WO2013082134A1 - Équipement pétrolier à coefficient de frottement réduit - Google Patents

Équipement pétrolier à coefficient de frottement réduit Download PDF

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Publication number
WO2013082134A1
WO2013082134A1 PCT/US2012/066825 US2012066825W WO2013082134A1 WO 2013082134 A1 WO2013082134 A1 WO 2013082134A1 US 2012066825 W US2012066825 W US 2012066825W WO 2013082134 A1 WO2013082134 A1 WO 2013082134A1
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WO
WIPO (PCT)
Prior art keywords
coiled tubing
base metal
oilfield component
polymer layer
passing
Prior art date
Application number
PCT/US2012/066825
Other languages
English (en)
Inventor
Joseph Varkey
Original Assignee
Schlumberger Canada Limited
Services Petroliers Schlumberger
Schlumberger Holdings Limited
Schlumberger Technology B.V.
Prad Research And Development Limited
Schlumberger Technology Corporation
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 Canada Limited, Services Petroliers Schlumberger, Schlumberger Holdings Limited, Schlumberger Technology B.V., Prad Research And Development Limited, Schlumberger Technology Corporation filed Critical Schlumberger Canada Limited
Publication of WO2013082134A1 publication Critical patent/WO2013082134A1/fr

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Classifications

    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B32—LAYERED PRODUCTS
    • B32B—LAYERED PRODUCTS, i.e. PRODUCTS BUILT-UP OF STRATA OF FLAT OR NON-FLAT, e.g. CELLULAR OR HONEYCOMB, FORM
    • B32B15/00—Layered products comprising a layer of metal
    • B32B15/04—Layered products comprising a layer of metal comprising metal as the main or only constituent of a layer, which is next to another layer of the same or of a different material
    • B32B15/08—Layered products comprising a layer of metal comprising metal as the main or only constituent of a layer, which is next to another layer of the same or of a different material of synthetic resin
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B32—LAYERED PRODUCTS
    • B32B—LAYERED PRODUCTS, i.e. PRODUCTS BUILT-UP OF STRATA OF FLAT OR NON-FLAT, e.g. CELLULAR OR HONEYCOMB, FORM
    • B32B1/00—Layered products having a non-planar shape
    • B32B1/08—Tubular products
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B32—LAYERED PRODUCTS
    • B32B—LAYERED PRODUCTS, i.e. PRODUCTS BUILT-UP OF STRATA OF FLAT OR NON-FLAT, e.g. CELLULAR OR HONEYCOMB, FORM
    • B32B15/00—Layered products comprising a layer of metal
    • B32B15/18—Layered products comprising a layer of metal comprising iron or steel
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B32—LAYERED PRODUCTS
    • B32B—LAYERED PRODUCTS, i.e. PRODUCTS BUILT-UP OF STRATA OF FLAT OR NON-FLAT, e.g. CELLULAR OR HONEYCOMB, FORM
    • B32B15/00—Layered products comprising a layer of metal
    • B32B15/20—Layered products comprising a layer of metal comprising aluminium or copper
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B32—LAYERED PRODUCTS
    • B32B—LAYERED PRODUCTS, i.e. PRODUCTS BUILT-UP OF STRATA OF FLAT OR NON-FLAT, e.g. CELLULAR OR HONEYCOMB, FORM
    • B32B27/00—Layered products comprising a layer of synthetic resin
    • B32B27/18—Layered products comprising a layer of synthetic resin characterised by the use of special additives
    • B32B27/20—Layered products comprising a layer of synthetic resin characterised by the use of special additives using fillers, pigments, thixotroping agents
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B32—LAYERED PRODUCTS
    • B32B—LAYERED PRODUCTS, i.e. PRODUCTS BUILT-UP OF STRATA OF FLAT OR NON-FLAT, e.g. CELLULAR OR HONEYCOMB, FORM
    • B32B27/00—Layered products comprising a layer of synthetic resin
    • B32B27/28—Layered products comprising a layer of synthetic resin comprising synthetic resins not wholly covered by any one of the sub-groups B32B27/30 - B32B27/42
    • B32B27/288—Layered products comprising a layer of synthetic resin comprising synthetic resins not wholly covered by any one of the sub-groups B32B27/30 - B32B27/42 comprising polyketones
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B32—LAYERED PRODUCTS
    • B32B—LAYERED PRODUCTS, i.e. PRODUCTS BUILT-UP OF STRATA OF FLAT OR NON-FLAT, e.g. CELLULAR OR HONEYCOMB, FORM
    • B32B27/00—Layered products comprising a layer of synthetic resin
    • B32B27/32—Layered products comprising a layer of synthetic resin comprising polyolefins
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B32—LAYERED PRODUCTS
    • B32B—LAYERED PRODUCTS, i.e. PRODUCTS BUILT-UP OF STRATA OF FLAT OR NON-FLAT, e.g. CELLULAR OR HONEYCOMB, FORM
    • B32B27/00—Layered products comprising a layer of synthetic resin
