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WO2003036027A1 - Lubrifiant pour puits de forage - Google Patents

Lubrifiant pour puits de forage Download PDF

Info

Publication number
WO2003036027A1
WO2003036027A1 PCT/GB2002/004786 GB0204786W WO03036027A1 WO 2003036027 A1 WO2003036027 A1 WO 2003036027A1 GB 0204786 W GB0204786 W GB 0204786W WO 03036027 A1 WO03036027 A1 WO 03036027A1
Authority
WO
WIPO (PCT)
Prior art keywords
tubular
expander tool
fuuerene
wellbore
tool
Prior art date
Application number
PCT/GB2002/004786
Other languages
English (en)
Inventor
Patrick G. Maguire
Khai Tran
Alexander Craig Mackay
Original Assignee
Weatherford/Lamb, 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
Application filed by Weatherford/Lamb, Inc. filed Critical Weatherford/Lamb, Inc.
Publication of WO2003036027A1 publication Critical patent/WO2003036027A1/fr

Links

Classifications

    • C—CHEMISTRY; METALLURGY
    • C23—COATING METALLIC MATERIAL; COATING MATERIAL WITH METALLIC MATERIAL; CHEMICAL SURFACE TREATMENT; DIFFUSION TREATMENT OF METALLIC MATERIAL; COATING BY VACUUM EVAPORATION, BY SPUTTERING, BY ION IMPLANTATION OR BY CHEMICAL VAPOUR DEPOSITION, IN GENERAL; INHIBITING CORROSION OF METALLIC MATERIAL OR INCRUSTATION IN GENERAL
    • C23C—COATING METALLIC MATERIAL; COATING MATERIAL WITH METALLIC MATERIAL; SURFACE TREATMENT OF METALLIC MATERIAL BY DIFFUSION INTO THE SURFACE, BY CHEMICAL CONVERSION OR SUBSTITUTION; COATING BY VACUUM EVAPORATION, BY SPUTTERING, BY ION IMPLANTATION OR BY CHEMICAL VAPOUR DEPOSITION, IN GENERAL
    • C23C30/00—Coating with metallic material characterised only by the composition of the metallic material, i.e. not characterised by the coating process
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B82—NANOTECHNOLOGY
    • B82Y—SPECIFIC USES OR APPLICATIONS OF NANOSTRUCTURES; MEASUREMENT OR ANALYSIS OF NANOSTRUCTURES; MANUFACTURE OR TREATMENT OF NANOSTRUCTURES
    • B82Y30/00—Nanotechnology for materials or surface science, e.g. nanocomposites
    • C—CHEMISTRY; METALLURGY
    • C23—COATING METALLIC MATERIAL; COATING MATERIAL WITH METALLIC MATERIAL; CHEMICAL SURFACE TREATMENT; DIFFUSION TREATMENT OF METALLIC MATERIAL; COATING BY VACUUM EVAPORATION, BY SPUTTERING, BY ION IMPLANTATION OR BY CHEMICAL VAPOUR DEPOSITION, IN GENERAL; INHIBITING CORROSION OF METALLIC MATERIAL OR INCRUSTATION IN GENERAL
    • C23C—COATING METALLIC MATERIAL; COATING MATERIAL WITH METALLIC MATERIAL; SURFACE TREATMENT OF METALLIC MATERIAL BY DIFFUSION INTO THE SURFACE, BY CHEMICAL CONVERSION OR SUBSTITUTION; COATING BY VACUUM EVAPORATION, BY SPUTTERING, BY ION IMPLANTATION OR BY CHEMICAL VAPOUR DEPOSITION, IN GENERAL
    • C23C30/00—Coating with metallic material characterised only by the composition of the metallic material, i.e. not characterised by the coating process
    • C23C30/005—Coating with metallic material characterised only by the composition of the metallic material, i.e. not characterised by the coating process on hard metal substrates
    • 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
    • E21B17/02—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 OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/02—Subsoil filtering
    • E21B43/10—Setting of casings, screens, liners or the like in wells
    • E21B43/103—Setting of casings, screens, liners or the like in wells of expandable casings, screens, liners, or the like

