US20150275589A1 - System and Methodology for Use In Borehole Applications - Google Patents

System and Methodology for Use In Borehole Applications Download PDF

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Publication number
US20150275589A1
US20150275589A1 US14/663,419 US201514663419A US2015275589A1 US 20150275589 A1 US20150275589 A1 US 20150275589A1 US 201514663419 A US201514663419 A US 201514663419A US 2015275589 A1 US2015275589 A1 US 2015275589A1
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US
United States
Prior art keywords
recited
stabilizer
sleeve
wear protection
protection elements
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.)
Abandoned
Application number
US14/663,419
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English (en)
Inventor
Stuart David Dixon Walker
Edward Richards
Are Funderud
Martin Sanderson
Carlos Javier Delgado
Torbjoern Aksnes
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.)
Schlumberger Technology Corp
Original Assignee
Schlumberger Technology Corp
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 Schlumberger Technology Corp filed Critical Schlumberger Technology Corp
Priority to US14/663,419 priority Critical patent/US20150275589A1/en
Priority to PCT/US2015/021639 priority patent/WO2015148287A1/fr
Publication of US20150275589A1 publication Critical patent/US20150275589A1/en
Abandoned legal-status Critical Current

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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
    • 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
    • E21B3/00—Rotary drilling
    • 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
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in wells
    • 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
    • E21B41/00—Equipment or details not covered by groups E21B15/00 - E21B40/00
    • E21B41/0085—Adaptations of electric power generating means for use in boreholes

