10 2017-03-16 Hunting Energy Services, Inc. Multi-conducteur à connexion filetée rapide
US10167680B2 (en) 2015-09-10 2019-01-01 Hunting Energy Services, Inc. Multi-lead quick connect threaded connection
CN107989557A (zh) * 2017-12-08 2018-05-04 中国石油集团长城钻探工程有限公司 一种页岩气大位移井钻井用井下钻具分离工具
CN110871586A (zh) * 2018-08-31 2020-03-10 安德里茨股份公司 填塞螺杆
CN110871586B (zh) * 2018-08-31 2021-09-07 安德里茨股份公司 填塞螺杆
WO2024031147A1 (fr) * 2022-08-11 2024-02-15 Todd Haines Accessoire pour trépan

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