WO2013151940A1 - Système et outil de forage vibrants destinés à être utilisés dans des opérations de forage de fond de trou, et leur procédé de fabrication - Google Patents

Système et outil de forage vibrants destinés à être utilisés dans des opérations de forage de fond de trou, et leur procédé de fabrication Download PDF

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Publication number
WO2013151940A1
WO2013151940A1 PCT/US2013/034832 US2013034832W WO2013151940A1 WO 2013151940 A1 WO2013151940 A1 WO 2013151940A1 US 2013034832 W US2013034832 W US 2013034832W WO 2013151940 A1 WO2013151940 A1 WO 2013151940A1
Authority
WO
WIPO (PCT)
Prior art keywords
tool
cam
borehole
drill string
vibratory
Prior art date
Application number
PCT/US2013/034832
Other languages
English (en)
Inventor
Jeffery D. Baird
Original Assignee
Baird Jeffery D
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 Baird Jeffery D filed Critical Baird Jeffery D
Priority to US14/387,488 priority Critical patent/US20150159438A1/en
Priority to AU2013243673A priority patent/AU2013243673A1/en
Priority to GB1419221.5A priority patent/GB2518068B/en
Priority to CA2868514A priority patent/CA2868514A1/fr
Publication of WO2013151940A1 publication Critical patent/WO2013151940A1/fr
Priority to NO20141181A priority patent/NO20141181A1/no

Links

Classifications

    • EFIXED CONSTRUCTIONS
    • E21EARTH OR ROCK DRILLING; MINING
    • E21BEARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B7/00Special methods or apparatus for drilling
    • E21B7/24Drilling using vibrating or oscillating means, e.g. out-of-balance masses
    • EFIXED CONSTRUCTIONS
    • E21EARTH OR ROCK DRILLING; MINING
    • E21BEARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B28/00Vibration generating arrangements for boreholes or wells, e.g. for stimulating production
    • EFIXED CONSTRUCTIONS
    • E21EARTH OR ROCK DRILLING; MINING
    • E21BEARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B17/00Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/02Couplings; joints
    • E21B17/04Couplings; joints between rod or the like and bit or between rod and rod or the like
    • E21B17/042Threaded
    • E21B17/0423Threaded with plural threaded sections, e.g. with two-step threads
    • EFIXED CONSTRUCTIONS
    • E21EARTH OR ROCK DRILLING; MINING
    • E21BEARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B17/00Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/10Wear protectors; Centralising devices, e.g. stabilisers
    • EFIXED CONSTRUCTIONS
    • E21EARTH OR ROCK DRILLING; MINING
    • E21BEARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B17/00Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/10Wear protectors; Centralising devices, e.g. stabilisers
    • E21B17/1078Stabilisers or centralisers for casing, tubing or drill pipes
    • EFIXED CONSTRUCTIONS
    • E21EARTH OR ROCK DRILLING; MINING
    • E21BEARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B19/00Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables
    • E21B19/16Connecting or disconnecting pipe couplings or joints
    • EFIXED CONSTRUCTIONS
    • E21EARTH OR ROCK DRILLING; MINING
    • E21BEARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B7/00Special methods or apparatus for drilling
    • EFIXED CONSTRUCTIONS
    • E21EARTH OR ROCK DRILLING; MINING
    • E21BEARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B7/00Special methods or apparatus for drilling
    • E21B7/04Directional drilling
    • E21B7/046Directional drilling horizontal drilling