Definitions

  • wellbores are drilled into a desired hydrocarbon-bearing formation via a variety of drilling systems.
  • drilling operations may be performed with drill strings including a variety of bottom hole assemblies constructed to drill a desired wellbore.
  • rotary steerable drilling systems may be used to control the trajectory of the wellbore being drilled. This facilitates the drilling of deviated, e.g. horizontal, wellbores.
  • stabilizers and other drilling components of the bottom hole assembly may be subjected to substantial abrasion. This abrasion can be detrimental to the life of the stabilizer or other bottom hole assembly components.
  • stabilizers may be used with steerable drilling systems to provide contact points with the wellbore wall to facilitate steering.
  • stabilizers known as string stabilizers may be used farther up the bottom hole assembly of the drill string to support tools, to reduce shock and vibration, and to reduce stick-slip.
  • the downhole component may comprise a stabilizer having a plurality of blades extending outwardly from a body, e.g. sleeve.
  • Various features of the downhole component enhance the usefulness and dependability of the downhole component. Examples of such features comprise uniquely shaped surfaces; materials with a desired hardness, toughness, and impact strength; and/or wear protection elements incorporated into the downhole component.
  • FIG. 1 is a side view of an example of a stabilizer, e.g. an abrasion resistant stabilizer, mounted in a drill string, according to an embodiment of the disclosure;
  • a stabilizer e.g. an abrasion resistant stabilizer
  • FIG. 2 is a cross-sectional view of an example of a stabilizer to illustrate mounting of the stabilizer on a collar of a drill string, according to an embodiment of the disclosure
  • FIG. 3 is a side view of another example of a stabilizer, according to an embodiment of the disclosure.
  • FIG. 4 is a graphical representation illustrating plots of pull force versus taper angle for varying hole inclinations, according to an embodiment of the disclosure
  • FIG. 5 is a side view of another example of a stabilizer, according to an embodiment of the disclosure.
  • FIG. 6 is an orthogonal view of an abrasion resistant sleeve which may be used with a variety of downhole components, including stabilizers, according to an embodiment of the disclosure;
  • FIG. 7 is an illustration of a drill string having a plurality of downhole components protected with abrasion resistant sleeves and/or other abrasion resistant features, according to an embodiment of the disclosure
  • FIG. 8 is an illustration of another example of an abrasion resistant component in the form of a rotary valve system, according to an embodiment of the disclosure.
  • FIG. 9 is an illustration of another example of an abrasion resistant component in the form of an impeller which may be used in a variety of downhole components, according to an embodiment of the disclosure.
  • the stabilizer (or stabilizers) comprises an end face or end faces having shallower slopes instead of steep slopes. Steep slopes can sometimes cause the bottom hole assembly to get stuck on a ledge or other obstruction along the wellbore.
  • shallower slopes may be employed on both leading and trailing faces.
  • a shallower slope may be employed on one of the faces.
  • the shallower slope may be located on a trailing face of the stabilizer to reduce the risk of hanging-up the bottom hole assembly on a ledge or other obstruction while tripping out of the hole.
  • the shallower slopes and/or the relatively shallower slope on the trailing face may be employed on a variety of parts, components or entire tools.
  • the stabilizer may be constructed with a shallow sloped trailing face and a leading face having a steeper slope.
  • the steeper leading face moves the crown (contact point) of the stabilizer forward toward the drill bit.
  • drilling system 12 comprises a drill string 14 having a drill string collar 16 and a drill bit 18 .
  • the stabilizer 10 is mounted on drill string collar 16 and comprises a body 20 , e.g. a tubular body, having an interior surface 22 and an exterior surface 24 .
  • the interior surface 22 faces inwardly toward the drill string collar 16 and the exterior surface 24 faces in a radially outward direction.
  • the stabilizer 10 further comprises a plurality of blades 26 which extend outwardly from exterior surface 24 .
  • the blades 26 extend along at least a portion of the longitudinal length of body 20 and are separated circumferentially by flow channels 28 .
  • the blades 26 are arranged helically and thus provide generally helical flow channels 28 therebetween.
  • the flow channels 28 allow flows of fluid to move longitudinally past the stabilizer 10 along drill string 14 .
  • the longitudinal ends of blades 26 establish a leading face 30 and a trailing face 32 .
  • the leading face 30 is on the downhole end toward drill bit 18 and the trailing face 32 is on the uphole end of blades 26 .
  • the leading face 30 is oriented at a leading end angle 34 with respect to exterior surface 24
  • trailing face 32 is oriented at a trailing end angle 36 with respect to exterior surface 24 .
  • the leading face 30 and/or trailing face 32 may have a shallow slope in the form of a relatively small leading end angle 34 and/or trailing end angle 36 , respectively.
  • the leading face 30 has a relatively steep taper, e.g. a leading end angle 34 of 70° or greater.
  • the trailing face 32 has a shallow taper, e.g. a trailing end angle 36 of 45° or less.
  • the shallow taper may comprise a trailing end angle 36 of 30° or less.
  • some embodiments may utilize a substantially shallower taper on the trailing face 32 relative to a steeper taper on the leading face 30 .
  • the leading face 30 and/or trailing face 32 may be constructed with the leading end angle 34 and the trailing end angle 36 , respectively, formed as compound angles.