Definitions

  • the present invention relates to lubrication of components for use in a wellbore. More particularly, the invention relates to the lubrication of wellbore components with a fuUerene. More particularly still, the invention relates to reducing friction encountered during operation of a downhole tool in a wellbore.
  • Galling of wellbore components due to friction has always been a problem in wellbore operations. Galling is surface damage to mating, moving, metal parts due to friction between the parts. In a wellbore, galling can take place between moving parts of a single component, like slips and cones of a packer or between a component and some other surface in the wellbore that is necessarily contacted as a component operates. Galling is also a problem for threaded connections that may be made up on the surface of the well and then utilized in the wellbore. Soft metals are more susceptible to galling than hard metals, and similar metal surfaces are more prone to galling than dissimilar metal surfaces.
  • Wellbore threads are often specialized and perform functions other than simply holding parts together.
  • the threaded connections between sequential lengths of tubing are frequently required to form gas tight seals.
  • these "proprietary" threads that are capable of providing a gas tight seal for tubular connections.
  • these threads have special geometric designs including shoulders that form metal to metal seals to prevent the migration of gases through the threaded connection. Because of the gas-sealing connections, tolerances are especially close and the surfaces of the threads come into contact with each other frequently as they are threaded together.
  • the proprietary threads are commonly formed of a metal that is relatively soft, such as corrosive resistant alloys. With un-lubricated threaded connections, galling often results as the connection is made up or taken apart.
  • Repair of the galled threads means reworking or replacing the threads or the component upon which they are formed. Because the threaded connection is typically made or unmade during assembly or disassembly of a component and after most of the value has been added to a component, galling can result in a complete loss of a tool or assembly.
  • Galling is also a problem when expanding tubulars in a wellbore.
  • Expansion technology enables a tubular to be expanded and its diameter to be increased in a wellbore.
  • a liner for example, can be hung off of an existing string of casing without the use of a conventional slip assembly.
  • Tubulars can be expanded with a swedge or tapered cone that is physically pushed through the inside of the tubular with enough force that the inside diameter of the tubular is increased to at least the outside diameter of the cone.
  • expander tools are fluid powered and are run into a wellbore on a working string.
  • the hydraulic expander tools include radially extendable rollers which are urged outward radially from the body of the expander tool and into contact with a tubular therearound. As sufficient fluid pressure is generated upon a piston surface behind these rollers, the tubular is expanded past its point of plastic deformation. By rotating the expander tool in the wellbore and moving it axially, a tubular can be expanded along a predetermined length in a wellbore.
  • Figure 1 is an exploded view of an exemplary expander tool 100 for expanding a tubular (shown as 200 in Figure 2).
  • a tubular is expanded by an expander tool 100 acting outwardly against the inside surface of the tubular.
  • the expander tool 100 has a body 102 which is hollow and generally tubular with connectors 104 and 106 for connection to other components (not shown) of a downhole assembly.
  • the connectors 104 and 106 are of a reduced diameter compared to the outside diameter of the longitudinally central body part of the tool 100.
  • the central body part 102 of the expander tool 100 shown in Figure 2 has three recesses 114, each holding a respective roller 116.
  • Each of the recesses 114 has parallel sides and extends radially from a radially perforated tubular core (not shown) of the tool 100.
  • Each of the mutually identical rollers 116 is somewhat cylindrical and barrelled.
