WO2014106187A1 - Matériaux élaborés destinés à des applications de type tige de forage - Google Patents

Matériaux élaborés destinés à des applications de type tige de forage Download PDF

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Publication number
WO2014106187A1
WO2014106187A1 PCT/US2013/078322 US2013078322W WO2014106187A1 WO 2014106187 A1 WO2014106187 A1 WO 2014106187A1 US 2013078322 W US2013078322 W US 2013078322W WO 2014106187 A1 WO2014106187 A1 WO 2014106187A1
Authority
WO
WIPO (PCT)
Prior art keywords
drill string
string component
midbody
drill
composite lining
Prior art date
Application number
PCT/US2013/078322
Other languages
English (en)
Inventor
Christopher L. Drenth
Shakeel Khalfan
Original Assignee
Longyear Tm, Inc.
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Priority claimed from US13/731,499 external-priority patent/US20140182945A1/en
Application filed by Longyear Tm, Inc. filed Critical Longyear Tm, Inc.
Publication of WO2014106187A1 publication Critical patent/WO2014106187A1/fr

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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

Definitions

  • Implementations of the present invention relate generally to components and systems for drilling.
  • implementations of the present invention relate to drill components comprising fiber-composite reinforced midbodies.
  • Drill rods typically comprise a threaded box end and threaded a pin end joined by a midbody. Adjacent drill rods are joined together by coupling the threaded box end to the eomplementarily threaded pin end to form a tool joint.
  • a plurality of drill rod sections which are each typically about twenty-five feet long more or less, are coupled together in series to form a drill string. As the depth of the bore increases, the drill string is correspondingly lengthened by the addition of drill rod sections at the drill rig.
  • the drill string operativeiy couples a bottom hole assembly having a boring tool to a motor at the drill rig on the surface.
  • the motor transmits axial impact and/or torque via the drill string to the bottom hole assembly and, thus, the boring tool.
  • the forces transmitted by the motor combined with the weight of the drill string causes the boring tool to wear away the underlying material.
  • each drill rod section is made hollow so that the drill string can serve as a conduit for drilling fluid, such as compressed air, which is discharged through the drill bit at the bottom of the well.
  • drilling fluid such as compressed air
  • This drilling fluid picks up cuttings from the drill bit and carries them upwardly to the well top on the outside of the drill string.
  • Compressed air when used as the drilling fluid, can also be used to operate the drill bit, as in percussion drilling; or the drill bit can be operated directly by drill string rotation.
  • drill rods are hollow pipes that are subjected to high levels of at least one of axial and torsional loads during a drilling operation. Each drill rod in an assembly must support its own weight as well as the lengths of drill rod positioned above it in a drill string. Also, the drill rods can be subjected to high levels of impact, torsional and bending stresses, as well as dynamic loads, during the drilling operation. In percussive drilling, drill rods and other drill components are subject to high levels of impact, local working and bending stresses associated with the drilling process. Drill rods typically fail at the joints when failure occurs.
  • drill string weight which of course becomes greater and greater as the bore depth is increased.
  • drill rod sections have been made of structural steel or alloys of structural steel; but with the deeper bores now being drilled, the heavier drill strings can impose fatiguing loads on the component drill rod sections and on the equipment used to rotate and raise and lower the drill string.
  • Another limitation is the amount of tension that the drill string joints can withstand.
  • Some drill string components such as, for example and without limitation, drill bits have a maximum load. In order to avoid overloading the drill bit, the drill rig must pull back on the drill string which creates tension that can eventually cause the drill string joints to fail. Drill rigs typically are limited in the amount offeree they can exert to pull back.
  • the present disclosure provides for drill rods comprising an integral tubular metallic body having a first ends, an opposing second end, and an elongate midbody extending along a central axis between the first and second ends and where the metallic body defines a central bore that extends along the central axis and has a body inner surface and at least one body bore diameter.
  • the drill rods comprise an underlying tubular composite lining that has a lining outer surface that is connected to at least the body inner surface of the midbody of the metallic body, the composite lining defining an operative bore that extends along the central axis and has at least one operative bore diameter.
  • Figure 1 illustrates a longitudinal cross-sectional view of one aspect of a drill string component having a fiber-composite reinforced midbody.