  • one or both of the leading end angle 34 and/or trailing end angle 36 may be formed with a plurality of differently angled slopes.
  • the stabilizer 10 may be mounted on drill string collar 16 of drilling system 12 via a variety of structures and techniques. An example of such a structure and technique is illustrated in FIG. 2 .
  • the interior surface 22 has an internal diameter profile 38 , e.g. an abutment, located to facilitate construction of a lengthened stabilizer body 20 .
  • the profile 38 is oriented for engagement with a shoulder 40 of drill string collar 16 .
  • the stabilizer 10 may be threadably engaged with and tightened against shoulder 40 via a threaded region 42 on collar 16 and a corresponding threaded region 44 along the interior of body 20 .
  • the drill string collar also may comprise a bit box 46 for engagement with drill bit 18 .
  • the overall arrangement facilitates construction of a longer stabilizer 10 to accommodate the longer, shallower slopes of the face or faces 30 , 32 .
  • profile 38 acts against the collar shoulder 40 at an internal location which allows the stabilizer to be lengthened by enabling the blades 26 to extend over this internal location.
  • the leading face 30 and the trailing face 32 of blades 26 both have a relatively shallow slope.
  • the leading end angle 34 and the trailing end angle 36 are relatively small.
  • the shallow slope of the leading face 30 and the trailing face 32 may have leading end angle 34 and trailing end angle 36 , respectively, of 45° or less.
  • the shallow taper may comprise both a leading end angle 34 and a trailing end angle 36 of 30° or less.
  • a shallower taper on the leading face 30 can limit steerability and dogleg capability.
  • the slope taper at the leading face 30 may be steeper and the slope taper at the trailing face 32 may be relatively shallower.
  • the face taper angle has an effect on the force applied to the drill string, e.g. the pull force, to overcome friction associated with an obstruction, e.g. a ledge.
  • FIG. 4 illustrates examples of pull force used to overcome friction for a variety of borehole inclinations and face taper angles. As illustrated, the pull force used to move stabilizer 10 past the obstruction decreases as the face taper angle decreases. FIG. 4 provides a graphical overview of this relationship for a variety of wellbore types.
  • cutting features 48 are added along the slopes, e.g. the shallow slopes, of leading face 30 and/or trailing face 32 .
  • the cutting features 48 may comprise cutters, such as polycrystalline diamond (PDC) cutters, formed of hard material and positioned along the sloped faces 30 and/or 32 .
  • the cutting features may be oriented to cut away obstructions, such as ledges resulting from washouts, encountered along the wellbore. In some applications, the cutting features may be applied to a non-magnetic stainless steel substrate.
  • various downhole components 10 may be constructed in a manner providing resistance to abrasion in well related applications and non-well related applications.
  • the technique may provide increased abrasion resistance in a downhole component deployed in a drilling bottom hole assembly.
  • a sleeve is mounted to or constructed as part of the downhole component.
  • the sleeve is formed of materials having suitable hardness, toughness and impact strength, such as materials comprising a tungsten carbide matrix.
  • the tungsten carbide matrix may comprise tungsten carbide particles in a suitable matrix, e.g. cobalt, and processed according to appropriate powder metallurgy techniques to form a metal matrix composite referred to herein as tungsten carbide matrix.
  • the sleeve may be formed primarily of tungsten carbide matrix.
  • the sleeve may be formed of a suitable composite material with portions comprising the tungsten carbide mixture.
  • the portions of hard tungsten carbide mixture may be bonded to steel or to another material having suitable toughness and impact strength.
  • various other materials and material combinations may be used to form the sleeve.
  • the composition of the tungsten carbide matrix also may be adjusted to accommodate various loading effects, thermal effects, and/or other effects likely to be experienced by the sleeve in a given application.
  • the sleeve also may employ a plurality of wear protection elements. Depending on the application, the wear protection elements may be used with or incorporated into a variety of other components. It should be noted the suitable composite material and the plurality of wear protection elements may be used in a variety of parts, components or entire tools.
  • the abrasion resistant components facilitate drilling operations and may be in the form of a stabilizer (or stabilizers) having an abrasion resistant sleeve.
  • a stabilizer or stabilizers
  • One or more of the stabilizers may be employed at various positions along a drill string and in combination with various types of drill string components, such as bottom hole assembly components.
  • the abrasion resistant sleeves and/or other abrasion resistant features may be used in combination with directional drilling components, measurement-while-drilling components, and logging-while-drilling components.
  • the abrasion resistant sleeves and/or other abrasion resistant features also may be used with a variety of other components, such as bottom hole assembly components. Examples include wear bands, kicker plates, filters and screens, telemetry modulators, impellers, turbine blades, cutter blocks for hole enlargement tools, stabilizer blocks for variable gauge stabilizers, and/or other downhole components.
  • the abrasion resistant sleeves may comprise a suitable material or materials, e.g. a composite material having portions formed of tungsten carbide matrix.
  • the entire abrasion resistant sleeve may be made of tungsten carbide matrix.