Definitions

  • Any deviated or horizontal wellbore has a problem of keeping the formation cuttings suspended in the drilling fluid and from falling out of the mud system onto the bottom of the wellbore.
  • Many attempts have been made to keep the cuttings in the drilling fluid system via, water-based mud, oil- based mud, synthetic mud systems and mechanical manipulation of the drill string and mud pump pressure. Additional mechanical attempts have been made with drilling tools that provide extreme vibrations to the drill string via variations in drill mud pressures. These extreme vibrations have to be cushioned by other tools to insulate the vibrations at the surface to prevent damage to the drilling rig and expensive steering tools.
  • the present invention provides a system and tool that improves cuttings suspension in the mud system while improving the transition of controlled and steady weight through the lateral section of the drill string to the drill bit. Refurbishing costs are low and, more importantly, there are no moving parts in the tool itself other than the rotation of the number of cams rotating with the drill string.
  • Fig. 1A illustrates a top, rear perspective view of the present vibratory tool with wiping fingers attached.
  • Fig. IB shows a top, front perspective view of the tool of Fig. 1A.
  • Fig. 2A illustrates a side elevation, cross-sectional view of the present vibratory tool without wiping fingers.
  • Fig. 2B shows a cross-sectional view taken along line A-A of Fig. 1A.
  • Fig. 2C illustrates a top, front perspective view of an embodiment of the tool with a threaded portion along the cam body at the cam apex intersection with a flat section.
  • Fig. 2D shows a side elevation perspective view of the embodiment of Fig. 2C
  • Fig. 2E shows a cross-sectional view of the embodiment of Fig. 2D.
  • Fig. 3 is a cross-sectional end view of the present vibratory tool with a wiping finger installed.
  • Fig. 4 shows a partial, top plan view of the large flat on the cam of the present vibratory tool with opening to receive the wiping fingers.
  • Fig. 5A illustrates a cross-sectional view of the tool in a borehole with the apex of the cam at the top (90 degree position) of a horizontal wellbore.
  • Fig. 5B illustrates the tool of Fig. 5A rotated about 180 degrees in the borehole with the cam at approximately the bottom (278 degree position) of the horizontal wellbore.
  • Fig 5C illustrates the tool of Fig. 5A rotated about 270 degrees in the borehole with the cam at approximately the 360 degree position of the horizontal wellbore.
  • Figs. 6A-6H illustrate the displacement of the center point of the tool as it rotates, lifts, and cleans within the borehole.
  • Fig. 7 shows a sketch of a typical prior art horizontal drill string.
  • Fig. 8 illustrates a sketch of a horizontal drilling operation with a drill string incorporating the present vibratory tool.
  • Fig. 9 is an illustration of a rotating drill pipe section (with the present vibratory tool) deflecting within a horizontal wellbore as the cam lifts the drill string from the bottom of the borehole allowing critical fluid volume to effect the bottom of the wellbore and move cuttings back into the flow stream.
  • Fig. lOA is a top, rear perspective view of a section of standard drill pipe or heavy weight pipe having a raised wear joint retrofitted to incorporate the cam-shaped structure of the present vibratory tool.
  • Fig 10B is a top, front perspective view of the section of standard drill pipe of Fig. 10A having a raised wear joint retrofitted to incorporate the cam-shaped structure of the present vibratory tool.
  • Fig. lOA is a top, rear perspective view of a section of standard drill pipe or heavy weight pipe having a raised wear joint retrofitted to incorporate the cam-shaped structure of the present vibratory tool.
  • Fig 10B is a top, front perspective view of the section of standard drill pipe of Fig. 10A having a raised
  • IOC is a cross-sectional view of the retrofitted drill pipe of Fig 10A taken along line A-A.
  • Fig. 11 illustrates in cross-section an alternative embodiment of the vibratory tool showing a plurality of cam elements incorporated into a single tool profile.
  • a short and single body tool joint 20 with a unique cam- shaped profile 22 on the cam body 28 which raises and lowers the drill pipe within the borehole during drill string rotation.
  • the cam-body has a generally smooth, consistent, arc section along the opening side.
  • the closing side of the cam body 28 is provided with one or more flat surfaces of varying widths.