  • Each of the rollers 116 is mounted by means of an axle 118 at each end of the respective roller 116 and the axles are mounted in slidable pistons 120.
  • the rollers 116 are arranged for rotation about a respective rotational axis that is parallel to the longitudinal axis of the tool 100 and radially offset therefrom at 120-degree mutual circumferential separations around the central body 102.
  • the axles 118 are formed as integral end members of the rollers 116, with the pistons 120 being radially slidable, one piston 120 being slidably sealed within each radially extended recess 114.
  • the inner end of each piston 120 is exposed to the pressure of fluid within the hollow core of the tool 100 by way of the radial perforations in the tubular core. In this manner, pressurized fluid provided from the surface of the well, via a working string 310, can actuate the pistons 120 and cause them to extend outward whereby the rollers 116 contact the inner surface of a tubular to be expanded.
  • a new section of liner is run into the wellbore using a run-in string. As the assembly reaches that depth in the wellbore where the liner is to be hung, the new liner is cemented in place. Before the cement sets, an expander tool is actuated and the liner is expanded into contact with the existing casing therearound. By rotating the expander tool in place, the new lower string of casing can be fixed onto the previous upper string of casing, and the annular area between the two tubulars is sealed.
  • Figure 2 is a partial section view of a tubular 200 in a wellbore 300.
  • the tubular 200 is disposed coaxially within the casing 400.
  • An expander tool 100 is attached to a working string 310 and visible within the tubular 200.
  • the tubular 200 is run into the wellbore 300 with the expander tool 100 disposed therein.
  • the working string 310 extends below the expander tool 100 to facilitate cementing of the tubular 200 in the wellbore 300 prior to expansion of the tubular 200 into the casing 400.
  • a remote connection (not shown) between the working, or run-in, string 310 and the tubular 200 temporarily connects the tubular 200 to the run-in string 310 and supports the weight of the tubular 200.
  • the temporary connection may be a collett (not shown), and the tubular 200 may be a string of casing.
  • Figure 2 depicts the expander tool 100 with the rollers 116 retracted, so that the expander tool 100 may be easily moved within the tubular 200 and placed in the desired location for expansion of the tubular 200.
  • Hydraulic fluid (not shown) is pumped from the surface to the expander tool 100 through the working string 310.
  • hydraulic pressure is used to actuate the pistons (not shown) and to extend the rollers 116 so that they may contact the inner surface of the tubular 200, thereby expanding the tubular 200.
  • Figure 3 is a partial section view of the tubular 200 partially expanded by the expander tool 100.
  • the pistons (not shown) in the expander tool 100 are actuated and the rollers 116 are extended until they contact the inside surface of the tubular 200.
  • the rollers 116 of the expander tool 100 are further extended until the rollers 116 plastically deform the tubular 200 into a state of permanent expansion.
  • the working string 310 and the expander tool 100 are rotated during the expansion process, and the tubular 200 is expanded until the tubular' s outer surface contacts the inner surface of the casing 400.
  • the working string 310 and expander tool 100 are then translated within the tubular 200 until the desired length of the tubular 200 has been expanded.
  • Galling takes place during expansion due to friction between an outside surface of an outwardly extended roller and an inside surface of a tubular being expanded. Friction between the surfaces increases the amount of torque needed at the surface of the well to rotate the expansion tool in the wellbore and complete the expansion process. Increased friction causes galling of the contacting surfaces leading to even greater friction and less efficiency of the expansion tool.
