EP3023575A1 - Tige de train de tiges avec épaulement - Google Patents

Tige de train de tiges avec épaulement Download PDF

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Publication number
EP3023575A1
EP3023575A1 EP14194246.6A EP14194246A EP3023575A1 EP 3023575 A1 EP3023575 A1 EP 3023575A1 EP 14194246 A EP14194246 A EP 14194246A EP 3023575 A1 EP3023575 A1 EP 3023575A1
Authority
EP
European Patent Office
Prior art keywords
rod
shoulder
outside diameter
section
spigot
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.)
Withdrawn
Application number
EP14194246.6A
Other languages
German (de)
English (en)
Inventor
Per Mattson
David Wickström
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.)
Sandvik Intellectual Property AB
Original Assignee
Sandvik Intellectual Property AB
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 Sandvik Intellectual Property AB filed Critical Sandvik Intellectual Property AB
Priority to EP14194246.6A priority Critical patent/EP3023575A1/fr
Priority to CA2965868A priority patent/CA2965868A1/fr
Priority to MX2017006589A priority patent/MX2017006589A/es
Priority to RU2017121599A priority patent/RU2017121599A/ru
Priority to US15/527,778 priority patent/US20170321496A1/en
Priority to CN201580063020.6A priority patent/CN107002467A/zh
Priority to AU2015348706A priority patent/AU2015348706A1/en
Priority to PE2017000842A priority patent/PE20171231A1/es
Priority to BR112017010617A priority patent/BR112017010617A2/pt
Priority to PCT/EP2015/076502 priority patent/WO2016079013A1/fr
Publication of EP3023575A1 publication Critical patent/EP3023575A1/fr
Priority to ZA201702931A priority patent/ZA201702931B/en
Priority to CL2017001287A priority patent/CL2017001287A1/es
Withdrawn legal-status Critical Current

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP 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
    • E21B17/16—Drill collars
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B1/00—Percussion drilling
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP 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
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP 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
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP 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 DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP 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
    • E21B17/0426—Threaded with a threaded cylindrical portion, e.g. for percussion rods