  • Figure 2 illustrates a longitudinal cross-sectional view of another aspect of a drill string component having a fiber-composite reinforced midbody and an increasing body bore diameter.
  • Figure 3 illustrates a longitudinal cross-sectional view of another aspect of a drill string component having a fiber-composite reinforced midbody and a V-shaped body bore diameter.
  • Figure 4 is a table comparing the response of a 2-3/4" conventional drill rod to the composite drill rod of the present invention.
  • Implementations described herein are directed toward drill string components that preserve load, torsional and impact capacity but minimize the weight of the drill string component as well as methods of using and manufacturing the same.
  • the present disclosure provides for drill rods comprising an integral tubular metallic body having a first end, an opposing second end, and an elongate midbody extending along a central axis between the first and second ends and where the metallic body defines a central bore that extends along the central axis and has a body inner surface and at least one body bore diameter.
  • the drill rods further comprise an underlying tubular composite lining that has a lining outer surface that is connected to at least the body inner surface of the midbody of the metallic body, the composite lining defining an operative bore that extends along the central axis and has at least one operative bore diameter.
  • implementations of the present disclosure provide for improved drill string components that preserve load, torsional and impact capacity while minimizing the weight of the drill string component.
  • implementations of the present disclosure maintain a continuous metal exterior surface and, thus, avoid any abrasive wear of the composite lining against the drilled hole or cuttings resulting therefrom.
  • maintaining a continuous metal rod for threading drill string components together and limiting the use of composite material to an interior lining avoids the alternative of assembling drill string components from dissimilar materials.
  • creating a drill string component by non- mechanicai bonding of steel or steel alloy to, for example, a composite or even an aluminum midbody can create a weak and/or brittle interface or joint that can be insufficient to withstand the impact, vibration and fatigue loading associated with typical drill string loading conditions.
  • there can also be insufficient annular space available to allow a combination of mechanical and chemical bonding in certain drilling applications such as, for example and without limitation, wireline core drilling and the like.
  • there is enough annular space to enable feasibility of such an approach in other applications, such as, for example and without limitation, energy, oil and like drilling applications,
  • implementations of the present invention provide for corrosion protection in, for example and without limitation, percussive drilling applications.
  • corrosive and/or acidic drilling fluids can be pumped through drill rod interiors and this can lead to stress corrosion fatigue failures involving crack initiation on the inner diameter of the drill rod interior.
  • the present disclosure comprises drill string components having a composite lining that provides increased protection against corrosion and can reduce or eliminate stress corrosion fatigue failures.
  • implementations of the present disclosure provide for more accurate drilling results by increasing the stifmess of the drill string components and, thus, the drill string.
  • the increased stiffiiess associated with the composite lining can result in an increased stiffness of the drill string component. This increased stiffness can reduce the deflection of the drill string and, correspondingly, the drilled hole, thereby providing more accurate drilling results such as, for example and without limitation, improved blasting efficiency when drilling blast holes, improved targeting in mineral exploration, and the like.
  • FIG. 1-3 various exemplary implementations of a drill string components that preserve load, torsional and impact capacity while minimizing the weight of the drill string component are illustrated.
  • a drill rod 100 comprises an integral tubular metallic body 101 further comprising a first end 102, an opposing second end 104, and an elongate midbody 106 extending along a central axis 108 between the first end 102 and second end 104.
  • the first end 102 of the tubular metallic body 101 can comprise a box end and a second end 104 can comprise a pin end.
  • both the first end 102 and the second end 104 can form a box end or both form a pin end.
  • the metallic body 101 can further define a central bore 110 that extends along the central axis 108 and has a body inner surface 112 and at least one body bore diameter 1 14,
  • an underlying tubular composite lining 116 having a lining outer surface 118 can be connected to at least a portion of the body inner surface 112 of the midbody 106 of the metallic body.
  • the composite lining 116 can define an operative bore 120 that can extend along the central axis and can have at least one operative bore diameter 122.
  • the composite lining can extend to a terminal end of the second end 104 or pin end of the tubular metallic body 101.