  • the cam body 28 is provided with a threaded portion 200 extending along the intersecting edge 202 of the apex 42 of the cam body with a flat section 26 of the cam body 28.
  • the threaded portion 200 has course and shallow threads (depth approximately 0.025") that extend only 2"-4" along edge 202. The threads thin out as they spiral toward the smaller diameter of the cam body 28.
  • the thread portion results in momentary forward urging of the drill string toward the drill bit and provides mechanical scrapping of cuttings from the bottom of the wellbore when the threaded portion reaches the bottom of the well bore during rotation.
  • Optimum fluid volume is maintained around the outside of the cam profile to allow drilling fluid 46 to pass and create turbulence; therefore, thrusting cuttings back into the mud system for evacuation.
  • the cam body 28 with a generally, smooth, consistent opening side 500 arc section and flat sections 26, 34, and 36 on the closing side 502 of the cam body 28 causes a lifting of the drill string and a unique displacement of the tool center point 112 of the borehole creating an oscillating, harmonic rotation, or vibratory motion of the drill string as will be described further below (Figs. 6A-6H).
  • the threaded portion 200 along the length of the cam body further causes a momentary, forward-urging or lurching of the drill string when the edge 202 reaches the bottom cuttings in the wellbore.
  • the intersection of flats 26, 31, and 36 on the cam body 28 provide several leading edges 202, 204, and 206 to cause a mechanical, stepped scraping of the cuttings on the bottom of the hole while optional wiping fingers 24 thrust the cuttings back into the mud system without altering the bottom of the lateral wellbore.
  • the incorporation of short replaceable wiping fingers 24 that may be threaded into the long flat 26 on the cam are positioned such that they do not create a "pinch point" with the wellbore.
  • the wiping fingers 24 may be quickly replaced on the rig floor during trips after approximately 150 to 200 hours of operation.
  • the flat areas of the cam profile with the leading edges 202, 204, and 206, provide a gentle systematic scrapping of the bottom of the well bore without adding additional rotational friction to the drill string.
  • a plurality of tools 20 with cam bodies 28 installed along the drill string will create a continuous oscillation or "harmonic rotation" of the lateral section of the drill string in the deviated or horizontal wellbore which improves the turbulence of the mud system and helps keep the cuttings from dropping out onto the bottom of the wellbore.
  • the oscillation also improves well bore stability by imbedding cuttings and debris into the outer sides of the wall of the borehole forming a strengthening, composite boundary layer around the wellbore (Figs. 7, 8, and 9). This boundary layer naturally occurs when drilling the vertical section of the well but has not been available along the horizontal section until the utilization of the present vibratory tool.
  • the present vibratory tool may be utilized with drilling speeds from 20 rpm to 130 rpm. Ideally best vibratory action may be achieved in the 40--60 rpm range, but it is anticipated that rotation rates of 120 rpm may not be uncommon.
  • the rotary table may locked and after torqueing each cammed section 20 into the drill string, the position of the cam apex 42 may be recorded, referencing the degree of the apex to the degrees of the rotary table.
  • This cam apex position profile will insure the position of all the cams in relation to the steering tools when there is the need for "sliding" operations (moving the string without rotation of the string). The profile will also help analyze and vary the amount of oscillation or vibratory potential of the lateral section. Some range of torqueing ability helps to position the cam apexes during assembly for an even distribution of cam apexes in degrees from each other.
  • Fig.lA shows a top, rear perspective view of the present vibratory tool 20 having a cam body portion 28 with a modified pear-shaped cam profile 22.
  • a plurality of wiping fingers 24 extend outwardly from a first, wide flat surface 26 on the closing side of the cam body 28.
  • the pin end 30 of the tool 20 is opposite the box end 32 of the tool 20.
  • two other flat surfaces 34 and 36 each of which may have a varying width are formed along the outer surface of the cam body 28 each flat surface extending longitudinally from pin end tapering shoulder 38 to box end tapering shoulder 40.
  • fingers 24 may be provided in the flat surfaces 34 and 36