Definitions

  • the present invention relates to a drill string rod and a rod assembly to form part of a drill string having male and female ends separated by a main length section and in particular, although not exclusively, to a rod having an axially elongate shoulder configured to facilitate straight drilling and extraction of the bit end of the drill string.
  • Percussion drilling is used to create a long borehole via a plurality of elongate drill string rods coupled together end-to-end by interconnected male and female threaded ends.
  • the well-established technique breaks rock by hammering impacts transferred from the rock drill bit, mounted at one end of the drill string, to the rock at the bottom of the borehole.
  • the energy required to break the rock is generated by a hydraulically driven piston that contacts the end of the drill string (via a shank adaptor) to create a stress (or shock) wave that propagates through the drill string and ultimately to the base rock level.
  • Such couplers are typically stiffer than the rods and are intended to be resistant to bending so that the drill bit travels faster and straighter during drilling.
  • Example additional guidance couplers are described in WO 00/65192 ; US 4,874,045 ; EP 0192622 ; CA 2550801 and US 2002/0050362 .
  • conventional and additional intermediate couplers are disadvantageous for a number of reasons. In particular, it is not uncommon for these additional pieces to be misplaced during use. Additionally, due to the inclusion of additional threaded connections, the efficiency of the shockwave transmission to the drill bit is reduced whilst stress in the entire drill string as a whole is increased. There is therefore a need for a drill rod and a drill rod assembly that addresses these problems.
  • a rod provided with a male and a female end in which the male end is configured to form an extension of the drill bit to achieve straighter and faster drilling and in particular improved collaring. It is a further specific objective to prevent or reduce the likelihood of the drill bit becoming jammed in the bore hole when the drill string is extracted.
  • a drill rod having a main length section provided with male and female ends in which the male end is provided with an axially extended guidance collar or shoulder.
  • the elongate shoulder is formed as a radially flared extension of the main length section to provide a stiffer threaded joint section suitable for coupling to female ends of adjacent rods and in particular a female threaded sleeve of a drill bit.
  • the present dill rod is also particularly suitable for drilling relative small bore holes typically of a size approximately 54mm and less.
  • the guidance shoulder of the male end of the present drill rod comprises an axial length that is greater than an outside diameter of the shoulder. That is, the guidance shoulder is flared radially outward relative to the main length section but also extends axially over a greater distance relative to conventional shoulder driven rods so as to form an elongate axial extension of the drill bit.
  • the outside diameter of the shoulder is equal to or approximately equal to the outside diameter of an axially rearward mounting sleeve of the drill bit such that the shoulder of the rod and the rearward portion of the drill bit are interconnected to provide a single elongate cylindrical section having an outside diameter that is greater than the main length section of the rod.
  • Such a configuration is effective to provide both the shoulder driven characteristic for percussion drilling and a system that is stiffer and comprises a potential deviation angle that is less than existing assemblies.
  • Reference within this specification to the deviation angle encompass the angle by which the drill bit may rotate about its axis to the point where the cutting head end of the bit and/or an axially rearwardmost part of the shoulder contact the inward facing surface of the borehole.
  • a drill string rod to form part of a drill string, the rod comprising: a hollow elongate main length section extending axially between a male end and a female end; the male end comprising a spigot having a threaded section projecting axially from a shoulder that axially separates the spigot and the main length section, the shoulder having an outside diameter that is greater than an outside diameter of the main length section; characterised in that: an axial length of the shoulder over which the greater outside diameter extends is greater than the outside diameter of the shoulder.
  • the outside diameter of the shoulder is a maximum outside diameter of the rod.
  • the outside diameter of the shoulder is slightly less than the maximum outside diameter of a drill bit head to assist with guiding the driven rotation during advancement of the drill bit into the rock.
  • the maximum outside diameter of the rod at the shoulder is uniform or approximately uniform over the axial length of the shoulder.
  • Such a configuration is configured to be consistent with an axially rearward female cylindrical mounting sleeve provided at an axially rearward end of the drill bit such that the combined shoulder and drill bit sleeve form a single cylindrical section of uniform outside diameter.
  • the female end comprises a sleeve portion having an internal threaded section to cooperate with the threaded section of the spigot of a further drill rod of the drill string, an outside diameter of the sleeve portion being greater than the outside diameter of the main length section.
  • the outside diameter of the shoulder is equal to or approximately equal to the outside diameter of the sleeve portion.
  • an outside diameter of the female sleeve may be less than the outside diameter of the shoulder.
  • a configuration with equal outside diameters facilitates rod guidance to achieve straighter holes and extraction of the drill string from the bore.
  • the spigot extends axially from an annular end surface of the shoulder, an axial length of the spigot configured such that the annular end surface of the shoulder is capable of abutting an annular end surface of the female end of a neighbouring rod of the drill string.
  • the spigot is divided axially into a threaded section that represents an endmost part of the spigot and a non-threaded shank that is positioned axially intermediate the threaded end section and the annular end surface of the shoulder.
  • an outside diameter of the shank is flared radially outward at the junction with the annular end surface of the shoulder to reduce stress concentrations and any lateral bending of the spigot relative to the shoulder.
  • an axial length of the spigot is less than or equal to the axial length of the shoulder.
  • an outside diameter of the spigot is equal to or less than the outside diameter of the main length section along a full axial length of the spigot.
  • Such a configuration provides an annular end surface at the shoulder configured to abut an annular end surface of a drill bit to achieve the desired shoulder contact coupled configuration.
  • the rod comprises an internal bore extending axially through the main length section and the spigot, the internal bore being of uniform internal diameter along a full axial length of the main length section and the spigot.
  • the uniform internal diameter provides the desired control of the pressure of a flushing fluid delivered internally through the rod to the drill bit.
  • the threaded section of the spigot comprises at least one axially extending helical ridge and trough wherein the outside diameter along the threaded section at radial positions of the ridge and trough is uniform over a full axial length of the threaded section.
  • the threaded section comprises two helical turns extending axially over the spigot configured to mate with corresponding thread turns provided internally within a mounting sleeve of the drill bit and/or the internally threaded female end of neighbouring drill rods.
  • the rod may comprise a transition section positioned axially at a junction of the main length section and the shoulder; wherein an outside diameter at the transition section changes according to at least one radius of curvature.
  • an outside diameter at the transition section decreases radially according to a first radius of curvature from the main length section to an intermediate section and the outside diameter increases radially according to a second radius of curvature from the intermediate section to the shoulder.
  • a drill rod assembly to form part of a drill string, the assembly comprising: a drill rod as claimed herein; a drill bit releasably attachable to the male end of the drill rod; the drill bit having an axially forward cutting head and an axially rearward mounting sleeve to attach to the male end of the drill rod; wherein an outside diameter of the mounting sleeve is equal to or approximately equal to the outside diameter of the shoulder.
  • the outside diameter of the mounting sleeve is uniform or approximately uniform over an axial length of the mounting sleeve being defined between a rearwardmost end of the drill bit and an axially forwardmost end of the mounting sleeve at which region the outside diameter of the mounting sleeve increases to form a junction with the cutting head.
