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WO1999005391A1 - Stabilisateur de colonne de forage - Google Patents

Stabilisateur de colonne de forage Download PDF

Info

Publication number
WO1999005391A1
WO1999005391A1 PCT/US1997/018760 US9718760W WO9905391A1 WO 1999005391 A1 WO1999005391 A1 WO 1999005391A1 US 9718760 W US9718760 W US 9718760W WO 9905391 A1 WO9905391 A1 WO 9905391A1
Authority
WO
WIPO (PCT)
Prior art keywords
wear
resistant
stabilizer
blade
inserts
Prior art date
Application number
PCT/US1997/018760
Other languages
English (en)
Inventor
Robert A. Weiss
Jerry W. Welch
Original Assignee
Weiss Robert A
Welch Jerry W
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 Weiss Robert A, Welch Jerry W filed Critical Weiss Robert A
Publication of WO1999005391A1 publication Critical patent/WO1999005391A1/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
    • 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
    • E21B17/1078—Stabilisers or centralisers for casing, tubing or drill pipes

Definitions

  • the present invention relates to rotary borehole drilling devices. More particularly, the present invention relates to a stabilizer for incorporation into a rotary drill string used in the rotary drilling of a borehole, such as an oil and gas well.
  • drill string In the drilling of earth boreholes such as are required for oil and gas wells, it is common practice to use a rotating drilling bit driven by a long assembly known as a drill string.
  • the drill string can consist of numerous elements, depending upon the type of well being drilled, interengaged by means of screwed connections. All of the drill string components contain a throughbore to transmit drilling fluid or mud under pressure to cool the bit, carry the cuttings, and/or operate a downhole mud turbine or hydraulic motor.
  • one of the drill string components is a stabilizer that consists of a tubular body having screwed or other connections top and/or bottom for engagement with other drill string components, the stabilizer further including a plurality of ribs or blades that engage the wall of the borehole and that define radially opening grooves through which the return drilling fluid can pass upwardly through the borehole.
  • a stabilizer may be used in the string located near the bit and/or in any other location intermediate of the length of the drill string.
  • virtually all of the drill string components, except for the bit and the stabilizer have an outside diameter that is smaller than that of the hole being drilled.
  • a stabilizer One function of a stabilizer is to centralize the neighboring drill string components in the whole, thus preventing or reducing whip, vibration, and wear of other components.
  • an important function of stabilizers is to control the direction of drilling or change in direction in both elevation and azimuth. The latter function has become particularly important in drilling a number of directional wells from one site, e.g., an offshore platform, especially in so-called horizontal wells.
  • the outer surfaces of the stabilizer blades or ribs that contact the wall of the borehole form an interrupted cylinder. These surfaces (contact surfaces), which rub on the formation, are subject to wear, which can become particularly severe when the stabilizer is rotated at very high speed in hard and abrasive formations, such as occurs with a "near-bit stabilizer" used immediately above a bit driven by a downhole motor.
  • one method of reducing wear on the contact surfaces of the blades is to insert plugs of hard material, such as diamond, into blind holes formed in the contact surfaces of the ribs such that the outer surface of each plug is substantially flush with the contact surface of the rib.
  • U.S. Patent No. 5,474,143 discloses a drill bit ream stabilizer wherein a stabilizer having spiral flutes and lands is provided with polycrystalline diamond layer inserts at a leading edge to provide a reamer, the inserts projecting radially outwardly from the spiral lands and adapted to ream a hole substantially the same size as the nominal size of the drill bit.
  • the rotary drill string stabilizer of the present invention includes an elongate, tubular body having a first end and a second end, typically the first end and the second end providing threaded connections whereby the stabilizer can be connected in the drill string.
  • At least three, circumferentially spaced stabilizing blades or ribs are integrally formed on the body of the stabilizer, each blade having a first, lateral wall and a borehole-engaging surface, the intersection of which form a leading edge.
  • Each blade also has a lower end adjacent the first end of the tubular member and an upper end adjacent the second end of the tubular member, each pair of adjacent blades defining a groove therebetween.
  • a wear- resistant formation is positioned in each first lateral wall along the lower edge of each blade, the wear-resistant formation extruding axially along each of the first lateral walls such that an exposed wear-resistant edge is formed closely adjacent the leading edge of each blade.
  • the wear-resistant formation is formed of a material that is harder than the material of said blade and is free of any surface that projects radially outwardly of the borehole-engaging surface.
  • Fig. 1 is a side, elevational view showing one embodiment of the stabilizer of the present invention
  • Fig. 2 is an end view taken along the lines 2-2 of Fig. 1;
  • Fig. 3 is a side, elevational view showing another embodiment of the stabilizer of the present invention.
  • Fig. 4 is an end view taken along the lines 4-4 of Fig. 3;
  • Fig. 5 is an enlarged, cross-sectional view taken along the lines 5-5 of Fig. 3;
  • Fig. 6 is a fragmentary, side elevational view of another embodiment of the present invention.
  • Fig. 7 is a fragmentary, side elevational view of another embodiment of the present invention
  • Fig. 8 is a partial, side elevational view of a three-ribbed stabilizer of the present invention showing the staggering of three sets of wear-resistant inserts on the three ribs, respectively, and showing how in rotated elevation such staggering presents an essentially continuous wear-resistant edge formed by said inserts;
  • Fig. 9 is a fragmentary, side elevational view of another embodiment of the present invention.
  • Fig. 10 is a cross-sectional view taken along the lines 10-10 of Fig. 9.
  • the stabilizer shown generally as 10 is a generally cylindrical, tubular body 12, elongate in nature, and having an axial bore 14 extending generally centrally therethrough.
  • body 12 has an upper cylindrical shank 16 with a threaded box 18 formed therein and a lower cylindrical shank 20 on which is formed a threaded pin 22.