  • the sleeve also may be provided with additional wear protection elements, such as polycrystalline diamond compacts and thermally stable polycrystalline components.
  • the polycrystalline diamond compacts and the thermally stable polycrystalline components can be constructed in a variety of different shapes to provide additional, high abrasion resistance with respect to the sleeves or other components.
  • the additional wear protection elements also may be positioned in optimized patterns or arrangements to help reduce the erosion and abrasive wear.
  • the component 10 e.g. stabilizer 10
  • the abrasion resistant stabilizer 10 may similarly be mounted on drill string collar 16 .
  • the abrasion resistant stabilizer 10 may comprise the plurality of blades 26 which extend outwardly from exterior surface 24 .
  • the abrasion resistant stabilizer 10 may be used in combination with drill bit 18 and/or in combination with other drill string components.
  • the abrasion resistant stabilizer 10 may comprise an abrasion resistant sleeve 50 .
  • the abrasion resistant sleeve 50 may be constructed as the entire abrasion resistant stabilizer 10 , or the abrasion resistant sleeve 50 may be mounted to or incorporated into the stabilizer 10 .
  • the abrasion resistant sleeve 50 is formed at least in part from tungsten carbide matrix and comprises a plurality of additional wear protection elements 52 .
  • the additional wear protection elements 52 may comprise polycrystalline diamond compacts and/or thermally stable polycrystalline components.
  • sleeve 50 may be formed with stabilizer blades 26 and the wear protection elements 52 may be mounted on or incorporated into the stabilizer blades 26 .
  • the wear protection elements 52 may comprise polycrystalline diamond compact elements 54 and/or thermally stable polycrystalline elements 56 .
  • the wear protection elements 52 may be mounted along a lead edge 58 progressing up along each stabilizer blade 26 and in an arrangement which reduces wear on the lead edge 58 . Additionally, the wear protection elements 52 may be arranged to reduce transversal wear patterns.
  • the wear protection elements 52 comprise polycrystalline diamond compact elements 54 constructed as high rake cutters provided along the leading edges 58 .
  • the polycrystalline diamond compact elements 54 are arranged in rows along the leading edge 58 .
  • the blades 26 also comprise thermally stable polycrystalline elements 56 positioned to provide additional wear protection.
  • the wear protection elements 52 may be formed from a variety of hardened materials.
  • the wear protection elements 52 also may have various shapes and may be arranged in different patterns depending on the environment, the application, and/or the type of abrasion resistant component 10 , e.g. stabilizer 10 .
  • sleeve 50 may comprise threaded regions 59 (or other suitable connector mechanisms) at its longitudinal ends to facilitate attachment to adjacent well string components.
  • abrasion resistant components 10 are assembled into drill string 14 deployed in a wellbore 60 .
  • the abrasion resistant components 10 incorporate abrasion resistant sleeves 50 which provide the components with high abrasion resistance.
  • the abrasion resistant sleeves 50 may be formed in whole or in part of tungsten carbide matrix.
  • the abrasion resistant sleeves 50 may be used to protect antennas 62 of, for example, measurement-while-drilling components and/or logging-while-drilling components.
  • the abrasion resistant sleeves 50 also may be used in conjunction with, e.g.
  • abrasion resistant sleeves 50 in these embodiments may again comprise or be combined with a variety of the wear protection elements 52 formed of various hard materials.
  • the wear protection elements 52 may be attached to sleeve 50 via suitable attachment mechanisms, such as threaded attachment mechanisms, weldments, independent fasteners, and/or other suitable attachment mechanisms.
  • the abrasion resistant component 10 also may comprise a variety of rotary valves 64 in which hardened, wear protection elements 52 are combined with various components of the valve 64 .
  • the rotary valve 64 is combined with a torque impeller 66
  • the wear protection elements 52 may be mounted on or formed with impeller blades and/or other system components to provide a high resistance to abrasion from, for example, sand and other particulates.
  • impellers 66 may incorporate wear protection elements 52 along impeller blades 68 and/or at other portions of the impeller 66 to provide resistance to abrasion.
  • the abrasion resistant sleeves 50 and/or wear protection elements 52 may be used with many types of components to construct abrasion resistant components 10 .
  • the abrasion resistant sleeves 50 and/or wear protection elements 52 may be combined with wear bands, kicker plates, filters and screens, telemetry modulators, turbine blades, cutter blocks for hole enlargement tools, stabilizer blocks for variable gauge stabilizers, and/or other downhole components.
  • the wear resistant components 10 may have a variety of configurations comprising other and/or additional components.
  • the wear resistant components 10 may comprise a variety of rotary steerable system components such as pads, e.g. actuator pads, or kickers.
  • the shape and structure of the stabilizer body and stabilizer blades may vary in size and configuration depending on the parameters of a given application and environment.
  • a variety of materials may be used to construct the wear protection elements 52 .
  • the wear protection elements 52 may be combined with many types of abrasion resistant sleeves 50 and/or other types of abrasion resistant components in well applications and non-well applications.
  • the sleeve 50 may utilize features, e.g. tongue and groove features, to facilitate making-up the connection with adjacent components.