  • the shoulder and mounting sleeve of the drill bit collectively define a single cylindrical section of constant outside diameter being slightly less than a maximum outside diameter of the drill bit head positioned axially forward of the mounting sleeve and the shoulder.
  • the axial length of the shoulder is approximately equal to or less than an axial length of the mounting sleeve.
  • Such a configuration reduces the deviation angle by which the drill bit may be deflected laterally including perpendicular to the longitudinal axis of the drill rod to achieve straighter holes and better collaring.
  • a percussion drill rod 100 comprises an axially extending main length section 101 that is terminated at a first end by a male end indicated generally by reference 103 and at a second opposite end by a female end indicated generally by reference 102.
  • Rod 100 is capable of being coupled end-to-end with adjacent rods to form a drill string.
  • Male end 103 comprises a shoulder 110 that projects radially outward relative to main length section 101 and is formed as a cylindrical section extending over an axial distance being a fraction of the length of main length section 101.
  • female end 102 comprises a cylindrical sleeve section 111 having a length approximately equal to the axial length of shoulder 110.
  • an outside diameter of shoulder 110 and female sleeve 111 are approximately equal.
  • a respective transition section 107 extends axially between main length section 101 and the respective shoulder 110 and female sleeve 111.
  • Each transition section 107 comprises an axial length being slightly less than the axial length of shoulder 110 and female sleeve 111.
  • an outside diameter of each transition section 107 is less than the outside diameter of main length section 101 as described in further detail referring to figure 4 .
  • Figure 1 illustrates drill rod 100 releasably coupled to a drill bit indicated generally by reference 112 of conventional configuration.
  • Drill bit 112 comprises an axially forwardmost drill head 105 that mounts a plurality of wear resistant cutting buttons 106 projecting axially forward from head 105.
  • a mounting sleeve 104 extends axially rearward from head 105 and comprises an internal threaded cavity to receive a male part of male end 103.
  • male end 103 comprises a spigot 204 that projects axially forward from shoulder 110 and in particular an annular abutment surface 108 that represents a forwardmost end of shoulder 110.
  • Abutment surface 108 is positioned in contact with an annular endmost contact surface 109 of drill bit sleeve 104.
  • an axial length of spigot 204 is less than a corresponding axial length or depth of a cavity within bit sleeve 104 such that the present drill rod 100 is configured as a shoulder contact or shoulder driven rod.
  • the shockwave generated by the surface piston is translated through mated surfaces 108, 109 from rod 101 into drill bit 112.
  • an annular endmost surface 303 of spigot 204 is separated axially from the innermost end 600 of the internal cavity within bit sleeve 104 to provide the shoulder contact configuration.
  • releasable mating of rod 100 and bit 112 is achieved by cooperating screw threads 301, 302 projecting radially at spigot 204 and threads 601 projecting radially within the internal facing surface of the bit sleeve cavity.
  • the female end 102 of rod 100 comprises an internal cavity 200 extending axially within sleeve 111 from an axially rearward end surface 202.
  • End surface 202 of a first rod is configured to contact the shoulder abutment surface 108 of the male end 103 of a second rod when multiple drill rods 100 are coupled together end-to-end to form the drill string.
  • Screw threads 201 are provided at the internal facing surface of sleeve cavity 200 and are configured to cooperate with the spigot threads 301, 302 of a neighbouring rod 100.
  • An internal bore 203 extends axially through rod 100 and in particular axially from female cavity 200 to the annular end surface 303 of spigot 204. According to the specific implementation, bore 203 comprises an internal diameter that is substantially uniform over its entire axial length between the male 103 and female 102 ends.
  • spigot 204 projects axially from the annular abutment surface 108 that extends substantially perpendicular to the cylindrical external surface at shoulder 110.
  • Spigot 204 may be considered to be divided axially into threaded section 301, 302 and a non-threaded shank 300 that is positioned axially intermediate threaded section 301, 302 and shoulder 110.
  • Shank 300 is flared radially outward relative to a longitudinal axis 305 of rod 100 at the junction 304 with annular abutment surface 108 such that the external surface of the shank 300 at the shoulder junction 304 increases according to a radius of curvature.
  • the threaded section of spigot 204 comprises a pair of helical ridges 302 that define axially intermediate troughs 301 extending between shank 300 and the annular spigot end surface 303.
  • an axial length L B of spigot 204 including shank 300 and threaded section 301, 302 is less than an axial length L A of shoulder 110.
  • Shoulder length L A is defined axially between annular abutment surface 108 (aligned perpendicular to axis 305) and an axially rearwardmost part of shoulder 110 at which the outside diameter of rod 100 decreases and is no longer uniform in the axially rearward direction from annular abutment surface 108.
  • the rearward end of shoulder 110 is terminated by transition section 107.
  • the axial length L B may be in the range 60 to 100% or 75 to 85% of the axial length L A .
  • Section 107 may be considered to be divided into three axial regions including a first region 401 bordering main length section 101, a second region 402 bordering the rearward end of shoulder 110 and an intermediate region 400 positioned axially intermediate the first and second regions 401, 402.
  • An outside diameter of rod 100 at the first transition region 401 decreases radially according to a first radius of curvature (relative to main length section 101).
  • the outside diameter of rod 100 is substantially uniform over intermediate region 400 and then increases radially according to a second radius of curvature at second region 402. Accordingly, the outside diameter of rod 100 at transition section 107 is formed as an axially broad groove or slight depression positioned axially between main length section 101 and shoulder 110.
  • the radially curved transition 304 minimises stress concentrations at the junction of spigot 204 and shoulder 110. Additionally, the radius of curvature at second transition region 402 minimises stress concentrations at the axially rearward end of the shoulder 110 and the junction with main length section 101.
  • Shoulder 110 comprises an outside or external diameter D A being approximately equal to the outside diameter of female sleeve 111 at female end 102.
  • Outside diameter D A represents the largest outside diameter section of rod 100 along its entire axial length.
  • a corresponding outside diameter of spigot 204 at the threaded section corresponding to a radial position at the peak of each helical ridge 302 is represented by D C when D C is less than D A .
  • D C may be in the range 60 to 100% or 75 to 85% of D A .
  • an external diameter D B of main length section 101 is less than the outside diameter D A of shoulder 110 and according to specific implementations D B is 70 to 100% or 85 to 99% of D A .
  • shoulder 110 effectively provides an axial extension of bit sleeve 104.
  • an outside diameter D E of bit sleeve 104 is substantially equal to the outside diameter D A of shoulder 110 such that the two cylindrical sections 104, 110 collectively define a single cylinder extending between bit head 105 and transition section 107 having a uniform diameter D A , D E over its entire axial length being the combination of L A and the axial length of the bit sleeve L C . It follows therefore that the shoulder axial length L A is greater than the outside diameter D E of bit sleeve 104.
  • Shoulder 110 effectively provides a linear extension of bit sleeve 104 that reduces the possible deviation angle of the bit 112 and male end 103 of rod 100 as it is both inserted and extracted from the hole. That is, any bending or lateral deviation, perpendicular to axis 305 within the bore at the region of bit 112 is reduced and is effectively restricted by the axial length L A of shoulder 110 and in particular the axially rearward end of shoulder 110 contacting the internal surface of the bore.
  • an axial length L C of bit sleeve 104 is defined between the annular contact surface 109 (at the axially rearward end of bit 112) and the axially forwardmost sleeve end 500 at which the outside diameter D E increases to form the radially enlarged drill head 105.
  • bit sleeve axial length L C may be in the range 60 to 100% or 75 to 95% of the shoulder axial length L A .
EP14194246.6A 2014-11-21 2014-11-21 Tige de train de tiges avec épaulement Withdrawn EP3023575A1 (fr)