    • B32B27/32—Layered products comprising a layer of synthetic resin comprising polyolefins
    • B32B27/322—Layered products comprising a layer of synthetic resin comprising polyolefins comprising halogenated polyolefins, e.g. PTFE
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B32—LAYERED PRODUCTS
    • B32B—LAYERED PRODUCTS, i.e. PRODUCTS BUILT-UP OF STRATA OF FLAT OR NON-FLAT, e.g. CELLULAR OR HONEYCOMB, FORM
    • B32B27/00—Layered products comprising a layer of synthetic resin
    • B32B27/34—Layered products comprising a layer of synthetic resin comprising polyamides
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B32—LAYERED PRODUCTS
    • B32B—LAYERED PRODUCTS, i.e. PRODUCTS BUILT-UP OF STRATA OF FLAT OR NON-FLAT, e.g. CELLULAR OR HONEYCOMB, FORM
    • B32B7/00—Layered products characterised by the relation between layers; Layered products characterised by the relative orientation of features between layers, or by the relative values of a measurable parameter between layers, i.e. products comprising layers having different physical, chemical or physicochemical properties; Layered products characterised by the interconnection of layers
    • B32B7/04—Interconnection of layers
    • B32B7/12—Interconnection of layers using interposed adhesives or interposed materials with bonding properties
    • 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
    • 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
    • E21B19/00—Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables
    • E21B19/22—Handling reeled pipe or rod units, e.g. flexible drilling pipes
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B32—LAYERED PRODUCTS
    • B32B—LAYERED PRODUCTS, i.e. PRODUCTS BUILT-UP OF STRATA OF FLAT OR NON-FLAT, e.g. CELLULAR OR HONEYCOMB, FORM
    • B32B2255/00—Coating on the layer surface
    • B32B2255/06—Coating on the layer surface on metal layer
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B32—LAYERED PRODUCTS
    • B32B—LAYERED PRODUCTS, i.e. PRODUCTS BUILT-UP OF STRATA OF FLAT OR NON-FLAT, e.g. CELLULAR OR HONEYCOMB, FORM
    • B32B2255/00—Coating on the layer surface
    • B32B2255/20—Inorganic coating
    • B32B2255/205—Metallic coating
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B32—LAYERED PRODUCTS
    • B32B—LAYERED PRODUCTS, i.e. PRODUCTS BUILT-UP OF STRATA OF FLAT OR NON-FLAT, e.g. CELLULAR OR HONEYCOMB, FORM
    • B32B2262/00—Composition or structural features of fibres which form a fibrous or filamentary layer or are present as additives
    • B32B2262/02—Synthetic macromolecular fibres
    • B32B2262/0261—Polyamide fibres
    • B32B2262/0269—Aromatic polyamide fibres
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B32—LAYERED PRODUCTS
    • B32B—LAYERED PRODUCTS, i.e. PRODUCTS BUILT-UP OF STRATA OF FLAT OR NON-FLAT, e.g. CELLULAR OR HONEYCOMB, FORM
    • B32B2262/00—Composition or structural features of fibres which form a fibrous or filamentary layer or are present as additives
    • B32B2262/10—Inorganic fibres
    • B32B2262/101—Glass fibres
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B32—LAYERED PRODUCTS
    • B32B—LAYERED PRODUCTS, i.e. PRODUCTS BUILT-UP OF STRATA OF FLAT OR NON-FLAT, e.g. CELLULAR OR HONEYCOMB, FORM
    • B32B2262/00—Composition or structural features of fibres which form a fibrous or filamentary layer or are present as additives
    • B32B2262/10—Inorganic fibres
    • B32B2262/106—Carbon fibres, e.g. graphite fibres
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B32—LAYERED PRODUCTS
    • B32B—LAYERED PRODUCTS, i.e. PRODUCTS BUILT-UP OF STRATA OF FLAT OR NON-FLAT, e.g. CELLULAR OR HONEYCOMB, FORM
    • B32B2307/00—Properties of the layers or laminate
    • B32B2307/70—Other properties
    • B32B2307/714—Inert, i.e. inert to chemical degradation, corrosion
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B32—LAYERED PRODUCTS
    • B32B—LAYERED PRODUCTS, i.e. PRODUCTS BUILT-UP OF STRATA OF FLAT OR NON-FLAT, e.g. CELLULAR OR HONEYCOMB, FORM
    • B32B2597/00—Tubular articles, e.g. hoses, pipes
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F16—ENGINEERING ELEMENTS AND UNITS; GENERAL MEASURES FOR PRODUCING AND MAINTAINING EFFECTIVE FUNCTIONING OF MACHINES OR INSTALLATIONS; THERMAL INSULATION IN GENERAL
    • F16L—PIPES; JOINTS OR FITTINGS FOR PIPES; SUPPORTS FOR PIPES, CABLES OR PROTECTIVE TUBING; MEANS FOR THERMAL INSULATION IN GENERAL
    • F16L9/00—Rigid pipes
    • F16L9/14—Compound tubes, i.e. made of materials not wholly covered by any one of the preceding groups
    • F16L9/147—Compound tubes, i.e. made of materials not wholly covered by any one of the preceding groups comprising only layers of metal and plastics with or without reinforcement