  • box 18 may be formed at the lower end of stabilizer 10 with the pin 22 formed at the upper end of stabilizer 10. Alternately, both ends of stabilizer 10 could use threaded box connections, such as box 18.
  • Integrally formed, e.g., by machining, casting, or some other suitable technique, on body 12 are three circumferentially disposed and equally spaced blades or ribs, shown generally as 24, blades 24 projecting radially outwardly from body 12.
  • Each of blades 24 has a borehole-engaging radially outermost surface 26 (contact surface), a first, lateral side wall 28, and a second, lateral side wall 30.
  • the blades 24 are spiral in nature, each adjacent pair of blades 24 forming a spiral groove 32 therebetween.
  • Lateral side wall 28 can be considered a leading side of blade 24 in the sense that in normal usage in a borehole, stabilizer 10 and the remainder of the drill string would be rotated in a clockwise direction when viewed from the top, i.e., looking down the borehole, or counterclockwise when viewed from the bottom, as shown in Fig. 21 by arrow A.
  • Each of lateral side walls 28 and contact surface 26 on each blade 24 intersect to form a leading edge 34.
  • blades 24 also include lower and upper and lower chamfered surfaces 27 and 29, respectively, that taper from the diameter of contact surface 26 to the diameter of lower shank portion 20 and upper shank portion 16, respectively.
  • the contact surfaces 26 of blades 24 are essentially formed by hard surfacing material 36 in the form of rectangular tiles that are affixed to the hard blades 24 in the well-known fashion.
  • the hard surfacing material 36 can be made of numerous different materials, such as, for example, tungsten carbide, diamond, cubic boron nitride, etc. Additionally, as taught in U.S. Patent No.
  • hard surfacing on the outer borehole-engaging surfaces of the ribs 24 may be accomplished by means of plugs of a hard metallic matrix having a plurality of diamonds held within the matrix, the plugs being located in blind bores in the outer surface of the blades, the outer surface of the plugs being generally flush with the outer borehole- engaging surface of the blades.
  • Stabilizer 10 is also provided with a plurality of wear- resistant inserts 38, which are positioned in lateral wall 28 adjacent the leading edge 34 in a manner and for a purpose to be described more fully hereinafter.
  • FIG. 3 there is shown another embodiment of the stabilizer, designated as 10a, which differs from stabilizer 10 in that the blades 24a are substantially straight, i.e., parallel with the axis passing through bore 14a.
  • ribs 24a have lateral side walls 28a and 30a and outer borehole-engaging surfaces 26a carrying hard surfacing 36a (see Fig. 5).
  • Hard surfacing tiles 36a are received into the outer borehole-engaging surfaces 26a of blades 24a such that the radially outermost surface of hard surfacing tiles 36 is substantially flush with the surface 26a of rib 24a.
  • the hard surfacing tiles are likewise disposed in the contact surface of the blades 24 of stabilizer 10.
  • stabilizer 10a with the exception of the configuration of blades 24a forming straight grooves 32a, is, in all respects, the same as stabilizer 10. Accordingly, as noted, like parts have been numbered the same as the numbering used with respect to stabilizer 10.
  • the contact surfaces 26 and 26a of blades 24, 24a of stabilizers 10, 10a form interrupted cylinders, i.e., interrupted by the grooves 32, 32a, respectively, formed between each adjacent pair of blades 24, 24a.
  • the contact surfaces 26 and 26a lie on a cylindrical surface having a diameter essentially the same as that of the borehole and, accordingly, will engage the borehole as the drill string is rotated.
  • the leading edges 34 and 34a will be the first portion of the blades to contact the borehole for a given rotation of the stabilizers 10, 10a.
  • FIG. 5 there is shown the positioning of the wear-resistant inserts 38a in stabilizer 10a, it being understood that inserts 38 with respect to stabilizer 10 are likewise positioned.
  • Each insert 38 is received in a bore 50 formed in lateral wall 28a adjacent the leading edge 34a.
  • the wear-resistant inserts 38 are positioned in the lateral side wall 28a adjacent the leading edge 34a, the inserts being disposed along each of the lateral walls 28a in axial juxtaposition to one another.
  • inserts 38a have an exposed wear-resistant edge 52 that lies closely adjacent leading edge 34a. However, as can also be seen, no surface of insert 38 projects radially outwardly of contact surface 26a.
  • no surface of the wear-resistant formation e.g., inserts 38
  • the stabilizer would become a reamer and would enlarge the hole to above the desired gauge.
  • the stabilizer and the bit gauge are the same. Allowing the stabilizer to ream a larger hole than is being drilled by the bit would, in many cases, permit the drill string to wobble with all of the undesirable side effects discussed above.
  • the metal 54 forming leading edge 34a of blade 24a will eventually wear away, causing the hard surfacing tiles 38 to break away from surface 26a such that eventually the blades 24a will wear away to the point where the centralizing function of the stabilizer 10a will be effectively lost.
  • the cylindrical diameter of stabilizer 10a is reduced so that it is under gauge, i.e., smaller than the gauge of the drill bit and, accordingly, smaller than the gauge of the hole being drilled. This will allow wobbling of the drill string, resulting in erratic drilling direction, as well as increased fatigue failure of the drill string components.
  • the wear-resistant inserts 38 are disposed along the leading or lower end of the ribs 24, 24a, since it is these portions of the blades that are the most subject to wear as they encounter the walls of the borehole first during the drilling operation. Accordingly, it is this portion of the blades that is the most susceptible to rapid wearing, leading to premature failure of the stabilizers.
  • wear-resistant inserts can be placed in the lateral walls along the full length thereof in the manner described above, i.e., positioned such that they are in axial juxtaposition and have an exposed wear-resistant edge that is closely adjacent and parallel to the leading edge. Such a stabilizer is shown in Fig.
  • FIG. 6 shows another embodiment of the present invention wherein the stabilizer, shown generally as 10c, which structurally is essentially the same as stabilizer 10a, incorporates wear-resistant inserts 38 at the upper and lower ends of the blades 24; i.e., the wear-resistant inserts do not extend along the full length of the blades, as shown in Fig. 7.