Priority Applications (12)

Application Number Priority Date Filing Date Title
EP14194246.6A EP3023575A1 (fr) 2014-11-21 2014-11-21 Tige de train de tiges avec épaulement
CN201580063020.6A CN107002467A (zh) 2014-11-21 2015-11-13 具有引导台肩的钻柱钻杆
MX2017006589A MX2017006589A (es) 2014-11-21 2015-11-13 Varilla de sarta de perforacion con saliente de guiado.
RU2017121599A RU2017121599A (ru) 2014-11-21 2015-11-13 Штанга бурильной колонны с направляющим выступом в виде муфты
US15/527,778 US20170321496A1 (en) 2014-11-21 2015-11-13 Drill string rod with guidance shoulder
CA2965868A CA2965868A1 (fr) 2014-11-21 2015-11-13 Tige de train de tiges de forage dotee d'un epaulement de guidage
AU2015348706A AU2015348706A1 (en) 2014-11-21 2015-11-13 Drill string rod with guidance shoulder
PE2017000842A PE20171231A1 (es) 2014-11-21 2015-11-13 Varilla de sarta de perforacion con saliente de guiado
BR112017010617A BR112017010617A2 (pt) 2014-11-21 2015-11-13 haste de corda de perfuração com anteparo de guia
PCT/EP2015/076502 WO2016079013A1 (fr) 2014-11-21 2015-11-13 Tige de train de tiges de forage dotée d'un épaulement de guidage
ZA201702931A ZA201702931B (en) 2014-11-21 2017-04-26 Drill string rod with guidance shoulder
CL2017001287A CL2017001287A1 (es) 2014-11-21 2017-05-18 Vara de sarta de perforación con soporte guía