Definitions

  • Spooled conveyances such as coiled tubing are used in downhole wellbore operations and/or applications such as, but not limited to, fluid pumping, fracturing, acidizing, and/or drilling.
  • the tubing In the oilfield, the tubing often disposed on a reel, which may be in turned disposed on a coiled tubing truck 8 with a tool 9 attached to an end thereof, such as those shown in Fig. 1.
  • the coiled tubing 10 is paid out from a reel, straightened out and then conveyed into a wellbore 12 penetrating a subterranean formation 14.
  • the coiled tubing 10 may have a coefficient of friction ranging from about 0.28 to about 0.35.
  • the number of points of contact increases and, in wells having deviated portions 16, such as that shown in Fig. 1 , the number of contact points may increase even further.
  • the accumulated friction among all the contact points within the wellbore 12 along the length of the coiled tubing 10 in these deeper wells may reach a point where the added or accumulated friction slows and/or stops the progress of the tubing 10 such that the tubing 10 can be advanced no further.
  • An embodiment of a method for coating an oilfield component comprises providing an oilfield component base metal, passing the oilfield component base metal through a heat source, extruding a polymer layer over the oilfield component base metal, the polymer layer bonding to the oilfield component base metal to form a completed oilfield component having a reduced coefficient of friction.
  • passing the base metal through the heat source modifies the exterior surface of the base metal.
  • extruding comprises extruding a polymer layer comprising a modified polyolefin, a modified TPX, PEEK, PEK and/or a modified fluoropolymer.
  • the polymer layer may be amended with short fibers to provide the reduced coefficient of friction.
  • the method further comprises extruding an outer jacket polymer layer over the polymer layer, the jacket layer bonding to the polymer layer to form the completed oilfield component.
  • the outer jacket layer may comprise a polyolefin, a polyamide, an unmodified fluoropolymer, an unmodified aromatic polymer, a reinforced aromatic polymer, and/or a reinforced fluoropolymer.
  • the outer jacket layer may be reinforced with carbon, glass, aramid or any other suitable natural or synthetic fiber, fibers in polymer matrix, micron sized PTFE, Graphite, and/or Ceramer.
  • the oilfield component comprises coiled tubing and further comprising disposing the completed coiled tubing on a reel, deploying the completed coiled tubing into a wellbore, wherein the reduced coefficient of friction allows the coiled tubing to be deployed at extended lengths in a deviated wellbore.
  • the base metal comprises copper-clad steel, aluminum-clad steel, anodized aluminum-clad steel, titanium-clad steel, carpenter alloy 20Mo6HS, GD31 Mo, austenitic stainless steel, high strength galvanized carbon steel, titanium clad copper, and/or any other suitable metal or alloys.
  • the method further comprises coating the exterior surface of the oilfield component with another metal or metals prior to passing the oilfield component through the heat source.
  • Coating may comprise metal deposition by electro plasma technology (EPT), electrolytic coating, gas plasma coating, arc spraying or any other suitable coating/deposition method.
  • passing the oilfield component through a heat source comprises passing the oilfield component through an induction heater, a radiant heater, a conduction heater, and/or a convection heater.
  • the completed oilfield component comprises a coefficient of friction of about 0.10 to about 0.20.
  • the oilfield component comprises at least one of coiled tubing, jointed tubing, casing string, drill pipe segments, downhole tool components surface equipment components, and drill stems. The method may further comprise use of the oilfield component in an oilfield, in a wellbore, or in conjunction with an oilfield operation.
  • An embodiment of a method for forming a coated coiled tubing comprises providing a coiled tubing comprising a base metal, passing the coiled tubing through a heat source, extruding a polymer layer over the coiled tubing, the polymer layer bonding to the base metal of the coiled tubing to form a completed coiled tubing having a reduced coefficient of friction.