  • Positioning the wear-resistant inserts 38c at both the upper and lower ends of the stabilizer 10c protects the stabilizer contact surfaces from wear whenever the borehole is being back-reamed or when the drill string is being pulled out of the hole. It will be appreciated, for example, that if the drill string is pulled out of the hole, i.e., in the direction of arrow B, as the string is rotated, the upper end of the stabilizer 10c, i.e., adjacent chamfered surfaces 29, 29a and hence the upper ends of the blades 24a, will initially engage the borehole walls, with the result that wearing will be concentrated at the upper end of the blades 24a.
  • the wear-resistant inserts on each of the blades are in a staggered relationship to one another, i.e, in the axially juxtaposed position such that when viewed in side elevation, rotated profile, the exposed wear-resistant edges of the inserts that lie closely adjacent the leading edges of the blades present an essentially continuous wear- resistant edge adjacent the leading edge of the blade.
  • Fig. 8 there are shown the three separate blades of a stabilizer, such as stabilizer 10a, in Fig. 3, the blades being indicated generally as 50, 60, and 70.
  • wear-resistant inserts 52 are positioned in the side wall 54.
  • inserts 52 are, as described above, in axial juxtaposition to one another and have an exposed wear- resistant edge 56 that lies closely adjacent leading edge 58.
  • the wear-resistant inserts 62 are likewise positioned in the lateral wall 64, an exposed wear-resistant edge 66 lying closely adjacent the leading edge 68. Note, however, that inserts 62 are axially displaced relative to inserts 52.
  • inserts 72 are positioned in lateral side wall 74 such that an exposed wear- resistant edge 76 of inserts 72 lies closely adjacent leading edge 78.
  • inserts 72 are axially displaced both with respect to inserts 62 on rib 60 and inserts 52 on rib 50.
  • the expression "closely adjacent said leading edge” and similar terms referring to the positioning of the wear-resistant edge of the wear-resistant formation relative to the leading edge is intended to mean that, depending upon the nature of the wear-resistant formation, the wear-resistant edge thereof is as close as possible to the leading edge such that the relatively soft metal forming the leading edge will be protected from any abrasion or wearing.
  • the wear-resistant edges thereof may not lie exactly adjacent the leading edge, they will be positioned as closely thereto as practicable, consistent with maintaining the structural integrity of the stabilizer blades and the inserts.
  • the wear-resistant inserts that are used in the present invention can be virtually any shape provided that no surface of the insert projects radially outwardly of the contact surface formed on the blade. However, for ease of installation, it is preferred that the inserts have a cylindrical shank that can be received in a cylindrical blind bore drilled in the lateral walls of the stabilizer blades.
  • the portion of the wear-resistant inserts that forms the wear-resistant edge can be made of numerous materials that are harder than the material of the ribs to which it is attached.
  • the wear-resistant material will have a hardness of at least 60 Rockwell or greater. Suitable wear-resistant materials include tungsten carbide, polycrystalline diamond, cobalt boron nitride, etc.
  • wear-resistant materials that can withstand abrasion in hard formations and that can be bonded or otherwise affixed to mild steel, stainless steel, or the like are well known to those skilled in the art.
  • the wear-resistant inserts can be made, for example, with a cemented carbide body or shank that is received in a bore in the stabilizer blade to which is bonded, directly or through an intermediate transition layer, a polycrystalline diamond layer.
  • the transition layer will generally comprise a composite material containing diamond crystal, cobalt, and pre-cemented tungsten carbide particles.
  • the diamond crystal content of the composite material is greatest adjacent the wear-resistant or outermost surface and lowest adjacent the cemented tungsten carbide body or shank.
  • Fig. 9 there is shown another embodiment of the present invention wherein the wear-resistant formation comprises a continuous insert of wear-resistant material that is deposited, or somehow affixed, to the lateral walls adjacent the leading edge of the blades.
  • a stabilizer 90 that structurally is in all respects essentially the same as stabilizer 10a and that includes a continuous wear-resistant formation 92 denning a wear-resistant edge 94 that lies closely adjacent the leading edge 34a of blade 24a.
  • wear-resistant formation 92 is received in a groove 96 in wall 28a and extends the full length of blade 24a, much in the manner of the inserts 38 shown in Fig. 7.
  • wear-resistant formation 92 would be positioned adjacent the lower end, i.e., adjacent shank 20 of stabilizer 90.
  • wear-resistant formation 92 is essentially shown as having a rectangular configuration and cross-section and extending relatively deeply into side wall 28a, it will be appreciated that wear-resistant formation 92 could be formed using hard surfacing tiles 36 abutted in end-to-end relationship so as to lie along and parallel to the leading edge 34a. It will also be apparent that wear-resistant formation 92 can be formed of numerous materials, as described above with respect to wear-resistant inserts 38.
  • the wear-resistant edge can be a discontinuous series of wear-resistant edge segments, such as are provided by the wear-resistant inserts 38, or can be a continuous, uninterrupted wear-resistant edge, such as is provided by the use of wear-resistant formation 92.
  • the angle at which the inserts are positioned on the blade can be varied such that the wear-resistant inserts serve only to protect the leading edges of the blades or, in certain cases, such that the stabilizer can perform a reaming function.
  • the latter would be desirable when, for example, the borehole has gone undergauge because of wearing of the bit or because of the particular nature of the formation, the borehole has essentially collapsed around the drill string.
  • the angle can vary from about 0° to about 35°, as determined, as shown in Fig. 5, by the angle, ⁇ , determined by the intersection of a line x passing through the centerline of the stabilizer and a line y passing across the face 100 of the wear-resistant insert. As shown in Fig. 5, the angle is about 15 to 18°.
  • the stabilizer would become more aggressive as a reamer in the cases noted above, i.e., when the borehole has gone undergauge because of bit wearing or there has been a collapse of the hole around the drill string.
  • the angle will be from about 15 to about 20 ° .