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
EP14194246.6A EP3023575A1 (fr) 2014-11-21 2014-11-21 Tige de train de tiges avec épaulement

Publications (1)

Publication Number Publication Date
EP3023575A1 true EP3023575A1 (fr) 2016-05-25

Family

ID=51947195

Family Applications (1)

Application Number Title Priority Date Filing Date
EP14194246.6A Withdrawn EP3023575A1 (fr) 2014-11-21 2014-11-21 Tige de train de tiges avec épaulement

Country Status (12)

Country Link
US (1) US20170321496A1 (fr)
EP (1) EP3023575A1 (fr)
CN (1) CN107002467A (fr)
AU (1) AU2015348706A1 (fr)
BR (1) BR112017010617A2 (fr)
CA (1) CA2965868A1 (fr)
CL (1) CL2017001287A1 (fr)
MX (1) MX2017006589A (fr)
PE (1) PE20171231A1 (fr)
RU (1) RU2017121599A (fr)
WO (1) WO2016079013A1 (fr)
ZA (1) ZA201702931B (fr)

Cited By (2)

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Publication number Priority date Publication date Assignee Title
CN109372443A (zh) * 2018-12-14 2019-02-22 无锡双马钻探工具有限公司 一种煤矿整体钻杆
US10627023B2 (en) 2015-05-22 2020-04-21 Sandvik Intellectual Property Ab Threaded coupling end for a percussion drill string component

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US20180100356A1 (en) * 2016-10-10 2018-04-12 Padley & Venables Limited Drill Rod
PT3536894T (pt) 2018-03-09 2020-11-19 Sandvik Mining And Construction Tools Ab Acoplamento para ligar elementos tubulares de fundo de furo
AU2018453343A1 (en) 2018-12-21 2021-02-18 Halliburton Energy Services, Inc. Single acting snap ring guide
PL3712374T3 (pl) * 2019-03-18 2023-01-16 Sandvik Mining And Construction Tools Ab Żerdź przewodu wiertniczego
CA3147685A1 (fr) * 2019-10-11 2021-04-15 John Hammargren Ensemble de forage protege par un epaulement

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US1926925A (en) 1931-04-07 1933-09-12 Gulf Res & Dev Corp Pin, bolt, and other connecting device
US4076436A (en) 1975-01-06 1978-02-28 Bowen Tools, Inc. Stress relieved tool elements
US4332502A (en) 1977-01-11 1982-06-01 Padley & Venables Limited Apparatus for use in drilling
US4398756A (en) 1980-09-15 1983-08-16 Vallourec, S. A. Cylindro-conical pipe joint
EP0192622A2 (fr) 1985-02-20 1986-08-27 Kometa Oy Appareil de forage pour forage à percussion
US4687368A (en) 1985-04-04 1987-08-18 Santrade Limited Thread structure for percussion rock drilling
US5169183A (en) 1987-05-12 1992-12-08 Diamant Boart Stratabit S.A. Threaded joint for drill rod elements
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CN109372443A (zh) * 2018-12-14 2019-02-22 无锡双马钻探工具有限公司 一种煤矿整体钻杆

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RU2017121599A3 (fr) 2019-02-15
AU2015348706A1 (en) 2017-05-18
CN107002467A (zh) 2017-08-01
CA2965868A1 (fr) 2016-05-26
MX2017006589A (es) 2017-12-14
ZA201702931B (en) 2019-10-30
CL2017001287A1 (es) 2017-12-15
PE20171231A1 (es) 2017-08-24
BR112017010617A2 (pt) 2018-02-14
US20170321496A1 (en) 2017-11-09
RU2017121599A (ru) 2018-12-21
WO2016079013A1 (fr) 2016-05-26

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