  • the shoulders gradually taper from the tool body surface 23 of the cylindrical body portion 21 to the top surface at the apex 42 of cam-shaped body portion 28.
  • the tapering shoulders 38 and 40 provide smooth leading and trailing surfaces as the tool is moved longitudinally through the horizontal borehole.
  • Fig. IB illustrates a top, front perspective view of the tool of Fig. 1A.
  • the smooth, consistent, opening side arc section 19 of the cam profile 22 on the cam body 28 is clearly illustrated as are the tapering shoulders 38, 40 and surface 23.
  • the tool 20 has a longitudinal axis L-L running the length of the tool.
  • the tool has a cylindrical body portion 21 and a cylindrical tool body surface 23.
  • the body portion 21 has an internally threaded section 300 at the box end 32 so that it may be coupled to a first drill string section.
  • An opposite, pin end 30 has an externally threaded section 302 for coupling to another section of the drill string.
  • Fig. 2B The distance rl from the tool center point 50 to the tool body surface 23 is less than the distance r2 from the center point 50 of the tool to the apex 42 of the cam body portion 28 (Fig. 2B).
  • Fig. 2A a cross-sectional view of the embodiment of Fig. 2A is shown.
  • the various flat surfaces 26, 34, and 36 of varying widths on the closing side 502 of the cam body 28 are illustrated in relation to the smooth, consistent arc section 19 on the opening side of cam body 28.
  • Typical dimensions are again provided on Fig. 2B.
  • FIG. 2C illustrates a top, front perspective view of an embodiment of the tool 20 with a threaded portion 200 extending along the intersecting edge 202 at the apex 42 of the cam body 28 with a flat section 26 of the cam body 28.
  • the threaded portion 200 has course and shallow threads (depth approximately 0.025") that extend only 2" -4" along edge 202. The threads thin out as they spiral toward the smaller diameter of the cam body 28.
  • the thread portion results in momentary forward urging of the drill string toward the drill bit and provides mechanical scrapping of cuttings from the bottom of the wellbore when the threaded portion reaches the bottom of the well bore during rotation.
  • FIG. 2D shows a side elevation perspective view of the embodiment of Fig. 2C with the threaded portion 200 along the edge of the intersection of the cam arc section 19 of the cam body 28 and the flat section 26.
  • Fig. 2E shows a cross-sectional view of the embodiment of Fig. 2D.
  • a cross sectional view of the tool of Fig. 2D is shown in Fig. 2E.
  • the threaded edge 202 is shown at the apex 42 of the cam body 28.
  • Fig. 3 shows a cross-sectional end view of the present vibratory tool 20 with a wiping finger 24 installed in opening 27 in flat surface 26
  • the fingers may be of wire cable material of the like and threaded on one end for retention in opening 27.
  • the rear access of the openings 27a allows a suitable wrench or tool to be inserted to tighten or loosen the fingers for installation or
  • FIG. 4 shows a partial, top plan view of the large flat surface 26 on the cam body 28 of the present vibratory tool 20 with opening 27 to receive the wiping finger 24.
  • the openings are set at a 30 degree angle to the face of the flat 26.
  • Fig. 5A illustrates a cross-sectional view of the tool 20 in a borehole with the apex 42 of the cam body 28 at the top (90 degree position) of a horizontal wellbore 43.
  • Drilling mud 46 with suspended cuttings 48 is shown in the borehole.
  • the tool 20 is generally resting near the bottom of the wellbore.
  • the tool will shift left and upwardly in the borehole.
  • the fingers 27 are fully extended and almost touch the top side of the borehole.
  • the center point 50 of the tool in relation to the center 112 of the wellbore. This center point 50 will move abruptly as the tool rotates creating a shifting movement of the tool within the borehole.
  • the shifting motion creates turbulence in the drilling mud keeping the cuttings suspended in the mud.
  • the fingers 27 sweep inside the borehole thereby thrusting the cuttings along the drill string for evacuation.
  • Fig. 5B illustrates the tool of Fig. 5A rotated about 180 degrees in the borehole with the cam apex 42 at approximately the bottom (278 degree position) of the horizontal wellbore.
  • the intersecting edge 204 formed along the intersection of flat surfaces 34 and 36 moves closely along the inner wall of the borehole and causes cuttings 48 to be displaces and suspended in the drilling mud 46.
  • the fingers 24 have flexed and are sweeping cuttings 48.
  • the center point 50 of the tool 20 has moved upwardly and to the right as the tool oscillates and rotates within the borehole.