  • the drill rod 100 can have midbody 106 having a substantially constant body bore diameter 114 and a substantially constant operative bore diameter 120.
  • the cross-sectional thickness of at least the composite lining 116 is substantially constant across at least the body inner surface 112 of the midbody 106.
  • the body bore diameter 114 of the metallic body 101 can comprise a first bore diameter 114a and a second bore diameter 114b, wherein the first bore diameter can be less than the second bore diameter.
  • the second bore diameter 114b extends at least the length of the midbody 106.
  • the second bore diameter can extend the combined length of the midbody 106 and the second end 104.
  • the composite lining 116 can have a substantially constant cross- sectional thickness and can be configured to extend the longitudinal length corresponding to the second bore diameter 114b.
  • the liner cross-sectional thickness plus the tubular metallic body wall thickness is substantially constant across at least longitudinal length corresponding to the midbody 106.
  • the thickness of the composite lining 116 can comprise about 50% of the total wall thickness of at least the midbody 106.
  • the cross-sectional area of the composite lining 1 16 can comprise between about 10% to about 50% of the total cross-sectional area of at least the midbody 106 and, more preferably, between about 10% and about 30% of the total cross-sectional area of at least the midbody 106.
  • the composite lining 116 can be configured to provide between about 10% to 50% , more preferably between about 30% to 45%, and, preferred, about 44% of the moment of inertia or stiffness of at least the midbody 106.
  • the ratio of the thickness of the composite lining 116 of the total wall thickness of at least the midbody 106 can be about a 1 : 1 thickness ratio of composite to metal, for example and without limitation steel.
  • the ratio of the thickness of the composite lining 116 of the total wail thickness of at least the midbody 106 can be between about a 1:9 to about a 1 : 1 thickness ratio of composite to metal and, more preferably, between about a 1:9 to about a 3:7 thickness ratio of composite to metal.
  • the composite lining 116 can be configured to provide 44% of the moment of inertia or stiffness of at least the midbody 106 (or a moment of inertia ratio of 1 : 1.3 composite to steel).
  • the ratio of the thickness of the composite lining 116 of the total wail thickness of the pin end of the drill can less than about a 1 : 1 thickness ratio of composite to metal, for example and without limitation steel,
  • the ratio of the thickness of the composite lining 1 16 of the total wall thick 1 Iness of the pin end can be less than a range between about a 1 :9 to about a 1 : 1 thickness ratio of composite to metal. It is contemplated that the ratio of the thickness of the composite lining 116 of the total wall thickness of the pin end will be less then used in the midbody 106 due to the inherent stiffness of the pin end.
  • both the elastic modulus and the tensile strength of the composite lining 116 can be between about 1.5 and 2.5 and, more preferably about 2, times that of steel.
  • the elastic modulus of steel can be about 30 x 10 A 6 psi.
  • the tensile strength of conventional cold drawn steel tubing can be about 110,000 psi and the elastic limit or yield strength can be about 80 ksi. At least a portion of the drill rod joint ends are typically induction hardened to increase the elastic limit up to about 180,000 psi, but the elastic modulus remains constant.
  • the elastic modulus of the composite lining 116 can be up to about 60 x 10 ⁇ 6 psi, representing about twice the elastic modulus of conventional steel. It is contemplated that the elastic modulus of the composite lining 116 can be between about 40 to 90 MSI and, more preferably, between about 50 to 70 MSI. Similarly, the composite lining 116 tensile strength can be up to 240,000 psi, representing more than twice the tensile strength of steel tubing and about 1/3 greater than that of induction hardened rod joints. It is contemplated that the tensile strength of the composite lining 116 can be between about 200 to 300 KSI and, more preferably, between about 220 to 280 KSI.
  • a composite drill rod 100 having a cross- sectional of up to 50% composite lining 116 area at the midbody 106 can have a modulus of up to 1.50 times that of a conventional steel midbody and, in other aspects, up to 1.17 times the strength of a conventional steel midbody.
  • a drill rod 100 having a cross-sectional area of up to 33% composite lining 116 at the midbody 106 can have a modulus of up to 1.32 times that of a conventional steel midbody and, in other aspects, up to 1.10 times the strength of a conventional steel midbody.
  • the drill rod 100 can have improved response under dynamic loading conditions over conventional drill rods.
  • Computer simulations of the dynamic response of steel drill strings under compression and high r.p.m. indicate that the torque impulse loads from the drill bit create torsion and bending load waves that can rapidly travel up and reflect back down the drill string.
  • This dynamic response can magnify the impulse load by a factor of about 2 to about 3, and such magnification can exceed the elastic limit of the conventional drill rod.