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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 un stabilisateur (10), destiné à être utilisé dans le forage rotary d'un trou de sonde terrestre. Ce stabilisateur est constitué d'un corps tubulaire allongé (12) et d'au moins trois lames de stabilisation circonférentielles (24), intégrées à ce corps (12), chacune de ces lames (24) présentant une première paroi latérale (28) et une surface (26) destinée à entrer en contact avec le trou de sonde. L'intersection de cette paroi latérale (28) et de cette surface (26) destinée à entrer en contact avec le trou de sonde forme un bord avant (34), chaque paire de lames adjacentes définissant une rainure (32) entre ces lames adjacentes. Des inserts résistants à l'usure (38) sont placés axialement le long de chaque première paroi latérale (28), au moins le long de l'extrémité inférieure de chaque lame (24), ces inserts résistants à l'usure (38), qui présentent un bord résistant à l'usure adjacent audit bord avant (34), étant fabriqués dans un matériau plus dur que celui des lames (24) et ne présentant aucune surface saillant radialement à l'extérieur de ladite surface (26) destinée à entrer en contact avec le trou de sonde.
PCT/US1997/018760 1997-07-25 1997-10-14 Stabilisateur de colonne de forage WO1999005391A1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US90016997A 1997-07-25 1997-07-25
US08/900,169 1997-07-25