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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)
US14/663,419 2014-03-26 2015-03-19 System and Methodology for Use In Borehole Applications Abandoned US20150275589A1 (en)

Priority Applications (2)

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US14/663,419 US20150275589A1 (en) 2014-03-26 2015-03-19 System and Methodology for Use In Borehole Applications
PCT/US2015/021639 WO2015148287A1 (fr) 2014-03-26 2015-03-20 Système et méthodologie destinés à être utilisés dans des applications de trou de forage

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US201461970864P 2014-03-26 2014-03-26
US201462036572P 2014-08-12 2014-08-12
US14/663,419 US20150275589A1 (en) 2014-03-26 2015-03-19 System and Methodology for Use In Borehole Applications

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Cited By (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US9428963B1 (en) * 2014-10-28 2016-08-30 Alaskan Energy Resources, Inc. Bidirectional stabilizer with impact arrestors and blades with wrap angles
US9470048B1 (en) * 2014-10-28 2016-10-18 Alaskan Energy Resources, Inc. Bidirectional stabilizer with impact arrestors
US20180236580A1 (en) * 2015-08-12 2018-08-23 Schlumberger Technology Corporation Wear Resistant Parts and Fabrication
US10632713B2 (en) 2015-06-08 2020-04-28 Schlumberger Technology Corporation Replaceable hardfacing
WO2023023267A1 (fr) * 2021-08-20 2023-02-23 Longyear Tm, Inc. Tiges de forage ayant des stabilisateurs, et systèmes et procédés les comprenant

Citations (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4729438A (en) * 1986-07-03 1988-03-08 Eastman Christensen Co, Stabilizer for navigational drilling

Family Cites Families (5)

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Publication number Priority date Publication date Assignee Title
US3978933A (en) * 1975-01-27 1976-09-07 Smith International, Inc. Bit-adjacent stabilizer and steel
GB1542401A (en) * 1975-05-06 1979-03-21 Moppes & Sons Ltd L Van Stabilizers for drill strings
US4304311A (en) * 1979-10-29 1981-12-08 Shinn Kim E Drill string stabilizer having easily removed hard surface inserts
US7878273B2 (en) * 2008-11-17 2011-02-01 Omni Ip Ltd. Ultra-hard drilling stabilizer
US9051793B2 (en) * 2011-12-13 2015-06-09 Smith International, Inc. Apparatuses and methods for stabilizing downhole tools

Patent Citations (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4729438A (en) * 1986-07-03 1988-03-08 Eastman Christensen Co, Stabilizer for navigational drilling

Cited By (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US9428963B1 (en) * 2014-10-28 2016-08-30 Alaskan Energy Resources, Inc. Bidirectional stabilizer with impact arrestors and blades with wrap angles
US9470048B1 (en) * 2014-10-28 2016-10-18 Alaskan Energy Resources, Inc. Bidirectional stabilizer with impact arrestors
US10632713B2 (en) 2015-06-08 2020-04-28 Schlumberger Technology Corporation Replaceable hardfacing
US20180236580A1 (en) * 2015-08-12 2018-08-23 Schlumberger Technology Corporation Wear Resistant Parts and Fabrication
US10562121B2 (en) * 2015-08-12 2020-02-18 Schlumberger Technology Corporation Wear resistant parts and fabrication
WO2023023267A1 (fr) * 2021-08-20 2023-02-23 Longyear Tm, Inc. Tiges de forage ayant des stabilisateurs, et systèmes et procédés les comprenant

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