  • lubricants In order to reduce friction and prevent galling in a wellbore, lubricants have been used on threads and on surfaces between moving parts, like the rollers of expander tools and tubulars to be expanded. Lubricants have included grease and oil. Sometimes, soft metals such as copper, lead, zinc, or tin are added to the material making up contacting surfaces. The reasons for adding the soft metals are two fold. First, the soft metals provide a barrier that prevents galling and second, they deform under pressure and act as a lubricant.
  • Embodiments of the present invention provide methods and apparatus for reducing friction and preventing galling between surfaces in a wellbore.
  • mating threads are coated with fuUerene to reduce galling of the threads during make up and break down.
  • the fuUerene is a spherically shaped carbon 60 molecule otherwise known as buckyball or C 6 o-
  • the fuUerene coating provides an intermediate surface between two metal surfaces, thereby preventing galling between the two surfaces.
  • the fuUerene is placed between the roller of an expander tool and the surface of the tubular to be expanded in order to reduce friction and prevent galling.
  • the present invention provides a method for expanding a tubular in a wellbore. Initially, a tubular is disposed in the wellbore. The tubular is then expanded using an expander tool.
  • the expander tool and the expanded area of the tubular include a coating of fuUerene to prevent galling of the components. Furthermore, the fuUerene coating reduces the friction forces between the tool and the tubular, thereby increasing efficiency.
  • threaded connections are coated with fuUerene to prevent galling.
  • threaded connections for gas tight seals are coated with fuUerene.
  • Figure 1 is an exploded view of an exemplary expander tool
  • Figure 2 is a partial section view of a tubular in a wellbore showing an expander tool attached to a working string also disposed within the tubular.
  • Figure 3 is a partial section view of the partially expanded tubular of Figure 2.
  • Figure 4 is an illustration of carbon 60, buckminsterfullerene.
  • Figure 5 is a partial section view of a threaded connection between two tubulars.
  • Embodiments of the present invention are related to a downhole tool with a coating of fuUerene to reduce friction and prevent galling between two contacting surfaces.
  • a fuUerene is a carbon structure having each carbon atom bonded to three other carbon atoms. The carbon atoms so joined curve around to form a molecule with a cage-like structure and aromatic properties.
  • the most famous member of the fuUerenes is the buckyball, a fuUerene with sixty carbon atoms.
  • the sixty carbon atoms of the buckyball form a shape resembling a soccer ball.
  • a structural diagram representing buckyball, more formally known as buckminsterfullerene or C 6 o . is shown in Figure 4.
  • C 60 is particularly suitable for use as a lubricant to reduce friction and prevent galling.
  • FuUerenes are commonly derived by contact-arc vaporization of a graphite rod, which results in the formation of raw soot.
  • the raw soot produced by this process primarily comprises a mixture of two fuUerenes, C 60 and C 0 in a ratio of about 10 to 1 respectively, accounting for about 5 to 10% of the total soot.
  • FuUerenes such as C 60 , C o, C 76 , C 78 , C 84 , etc., can be deposited on a substrate alone following purification, or as a mixture with one or more fuUerenes.
  • FuUerenes can be recovered from raw soot by extraction with organic solvents, such as benzene or toluene, followed by precipitative or evaporative deposition of the fuUerenes on a surface of a substrate and solvent removal.
  • fuUerenes can be recovered by sublimation under vacuum with fu erene vapour being condensed as a film upon a relatively cool substrate surface.
  • FuUerenes may be coated on a surface by ion-sputtering of purified fuUerene or raw unprocessed fullerene-containing soot.
  • the fuUerene may also be deposited by other methods known to a person of ordinary skill in the art. Using sputtering, the fuUerene is arranged as a target within a vacuum chamber in spaced relation to a surface to be coated. The surface may be positioned proximate a grounded electrode, and the target positioned proximate a conductive electrode.