  • passing the base metal through the heat source modifies the exterior surface of the base metal.
  • the method further comprises extruding an outer jacket polymer layer over the polymer layer, the jacket layer bonding to the polymer layer to form the completed coiled tubing.
  • the method further comprises disposing the completed coiled tubing on a reel, deploying the completed coiled tubing into a wellbore, wherein the reduced coefficient of friction allows the coiled tubing to be deployed at extended lengths in a deviated wellbore.
  • passing the coiled tubing through a heat source comprises passing the coiled tubing through an induction heater, a radiant heater, a conduction heater, and/or a convection heater.
  • the method further comprises coating the exterior surface of the coiled tubing with another metal or metals prior to passing the coiled tubing through the heat source.
  • FIG. 1 is a schematic view of a spooled conveyance disposed in a wellbore.
  • Figs. 2a through 2c are radial cross-sectional views of oil field components and a completed oilfield component adjacent a schematic block diagram of manufacturing equipment according to an embodiment of the present disclosure.
  • the oilfield equipment may comprise coiled tubing, jointed tubing, individual components such as jointed tubing, casing string, drill pipe segments, downhole tool components (such as logging tool components, resistivity tool components, well intervention tool components and the like), drill stems, surface equipment components, and the like, as will be appreciated by those skilled in the art.
  • a metallic coiled tube formed from steel, a steel alloy, or other suitable metal or such metallic tube is indicated generally at 102.
  • the tube 102 may be coated with any other metallic element or elements to improve adhesion to polymers and to improve corrosion resistance and that can be made to bond to polymer, discussed in more detail below.
  • the coiled tube 102 is passed through an infrared heat source 103 or any other suitable heating method including, but not limited to, an induction heater, a radiant heater, a conduction heater, and/or a convection heater or the like to modify its exterior surface and facilitate bonding, discussed in more detail below.
  • a tie layer of polymer 104, amended to bond to metal, is extruded from the first extruder 105 over and bonds to the coiled tubing 102.
  • a final layer of un-amended polymer 106 is extruded from a second extruder 107 over and bonds to the polymer tie layer 104.
  • the outer polymer 106 is selected to provide a low coefficient of friction.
  • the tie layer is selected to provide a low coefficient of friction.
  • the method 100 proceeds as follows: In Fig. 2a, there is shown the oilfield equipment in the form of a metallic coiled tube 102, which passes through an infrared heat or another suitable heat source 103 to modify the exterior surface thereof and facilitate bonding to an amended polymer. In Fig. 2b, the tie layer of polymer 104, which is amended to bond to the metal of the tubing 102 is extruded from an extruder
  • an outer layer of polymer 106 (such as a pure polymer amended with short fibers for added physical strength) is extruded from an extruder 107 over the tie layer 104 and bonds to the tie layer 104, forming a completed coiled tube 108.
  • the embodiments disclosed herein comprise an oilfield equipment such as a metallic coiled tube 102 with a low-friction, polymeric jacket 104, 106 bonded to an exterior surface thereof.
  • the jacket 104, 106 is bonded to the tubing 102 by heat- treating the outer surface of the metal 102 to alter its surface properties, after which the tie layer of polymer 104, amended to bond to metal, is applied.
  • the coiled tubing 102 is then completed by applying a low-friction polymeric outer jacket 106 that bonds to the tie layer 104 to form the completed oilfield equipment, coiled tube or tubing 108.
  • the outer jacket 106 may be amended with short fibers to increase its abrasion and/or cut through resistance, erosion resistance, corrosion resistance and other physical durability attributes.
  • the tie-layer 104 may also be amended with short fibers to avoid providing a second jacket layer 106 over the non-reinforced tie layer 104.
  • the resulting coiled tubing 108 has increased corrosion resistance and, because of its lower coefficient of friction, the coiled tubing 108 may be advanced more easily into deeper wells than conventional coiled tubing.