  • Fig 5C illustrates the tool 20 of Fig. 5A rotated about 270 degrees in the borehole with the cam apex at approximately the 360 degree position of the horizontal wellbore. Again the center point 50 has moved within the borehole causing the tool to shift creating vibration in the drill string.
  • Figs. 6A-6H illustrate the displacement of the center point 50 of the tool as it rotates within the borehole. The center of the borehole is shown at 112. The apex 42 of the tool is shown rotating from 12 o'clock (90 degrees) in Fig. 6A through 1:30 o'clock in Fig. 6B to 3:00 o'clock (180 degrees) in Fig. 6C.
  • Fig. 6C shows that the tool beginning to lift in the wellbore.
  • FIG. 7 shows a sketch of a typical prior art horizontal drill string 400 with a generally vertical section 402 that applies weight to the drill bit 404.
  • Drill pipe tool connections 406, wear joints 408, steering tools 405, and the drill bit 404 are shown.
  • Tool joints and wear joints on the bottom of the lateral tend to restrict delivery of weight to drill bit (WOB) as shown at numeral 410.
  • Cuttings fall out at approximately 1000 feet forming beds that further restrict WOB, add drag, torque, and possible pipe sticking as seen at numeral 412.
  • Fig. 7 shows a sketch of a typical prior art horizontal drill string 400 with a generally vertical section 402 that applies weight to the drill bit 404.
  • Drill pipe tool connections 406, wear joints 408, steering tools 405, and the drill bit 404 are shown.
  • Tool joints and wear joints on the bottom of the lateral tend to restrict delivery of weight to drill bit (WOB) as shown at numeral 410.
  • Cuttings fall out at approximately 1000 feet forming beds that further restrict WOB, add drag, torque,
  • FIG. 8 illustrates a sketch of a horizontal drilling operation with a drill string incorporating the present vibratory tool 20 at 500' intervals. Penetration rates of approximately 300' per hour are achievable in shale formations. Fig. 8 reflects that the cam tool travels the 500' in approximately 1 hour 40 minutes. Further, as may be seen in Fig. 8, the drill string lifts and allows for cuttings to be circulated in a turbulent flow zone TFZ in the proximity of the tool 20.
  • Fig. 9 is an illustration of a rotating drill pipe section (with the present vibratory tool 20) deflecting within a horizontal wellbore as the cam body 28 lifts the drill string from the bottom of the borehole.
  • Fig. 10A is a top, front perspective view another embodiment of the present vibratory tool 20b on a section of standard drill pipe or heavy weight pipe 300 having a raised wear joint 60. The pipe 300 is retrofitted or refurbished to incorporate a cam-shaped structure 28b as will be described in Fig. IOC.
  • Fig 10B is a top, back perspective view of the section of standard drill pipe or heavy weight pipe of Fig. 10A having a raised wear joint 60 retrofitted or refurbished to incorporate the cam-shaped structure 28b of the present vibratory tool 20b.
  • Fig. IOC is a cross-sectional view of the retrofitted drill pipe of Fig 10A taken along line 10C-10C.
  • a cam profile member 70 is welded to the wear joint 60 as is a flat profile member 72.This creates a cam body 28b with a smooth, cam section 19a on the opening side of the cam body 28b Other flats may be cut or machined in the wear joint 60 as appropriate.
  • Fig. IOC also shows the drill pipe inside diameter 62 and a drilling fluid volume 46 within the wellbore 80.
  • Fig. 11 illustrates in cross-section an alternative embodiment of the vibratory tool 20c showing a plurality of cam elements 28c incorporated into a single tool profile. While Fig. 11 shows the plurality on a pipe wear joints 60, it is understood that multiple cams may be formed on a single tool as shown in earlier figures.
  • the wear joint 60 has two cam profile members 70 and two flat members 72 affixed to the joint. Weld build ups 73 are applied and ground to create a smooth transition of the tool profile.
  • Curve 90 degrees @1000 ft.
  • Each tool 20 raises itself, (deflects) and two opposing DUDS which are 15 ft. from each torqued tool joint.
  • Each tool 20 distributes cuttings back into the mud system 40 to 60 times per minute.
  • 96 Joints divided by (6) tools 20 16% cuttings suspension improvement and cleans the bottom of the well bore.
  • Each tool 20 positioned 500 ft. apart will deflect drill string 3 ⁇ 4 of an inch, (shortening and lengthening) the length of immediate 30 ft. section of drill pipe either side of the tool 20.
  • 96 total joints divided by 11.6 joints 8.27% improved weight transmission to drill bit by weight pulse action.