Publications (1)

Publication Number Publication Date
WO1999005391A1 true WO1999005391A1 (fr) 1999-02-04

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Application Number Title Priority Date Filing Date
PCT/US1997/018760 WO1999005391A1 (fr) 1997-07-25 1997-10-14 Stabilisateur de colonne de forage

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WO (1) WO1999005391A1 (fr)

Cited By (12)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6234261B1 (en) 1999-03-18 2001-05-22 Camco International (Uk) Limited Method of applying a wear-resistant layer to a surface of a downhole component
FR2824104A1 (fr) * 2001-04-27 2002-10-31 Smf Internat Element profile pour un equipement de forage rotatif et applications a des composants d'un train de tiges de forage
AU784676B2 (en) * 1999-12-17 2006-05-25 Qlt Usa, Inc Pharmaceutical gel and aerosol formulations and methods to administer the same to skin and mucosal surfaces
GB2468781A (en) * 2009-03-20 2010-09-22 Turbopower Drilling Sal Downhole drilling assembly
US8336645B2 (en) 2009-08-28 2012-12-25 Arrival Oil Tools, Inc. Drilling cuttings mobilizer and method for use
US8752753B2 (en) 2008-12-22 2014-06-17 Mark Russell Wear piece element and method of construction
GB2517595A (en) * 2013-08-20 2015-02-25 Hunting Energy Services International Ltd Improvements in or relation to tools
US9151118B2 (en) 2010-11-29 2015-10-06 Arrival Oil Tools, Inc. Reamer
US9683415B2 (en) 2008-12-22 2017-06-20 Cutting & Wear Resistant Developments Limited Hard-faced surface and a wear piece element
BE1028839B1 (fr) * 2020-11-30 2022-06-28 Diarotech Sa Nouvelle technique de revêtement pour pièces d'usure
EP4230201A1 (fr) 2022-02-21 2023-08-23 Universidade Nova De Lisboa Composition pour le traitement de maladies neurodégénératives
WO2023156983A1 (fr) 2022-02-21 2023-08-24 Universidade Nova De Lisboa Composés et compositions contre des maladies neurodégénératives

Citations (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3978933A (en) * 1975-01-27 1976-09-07 Smith International, Inc. Bit-adjacent stabilizer and steel
US4610316A (en) * 1984-11-23 1986-09-09 Lor, Inc. Free flow stabilizer
US4630694A (en) * 1985-10-16 1986-12-23 Walton Paul G Integral blade hole opener
US4982802A (en) * 1989-11-22 1991-01-08 Amoco Corporation Method for stabilizing a rotary drill string and drill bit
US5012863A (en) * 1988-06-07 1991-05-07 Smith International, Inc. Pipe milling tool blade and method of dressing same
US5027914A (en) * 1990-06-04 1991-07-02 Wilson Steve B Pilot casing mill
US5341888A (en) * 1989-12-19 1994-08-30 Diamant Boart Stratabit S.A. Drilling tool intended to widen a well