  • the oilfield equipment or metallic tubing 102 may be constructed of any metal that can be made to bond to polymer through the methods described above. Suitable metals may comprise, but are not limited to, copper-clad steel, aluminum-clad steel, anodized aluminum-clad steel, titanium-clad steel, carpenter alloy 20Mo6HS, GD31 Mo, austenitic stainless steel, high strength galvanized carbon steel, titanium clad copper, and/or any other suitable metal or alloys.
  • the oilfield equipment or metallic coiled tubing 102 made out of a standard steel tube may be coated with a suitable metallic element or elements to improve or facilitate the bonding to polymers (thermoplastic, elastomers, thermoplastic elastomers, and thermosets) and also to improve the corrosion resistance of the base metal (such as steel or the like) of the oilfield equipment or coiled tubing 102.
  • a suitable metallic element or elements to improve or facilitate the bonding to polymers (thermoplastic, elastomers, thermoplastic elastomers, and thermosets) and also to improve the corrosion resistance of the base metal (such as steel or the like) of the oilfield equipment or coiled tubing 102.
  • Any process to coat equipment such as a metallic tube 102 with another metal or metals may be used.
  • the process may comprise metal deposition by electro plasma technology (EPT), electrolytic coating, arc spraying, gas plasma coating or any other suitable coating/deposition method.
  • the metallic coating is specifically selected to improve the polymer adhe
  • the tie layer 104 is utilized to facilitate bonding to a metal or between materials that would not otherwise bond.
  • the tie layer 104 may comprise a modified polyolefin and may be amended with one of several adhesion promoters, such as, but not limited to, unsaturated anhydrides, (such as maleic-anhydride, or 5- norbornene-2, 3-dicarboxylic anhydride), carboxylic acid, acrylic acid, and/or silanes.
  • Adesion promoters such as, but not limited to, unsaturated anhydrides, (such as maleic-anhydride, or 5- norbornene-2, 3-dicarboxylic anhydride), carboxylic acid, acrylic acid, and/or silanes.
  • AdMER® from Mitsui Chemical
  • Fusabond® Bynel® from DuPont
  • Polybond® from Chemtura.
  • the tie layer 104 is utilized to facilitate bonding of a polymeric material to a metal or between materials that would not otherwise bond.
  • the tie layer 104 may comprise a modified TPX (4-methylpentene-1 based, crystalline polyolefin) and may be amended with one of several adhesion promoters, such as, but not limited to, unsaturated anhydrides, (such as maleic-anhydride, or 5-norbornene-2, 3- dicarboxylic anhydride), carboxylic acid, acrylic acid, and/or silanes.
  • unsaturated anhydrides such as maleic-anhydride, or 5-norbornene-2, 3- dicarboxylic anhydride
  • carboxylic acid acrylic acid
  • silanes silanes
  • the tie layer 104 may comprise TPXTM from Mitsui Chemical, a commercially available, amended TPX (4-methylpentene-1 based, crystalline polyolefin) with the adhesion promoters noted above or similar adhesion promoters.
  • the tie layer 104 is utilized to facilitate bonding of a polymeric material to a metal or between materials that would not otherwise bond.
  • the tie layer 104 may comprise modified fluoropolymers containing adhesion promoters and may be used where needed to facilitate bonding between materials that would not otherwise bond.
  • these adhesion promoters may comprise unsaturated anhydrides, (such as maleic-anhydride or 5-norbornene-2, 3-dicarboxylic anhydride), carboxylic acid, acrylic acid, and silanes).
  • fluoropolymers modified with adhesion promoters comprise PFA (perfluoroalkoxy polymer) from DuPont Fluoropolymers, (Modified PFA resin); Tefzel® from DuPont Fluoropolymers, (Modified ETFE resin which is designed to promote adhesion between polyamide and fluoropolymer); NeoflonTM-modified Fluoropolymer from Daikin America, Inc., (which is designed to promote adhesion between polyamide and fluoropolymer); FEP (Fluorinated ethylene propylene) from Daikin America, Inc, ETFE (Ethylene tetrafluoroethylene) from Daikin America, Inc., and/or EFEP (ethylene-fluorinated ethylene propylene) from Daikin America, Inc.
  • PFA perfluoroalkoxy polymer
  • Tefzel® from DuPont Fluoropolymers
  • NeoflonTM-modified Fluoropolymer from Daikin America