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

Abstract

L'invention porte sur un outil de forage vibrant destiné à être utilisé en couplage avec un train de tiges de forage dans un trou de forage dans des opérations de forage de fond de trou, lequel outil a un corps d'outil ayant une trajet d'écoulement de fluide s'étendant le long d'un axe longitudinal à travers celui-ci, une première extrémité de broche et une extrémité de boîte opposée. Une partie corps de came s'étendant longitudinalement le long de la longueur dudit outil a une section d'arc de came généralement lisse sur un côté d'ouverture comprenant au moins une surface plate allongée s'étendant longitudinalement le long d'un côté de fermeture de la partie corps de came d'un épaulement effilé d'extrémité de broche à un épaulement effilé d'extrémité de boîte. La partie corps de came, quand elle est couplée audit train de tiges de forage, soulève verticalement une section de tuyau de forage généralement horizontale du train de tiges de forage dans le trou de forage quand la section de tuyau de forage est tournée dans le trou de forage.
PCT/US2013/034832 2012-04-04 2013-04-01 Système et outil de forage vibrants destinés à être utilisés dans des opérations de forage de fond de trou, et leur procédé de fabrication WO2013151940A1 (fr)

Priority Applications (5)

Application Number Priority Date Filing Date Title
US14/387,488 US20150159438A1 (en) 2012-04-04 2013-04-01 Vibratory Drilling System and Tool For Use In Downhole Drilling Operations and A Method For Manufacturing Same
AU2013243673A AU2013243673A1 (en) 2012-04-04 2013-04-01 A vibratory drilling system and tool for use in downhole drilling operations and method for manufacturing same
GB1419221.5A GB2518068B (en) 2012-04-04 2013-04-01 A vibratory drilling system and tool for use in downhole drilling operations
CA2868514A CA2868514A1 (fr) 2012-04-04 2013-04-01 Systeme et outil de forage vibrants destines a etre utilises dans des operations de forage de fond de trou, et leur procede de fabrication
NO20141181A NO20141181A1 (no) 2012-04-04 2014-10-02 Et vibrasjonsboresystem og verktøy for anvendelse i nedihulls boreoperasjoner og fremgangsmåte for fremstilling av det samme

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US201261620043P 2012-04-04 2012-04-04
US61/620,043 2012-04-04

Publications (1)

Publication Number Publication Date
WO2013151940A1 true WO2013151940A1 (fr) 2013-10-10

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Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/US2013/034832 WO2013151940A1 (fr) 2012-04-04 2013-04-01 Système et outil de forage vibrants destinés à être utilisés dans des opérations de forage de fond de trou, et leur procédé de fabrication

Country Status (6)

Country Link
US (1) US20150159438A1 (fr)
AU (1) AU2013243673A1 (fr)
CA (1) CA2868514A1 (fr)
GB (1) GB2518068B (fr)
NO (1) NO20141181A1 (fr)
WO (1) WO2013151940A1 (fr)

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US9506318B1 (en) 2014-06-23 2016-11-29 Solid Completion Technology, LLC Cementing well bores
WO2022086337A1 (fr) * 2020-10-19 2022-04-28 National Oilwell Varco Norway As Améliorations relatives à des trains de tiges de forage

Families Citing this family (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN113958281B (zh) * 2021-11-04 2023-05-09 东北石油大学 一种利用超声波振动防环空泥包的钻柱短节

Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2727730A (en) * 1954-06-07 1955-12-20 Shell Dev Keyslot reamer
US6039130A (en) * 1998-03-05 2000-03-21 Pruet; Glen Square drill collar featuring offset mass and cutter
US20050284624A1 (en) * 2004-06-24 2005-12-29 Vibratech Drilling Services Ltd. Apparatus for inducing vibration in a drill string
US7461705B2 (en) * 2006-05-05 2008-12-09 Varco I/P, Inc. Directional drilling control
US20100212901A1 (en) * 2009-02-26 2010-08-26 Frank's International, Inc. Downhole vibration apparatus and methods
US20100326733A1 (en) * 2009-06-29 2010-12-30 Charles Abernethy Anderson Vibrating downhole tool

Patent Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2727730A (en) * 1954-06-07 1955-12-20 Shell Dev Keyslot reamer
US6039130A (en) * 1998-03-05 2000-03-21 Pruet; Glen Square drill collar featuring offset mass and cutter
US20050284624A1 (en) * 2004-06-24 2005-12-29 Vibratech Drilling Services Ltd. Apparatus for inducing vibration in a drill string
US7461705B2 (en) * 2006-05-05 2008-12-09 Varco I/P, Inc. Directional drilling control
US20100212901A1 (en) * 2009-02-26 2010-08-26 Frank's International, Inc. Downhole vibration apparatus and methods
US20100326733A1 (en) * 2009-06-29 2010-12-30 Charles Abernethy Anderson Vibrating downhole tool

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US9506318B1 (en) 2014-06-23 2016-11-29 Solid Completion Technology, LLC Cementing well bores
WO2022086337A1 (fr) * 2020-10-19 2022-04-28 National Oilwell Varco Norway As Améliorations relatives à des trains de tiges de forage

Also Published As

Publication number Publication date
GB201419221D0 (en) 2014-12-10
AU2013243673A1 (en) 2014-10-23
US20150159438A1 (en) 2015-06-11
CA2868514A1 (fr) 2013-10-10
GB2518068B (en) 2016-05-18
NO20141181A1 (no) 2014-10-22
GB2518068A (en) 2015-03-11

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