  • the chamber is back-filled with a gas at low pressure and a source of potential is applied to the electrodes.
  • the potential source serves both to produce a plasma of the gas between the spaced electrodes and to attract the gas ions to the target.
  • the potential causes the gas ions to bombard the target and break or knock off fuUerene atoms or molecules from the target. These atoms or molecules settle on the surface and form a layer of fuUerene.
  • the contact surfaces of the rollers 116 and the tubular 200 may be coated with a layer of fuUerene.
  • the surfaces are coated with C 60 .
  • Other possible fuUerenes for use as the coating include C 70 , C 76 , C 78 , C 84 , and combinations thereof.
  • the coating may further comprise at least one carrier component.
  • the carrier components may include, but not limited to, zirconium and ceramic, and may range from about 0% to about less than 100%, preferably about 1% to about 50%, and most preferably about 5% to about 25% of the composition of the coating.
  • the coating of fuUerene may be placed upon a surface using methods known to a person of ordinary skill in the art.
  • the target can be rod-shaped to facilitate the deposition of fuUerenes on an interior surface of the tubular.
  • the coating of spherically shaped C 60 acts as molecular ball bearings between the rollers 116 and the tubular 200.
  • molecular C 60 breaks loose from the coating to form a layer of molecular ball bearings.
  • the ball bearings reduce the friction between the rollers 116 and the tubular 200. Consequently, less torque is needed to overcome the friction between the rollers 116 and the tubular 200. The result is a more efficient expansion of the tubular.
  • the C 60 coating may also prevent galling of surfaces by acting as a sacrificial lubricant layer disposed between the rollers 116 and the tubular 200. Specifically, the C 60 coating prevents the two surfaces from coming into contact, thereby suppressing any galling effect.
  • the C 60 may be used with a swedge shaped mandrel or a cone to increase the diameter of a tubular without the use of an expander tool having extendable rollers.
  • a cone-shaped member is run into a wellbore and into contact with the upper end of a tubular to be expanded.
  • the cone can be run into the wellbore on a lower end of a tubular run in string.
  • the cone is designed with an outer diameter greater than the inner diameter of the unexpended tubular.
  • the outer surface of the cone may be coated with C 60 to reduce friction and prevent galling as the cone is urged into the tubular.
  • an inner surface of the tubular in contact with the cone may be coated with C 60 , or both contacting surfaces may be coated with C 60 .
  • a tubular is enlarged in situ in order to form a polish bore receptacle ("PBR") therein.
  • PBR polish bore receptacle
  • the use of a coating of C 60 according to the present invention will help ensure that the PBR has surface characteristics according to specification.
  • threaded connections may be coated with C 6 o to reduce friction and avoid galling.
  • either or both of the pipe ends may be coated with C 60 .
  • the C 60 coating may be deposited on the threaded connections by sputtering. Providing a layer of C 6 o on at least one of the threaded surfaces minimizes friction between the threads.
  • the C 60 coating may be used on a production tubing to prevent galling as shown in Figure 5.
  • Figure 5 is a partial section view of a first production tubing 510 having a first thread 515 mating with a second production tubing 520 having a second thread 525.
  • the production tubings 510, 520 may be manufactured from corrosive resistance alloy consisting of softer metals such as nickel and chrome.
  • the threads 515, 525 formed on the production tubings 510, 520 form a metal to metal seal to prevent gas leakage.
  • the outer threads 515, or the "pin,” are coated with C 60 prior to being connected with the inner threads 525, or the "box.”
  • both threads 515, 525 may be coated with C 60 or only one thread may be coated.
  • the C 60 prevents galling of the threads 515, 525 as the connection between the tubulars is made or broken.
  • the C 60 may also be used on drill pipe, casing, and other tubulars requiring threaded connections.