Patent Citations (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3978933A (en) * 1975-01-27 1976-09-07 Smith International, Inc. Bit-adjacent stabilizer and steel
US4610316A (en) * 1984-11-23 1986-09-09 Lor, Inc. Free flow stabilizer
US4630694A (en) * 1985-10-16 1986-12-23 Walton Paul G Integral blade hole opener
US5012863A (en) * 1988-06-07 1991-05-07 Smith International, Inc. Pipe milling tool blade and method of dressing same
US4982802A (en) * 1989-11-22 1991-01-08 Amoco Corporation Method for stabilizing a rotary drill string and drill bit
US5341888A (en) * 1989-12-19 1994-08-30 Diamant Boart Stratabit S.A. Drilling tool intended to widen a well
US5027914A (en) * 1990-06-04 1991-07-02 Wilson Steve B Pilot casing mill

Cited By (22)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6575350B2 (en) 1999-03-18 2003-06-10 Stephen Martin Evans Method of applying a wear-resistant layer to a surface of a downhole component
US6234261B1 (en) 1999-03-18 2001-05-22 Camco International (Uk) Limited Method of applying a wear-resistant layer to a surface of a downhole component
AU784676B2 (en) * 1999-12-17 2006-05-25 Qlt Usa, Inc Pharmaceutical gel and aerosol formulations and methods to administer the same to skin and mucosal surfaces
FR2824104A1 (fr) * 2001-04-27 2002-10-31 Smf Internat Element profile pour un equipement de forage rotatif et applications a des composants d'un train de tiges de forage
US6732821B2 (en) 2001-04-27 2004-05-11 S.M.F. International Profiled element for rotary drilling equipment and applications to components of a string of drill pipes
US8752753B2 (en) 2008-12-22 2014-06-17 Mark Russell Wear piece element and method of construction
US9683415B2 (en) 2008-12-22 2017-06-20 Cutting & Wear Resistant Developments Limited Hard-faced surface and a wear piece element
CN102300663B (zh) * 2008-12-22 2014-12-17 切割和耐磨损发展有限公司 耐磨件元件及构造方法
GB2468781A (en) * 2009-03-20 2010-09-22 Turbopower Drilling Sal Downhole drilling assembly
US9714543B2 (en) 2009-03-20 2017-07-25 Halliburton Energy Services, Inc. Downhole drilling assembly
GB2476595B (en) * 2009-03-20 2012-05-23 Halliburton Energy Serv Inc Downhole drilling assembly
GB2468781B (en) * 2009-03-20 2011-12-28 Halliburton Energy Serv Inc Downhole drilling assembly
US9249630B2 (en) 2009-03-20 2016-02-02 Halliburton Energy Services, Inc. Downhole drilling assembly
US10119336B2 (en) 2009-03-20 2018-11-06 Halliburton Energy Services, Inc. Downhole drilling assembly
GB2476595A (en) * 2009-03-20 2011-06-29 Turbopower Drilling Sal Downhole drill motor stabiliser
US8336645B2 (en) 2009-08-28 2012-12-25 Arrival Oil Tools, Inc. Drilling cuttings mobilizer and method for use
US9151118B2 (en) 2010-11-29 2015-10-06 Arrival Oil Tools, Inc. Reamer
GB2517595A (en) * 2013-08-20 2015-02-25 Hunting Energy Services International Ltd Improvements in or relation to tools
GB2517595B (en) * 2013-08-20 2016-04-20 Hunting Energy Services International Ltd Improvements in or relation to tools
BE1028839B1 (fr) * 2020-11-30 2022-06-28 Diarotech Sa Nouvelle technique de revêtement pour pièces d'usure
EP4230201A1 (fr) 2022-02-21 2023-08-23 Universidade Nova De Lisboa Composition pour le traitement de maladies neurodégénératives
WO2023156983A1 (fr) 2022-02-21 2023-08-24 Universidade Nova De Lisboa Composés et compositions contre des maladies neurodégénératives

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