  • the jacket or outer polymer 106 may comprise a polyolefin that may be reinforced with carbon, glass, aramid or any other suitable natural or synthetic fiber, fibers in polymer matrix, any other reinforcing additives such as micron sized PTFE, Graphite, CeramerTM.
  • the polyolefin may comprise HDPE (High Density Polyethylene), LDPE (Low Density Polyethylene), PP (Ethylene tetrafluoroethylene), and/or PP copolymer, etc. , as will be appreciated by those skilled in the art.
  • the jacket or outer polymer 106 may comprise a polyamide that may be reinforced with carbon, glass, aramid or any other suitable natural or synthetic fiber, fibers in polymer matrix, and/or any other reinforcing additives such as micron sized PTFE, Graphite, CeramerTM.
  • Examples of commercially available Polyamides comprise nylon 6, nylon 66, nylon 6/66, nylon 6/12, nylon 6/10, nylon 1 1 , and/or, Nylon 12.
  • Trade names of commercially available versions of these polyamide materials comprise Orgalloy® , RILSAN® or RILSAN® from Arkema, BASF Ultramid®, Miramid® from BASF, and/or Zytel® from DuPont Engineering Polymers.
  • the jacket or outer polymer 106 may comprise unmodified and reinforced fluoropolymers that may be reinforced with carbon, glass, aramid or any other suitable natural or synthetic fiber, fibers in polymer matrix, and/or any other reinforcing additives such as micron sized PTFE, Graphite, CeramerTM.
  • Examples of commercially available fluoropolymers for the jacket 106 comprise ETFE (Ethylene tetrafluoroethylene) from Du Pont, ETFE (Ethylene tetrafluoroethylene) from Daikin America, Inc., EFEP (ethylene-fluorinated ethylene propylene) from Daikin America, Inc., PFA (perfluoroalkoxy polymer) from DyneonTM Fluoropolymer, PFA (perfluoroalkoxy polymer) from Solvay Solexis, Inc., PFA (perfluoroalkoxy polymer) from Daikin America, Inc. and/orPFA (perfluoroalkoxy polymer) from DuPont Fluoropolymer, Inc.
  • ETFE Ethylene tetrafluoroethylene
  • EFEP ethylene-fluorinated ethylene propylene
  • PFA perfluoroalkoxy polymer
  • DyneonTM Fluoropolymer PFA (perfluoroal
  • the jacket or outer polymer 106 may comprise a aromatic polymer like polyether ether ketone (PEEK), polyetherketone (PEK) or any other aromatic polymer or their mixtures with other polymers that may be reinforced with carbon, glass, aramid or any other suitable natural or synthetic fiber, fibers in polymer matrix, and/or any other reinforcing additives such as micron sized PTFE, Graphite, CeramerTM.
  • PEEK polyether ether ketone
  • PEK polyetherketone
  • the aromatic polymer like PEEK is commercially available from companies like Victrex Inc. or Solvay Inc.
  • the embodiments described herein provide a low-friction, polymer-bonded oilfield equipment.
  • the oilfield equipment comprises coiled tubing 108 wherein the polymer bonded on an exterior surface thereof allows the coiled tubing 108 to extend its reach into wellbores, such as that shown in Figure 1.
  • the embodiment or embodiments add a bonded, low-friction, polymeric jacket 104, 106 over coiled tubing 102 that may effectively reduce the coefficient of friction of the coiled tubing 102 such as by about half (to approximately 0.15), which may allow the coiled tubing 108 to be advanced further and more efficiently into deeper wellbores.
  • the embodiments described herein may reduce the friction coefficient between the oilfield equipment such as the coiled tubing 108 and the inside of the casing or wellbore to about 0.10 to about 0.20. With this approximately 50% reduction in friction between the coiled tubing and the wellbore or well casing, it is possible to advance the tubing 108 more easily and to greater depths.
  • the polymeric coating 104, 106 also aids in protecting the base metal of the tubing 102 against corrosion. Should the coating 104, 106 become damaged in the field, the tubing 108 may be returned to a manufacturing facility and the coating or jacket 104, 106 can be repaired.
  • Embodiments described herein may be utilized in coating and using other oilfield equipment (which may benefit from having a surface with a reduced friction coefficient) that may comprise, but is not limited to, jointed tubing, casing string, drill pipe segments, downhole tool components (such as logging tool components, resistivity tool components, well intervention tool components and the like), drill stems, surface equipment components, and the like.