  • exceeding the elastic limit of the conventional drill rod under these loading conditions can lead to permanent twisting and bending of the drill string which, in turn, prevents productive drilling or even seizing of the drill string in the hole.
  • these impulse loads are typically insufficient to overload the drill rod joints.
  • the composite liner takes the majority of the bending and torque load.
  • the stress in the steel can be reduced by about 20%, down to 80 ksi, to avoid yielding. Refer to Table 1 for a summary of results comparing the response of a 2-3/4" conventional drill rod to the drill rod 100.
  • the body bore diameter 114 of at least the midbody 106 can increase from a first bore diameter 114a to a second bore diameter 114b.
  • the body bore diameter 1 14 can increase from a first bore diameter to a second bore diameter across the combined lengths of the midbody 106 and the second end 104.
  • the composite lining 1 16 can have a constant cross-sectional thickness and can be configured to extend the longitudinal length corresponding to at least the midbody 106 and, optionally, the second end 104.
  • cross-sectional thickness 124 of the composite liner 116 can vary such thai the sum of the composite lining cross-sectional thickness 124 and the midbody cross-sectional thickness 126.
  • the tubular metallic body can further comprise a tubular wall and the body bore diameter 114 of the metallic body 101 can comprise a first bore diameter 114a and a second bore diameter 114b, wherein the first bore diameter can be less than the second bore diameter.
  • the body inner surface 112 of the midbody 106 can be configured to taper from both the respective first end 102 and second end 104 both having a first bore diameter 114a to a middle portion 128 of the midbody having a second bore diameter 114b.
  • the composite lining 116 can have a constant cross-sectional thickness and can be configured to extend the longitudinal length corresponding to the midbody 106.
  • cross-sectional thickness of the composite liner 116 can vary such that the sum of the cross-sectional thickness of the composite lining 106 and the cross-sectional thickness of at least the midbody 106 at any point can be substantially constant.
  • the underlying composite linings of the present disclosure can comprise a fiber- impregnated composite material.
  • the fiber-impregnated composite material can comprise carbon fiber.
  • the fiber-impregnated composite material can comprise a known quantity of pitch-based carbon fiber.
  • the composite material can comprise a carbon-fiber containing polymer or resin material
  • the composite material can at least partially comprise substantially unidirectionally-oriented carbon fiber.
  • substantially unidirectional fibers can be selectively configured to provide increased stiffness or increased torsional strength.
  • a composite material containing carbon fiber substantially aligned with the central axis 108 can be used to provide increased stiffness of the drill rod.
  • a composite material containing carbon fiber oriented at an angle relative to the central axis 108 can be used to provide increased torsional strength of the drill rod.
  • the total thickness of the midbody 106 can comprise a thickness of tubular metallic body sufficient to protect the composite liner 116 from abrasion against the hole wall.
  • the thickness of the tubular metallic body comprises at least about 50%, and, more preferably, at least about 70% of the total midbody thickness.
  • the fibers can be substantially bi-directionally-oriented with respect to the central axis 108.
  • the fibers can be cross-laid to form spirals, imparting the drill rod with both increased stiffness and increased torsional strength.
  • a predetermined percentage of the fibers can have a first direction.
  • the remaining fibers can have at least a second direction.
  • a drill rod 100 can comprise a detached composite lining 1 16.
  • the composite lining 116 need not be bonded to the body inner surface 112.
  • Figures 1-3 provide a number of different drill string components that preserve load, torsional and impact capacity but minimize the weight of a drill string component.
  • implementations described herein can also be described in terms acts and steps in a method for accomplishing a particular result. For example, a method comprising manufacturing drill string components that preserve load, torsional and impact capacity but minimize the weight of a drill string component is described above with reference to the components and diagrams of Figures 1 through 3.
  • the drill siring components having composite liners provided herein can provide increased stiffness of the component and the resulting drill string, enabling more accurate drilling results.
  • the present disclosure limits composite elements to linings only and maintains a continuous metal rod on the exterior; thus avoiding the need to join dissimilar materials along the length of the drill string component as well as exposing the composite liner to abrasive wear against the drilling hole or the cuttings.
  • the interior composite lining protects against potential corrosion as corrosive and/or acidic drilling fluids are pumped through the interior of the drill string component.