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  • Engineering & Computer Science (AREA)
  • Chemical & Material Sciences (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Geology (AREA)
  • Materials Engineering (AREA)
  • Mechanical Engineering (AREA)
  • Physics & Mathematics (AREA)
  • Fluid Mechanics (AREA)
  • Nanotechnology (AREA)
  • Environmental & Geological Engineering (AREA)
  • Organic Chemistry (AREA)
  • Metallurgy (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Condensed Matter Physics & Semiconductors (AREA)
  • General Physics & Mathematics (AREA)
  • Crystallography & Structural Chemistry (AREA)
  • Composite Materials (AREA)
  • Earth Drilling (AREA)

Abstract

L'invention concerne des procédés et des dispositifs permettant de réduire le frottement et d'éviter l'éraillure entre des surfaces à l'intérieur d'un puits de forage. Selon un aspect, on utilise du fullerène comme revêtement sur des filets de couplage, ce qui permet de réduire l'éraillure des filets en cours d'assemblage et de désassemblage. Selon un autre aspect, on utilise du fullerène entre les surfaces d'un instrument d'expansion et d'une structure tubulaire assujettie à l'expansion pour réduire le frottement et éviter l'éraillure entre l'instrument et la structure considérés. De préférence, le fullerène utilisé se présente sous la forme d'une molécule de carbone 60 sphérique, que l'on appelle encore footballène ou C60. Ce type de revêtement tient lieu de surface intermédiaire entre deux surfaces métalliques, empêchant l'éraillure réciproque. Selon un autre aspect, le fullerène est placé entre le cylindre d'un instrument d'expansion et la surface de la structure tubulaire assujettie à l'expansion, de manière à réduire le frottement et l'éraillure.
PCT/GB2002/004786 2001-10-23 2002-10-22 Lubrifiant pour puits de forage WO2003036027A1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US10/003,721 US20030075340A1 (en) 2001-10-23 2001-10-23 Lubricant for use in a wellbore
US10/003,721 2001-10-23

Publications (1)

Publication Number Publication Date
WO2003036027A1 true WO2003036027A1 (fr) 2003-05-01

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ID=21707258

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/GB2002/004786 WO2003036027A1 (fr) 2001-10-23 2002-10-22 Lubrifiant pour puits de forage

Country Status (2)

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US (1) US20030075340A1 (fr)
WO (1) WO2003036027A1 (fr)

Families Citing this family (9)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB0108638D0 (en) * 2001-04-06 2001-05-30 Weatherford Lamb Tubing expansion
US7172027B2 (en) 2001-05-15 2007-02-06 Weatherford/Lamb, Inc. Expanding tubing
GB0215659D0 (en) * 2002-07-06 2002-08-14 Weatherford Lamb Formed tubulars
CA2616055C (fr) * 2007-01-03 2012-02-21 Weatherford/Lamb, Inc. Systeme et methodes d'expansion tubulaire
RU2327733C1 (ru) * 2007-02-06 2008-06-27 Сергей Дмитриевич Кущ Триботехническая смазка и смазочная композиция
US9097076B2 (en) * 2013-02-07 2015-08-04 Weatherford Technology Holdings, Llc Hard surfacing non-metallic slip components for downhole tools
US9273527B2 (en) * 2013-02-07 2016-03-01 Weatherford Technology Holdings, Llc Hard surfacing metallic slip components for downhole tools
US9605526B2 (en) 2013-11-21 2017-03-28 Halliburton Energy Services, Inc. Friction and wear reduction of downhole tubulars using graphene
US11898422B2 (en) 2020-11-03 2024-02-13 Saudi Arabian Oil Company Diamond coating on the cone for expandable tubulars

Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
DE4219580A1 (de) * 1992-06-15 1993-12-16 Eckard Dipl Ing Schlenker Kugelgelenk
WO1999006670A1 (fr) * 1997-08-01 1999-02-11 Shell Internationale Research Maatschappij B.V. Production d'une isolation locale entre l'interieur et l'exterieur d'un systeme de puits
WO2001016516A1 (fr) * 1999-08-27 2001-03-08 Sumitomo Metal Industries, Ltd. Joint fileté pour conduit de puits de pétrole

Patent Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
DE4219580A1 (de) * 1992-06-15 1993-12-16 Eckard Dipl Ing Schlenker Kugelgelenk
WO1999006670A1 (fr) * 1997-08-01 1999-02-11 Shell Internationale Research Maatschappij B.V. Production d'une isolation locale entre l'interieur et l'exterieur d'un systeme de puits
WO2001016516A1 (fr) * 1999-08-27 2001-03-08 Sumitomo Metal Industries, Ltd. Joint fileté pour conduit de puits de pétrole
EP1211451A1 (fr) * 1999-08-27 2002-06-05 Sumitomo Metal Industries, Ltd. Joint filet pour conduit de puits de p trole

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