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

Abstract

Selon un mode de réalisation, cette invention concerne un procédé de revêtement d'un composant d'exploitation pétrolière, comprenant les étapes consistant à : apporter un métal de base de composant d'exploitation pétrolière ; acheminer le métal de base de composant d'exploitation pétrolière à travers une source de chaleur ; et extruder une couche polymère au-dessus du métal de base de composant d'exploitation pétrolière, la couche polymère se fixant sur le métal de base de composant d'exploitation pétrolière pour former un composant d'exploitation pétrolière à coefficient de frottement réduit.
PCT/US2012/066825 2011-11-28 2012-11-28 Équipement pétrolier à coefficient de frottement réduit WO2013082134A1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US201161564202P 2011-11-28 2011-11-28
US61/564,202 2011-11-28

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WO2013082134A1 true WO2013082134A1 (fr) 2013-06-06

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WO2020172024A1 (fr) * 2019-02-22 2020-08-27 Forum Us, Inc. Procédé de conduite d'une opération à tubes spiralés
US10981196B2 (en) 2014-12-08 2021-04-20 General Electric Company Method of protecting an article having a complex shape
US11512539B2 (en) 2019-12-19 2022-11-29 Forum Us, Inc. Methods of conducting coiled tubing operations

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WO2008138957A2 (fr) * 2007-05-15 2008-11-20 Shell Internationale Research Maatschappij B.V. Système de forage d'un trou de forage
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US20090145610A1 (en) * 2006-01-12 2009-06-11 Joseph Varkey Methods of Using Enhanced Wellbore Electrical Cables
WO2008138957A2 (fr) * 2007-05-15 2008-11-20 Shell Internationale Research Maatschappij B.V. Système de forage d'un trou de forage
US20100044110A1 (en) * 2008-08-20 2010-02-25 Bangru Narasimha-Rao V Ultra-low friction coatings for drill stem assemblies
US20090236091A1 (en) * 2009-04-28 2009-09-24 Ahmed Hammami Fiber reinforced polymer oilfield tubulars and method of constructing same

Cited By (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US10981196B2 (en) 2014-12-08 2021-04-20 General Electric Company Method of protecting an article having a complex shape
WO2020172024A1 (fr) * 2019-02-22 2020-08-27 Forum Us, Inc. Procédé de conduite d'une opération à tubes spiralés
US12064787B2 (en) 2019-02-22 2024-08-20 Forum Us, Inc. Method of conducting a coiled tubing operation
US11512539B2 (en) 2019-12-19 2022-11-29 Forum Us, Inc. Methods of conducting coiled tubing operations

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