Abstract

L'invention concerne des mises en œuvres, qui comprennent des tiges de forage contenant un corps intégral tubulaire métallique comptant des premières extrémités, une seconde extrémité opposée et un corps intermédiaire allongé, qui s'étend le long d'un axe central, entre les premières et seconde extrémités, et où le corps métallique définit un trou central qui s'étend le long de l'axe central et qui a une surface interne de corps et au moins un diamètre de trou de corps. Selon d'autres aspects, les tiges de forage comprennent en outre un chemisage composite tubulaire sous-jacent qui présente une surface externe de chemisage, raccordée au moins à la surface interne de corps du corps intermédiaire du corps métallique, le chemisage composite définissant un trou d'opération qui s'étend le long de l'axe central et qui a au moins un diamètre de trou opérationnel.
PCT/US2013/078322 2012-12-31 2013-12-30 Matériaux élaborés destinés à des applications de type tige de forage WO2014106187A1 (fr)

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
US13/731,499 2012-12-31
US13/731,499 US20140182945A1 (en) 2012-12-31 2012-12-31 Engineered Materials for Drill Rod Applications
US201361794308P 2013-03-15 2013-03-15
US61/794,308 2013-03-15

Publications (1)

Publication Number Publication Date
WO2014106187A1 true WO2014106187A1 (fr) 2014-07-03

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Application Number Title Priority Date Filing Date
PCT/US2013/078322 WO2014106187A1 (fr) 2012-12-31 2013-12-30 Matériaux élaborés destinés à des applications de type tige de forage

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WO (1) WO2014106187A1 (fr)

Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4872519A (en) * 1988-01-25 1989-10-10 Eastman Christensen Company Drill string drill collars
CN2453110Y (zh) * 2000-12-12 2001-10-10 中国石油集团地球物理勘探局 高强度薄壁钻杆
US6799632B2 (en) * 2002-08-05 2004-10-05 Intelliserv, Inc. Expandable metal liner for downhole components
US20050103527A1 (en) * 2003-11-13 2005-05-19 Church Kris L. Dual wall drill string assembly

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4872519A (en) * 1988-01-25 1989-10-10 Eastman Christensen Company Drill string drill collars
CN2453110Y (zh) * 2000-12-12 2001-10-10 中国石油集团地球物理勘探局 高强度薄壁钻杆
US6799632B2 (en) * 2002-08-05 2004-10-05 Intelliserv, Inc. Expandable metal liner for downhole components
US20050039912A1 (en) * 2002-08-05 2005-02-24 Hall David R. Conformable Apparatus in a Drill String
US20050103527A1 (en) * 2003-11-13 2005-05-19 Church Kris L. Dual wall drill string assembly

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