WO2016032469A1 - Isolation de conducteur électrique améliorée - Google Patents

Isolation de conducteur électrique améliorée Download PDF

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Publication number
WO2016032469A1
WO2016032469A1 PCT/US2014/053031 US2014053031W WO2016032469A1 WO 2016032469 A1 WO2016032469 A1 WO 2016032469A1 US 2014053031 W US2014053031 W US 2014053031W WO 2016032469 A1 WO2016032469 A1 WO 2016032469A1
Authority
WO
WIPO (PCT)
Prior art keywords
layer
fluoroplastic
dielectric layer
motor
dielectric
Prior art date
Application number
PCT/US2014/053031
Other languages
English (en)
Inventor
Jason Holzmueller
William Goertzen
Jose Angel CARIDAD URENA
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
Priority to PCT/US2014/053031 priority Critical patent/WO2016032469A1/fr
Publication of WO2016032469A1 publication Critical patent/WO2016032469A1/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
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
    • E21B43/121—Lifting well fluids
    • E21B43/128—Adaptation of pump systems with down-hole electric drives
    • 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
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
    • E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
    • E21B43/2406—Steam assisted gravity drainage [SAGD]
    • 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
    • E21B47/00—Survey of boreholes or wells
    • E21B47/01—Devices for supporting measuring instruments on drill bits, pipes, rods or wirelines; Protecting measuring instruments in boreholes against heat, shock, pressure or the like
    • E21B47/017—Protecting measuring instruments

Definitions

  • Equipment used in harsh environments may be exposed to high-temperature and/or high-pressure environments. Integrity and longevity of such equipment may be affected by its operation in such an environment. For example, operation within a high-temperature and/or high-pressure environment can result in the rapid degradation of conductor insulation, such as the conductor insulation of magnet wire used within an electric motor. The degradation of magnet wire insulation can cause premature failure of the conductor and the electric motor.
  • Electrical wire conductors may be insulated using various materials and techniques, to accommodate the desired application.
  • ESP electric submersible pumps
  • robust wire insulation may be created by wrapping the wire conductor being made into magnet wire within an insulating tape that is wound helically around the wire.
  • magnet wire and other motor components may be subject to premature failure due to hydrolysis, for example, which can accompany the use of the components in harsh environments.
  • An apparatus may include an electrical conductor, a dielectric layer surrounding the electrical conductor, and a fluoroplastic layer covering the dielectric layer.
  • a method may include surrounding an electrical conductor with a dielectric layer and covering the dielectric layer with a fluoroplastic layer.
  • An electric motor may include a stator, magnet wire, and an enclosure. At least a portion of the magnet wire may be wound around the stator to form an electro-magnet.
  • the magnet wire may include an electrical conductor, a polyimide tape with a fluoropolymer adhesive dielectric layer surrounding the electrical conductor, and a fluoroplastic layer covering the dielectric layer.
  • FIG. 1 includes diagrams of example environments wherein the techniques and devices described herein may be applied.
  • FIG. 2 includes schematic and block diagrams showing an example ESP system, according to an embodiment.
  • Fig. 3 includes drawings of an example ESP motor, and associated components wherein the techniques and devices described herein may be applied, according to an embodiment.
  • Fig. 4 is a block diagram showing an example technique for reducing degradation of motor components, as well as example motor components wherein the techniques and devices described herein may be applied, according to various examples.
  • Fig. 5 is a drawing of an example power cable wherein the techniques and devices described herein may be applied, according to an embodiment.
  • Fig. 6 is a drawing of an example electrical conductor wherein the techniques and devices described herein may be applied, according to an embodiment.
  • Fig. 7 includes block diagrams showing example extrusion techniques, as well example conductors with extruded layers thereon, according to various embodiments.
  • Fig. 8 shows various diagrams of example dielectric tape with one or more layers of adhesive, according to various embodiments.
  • FIG. 9 is a flow diagram showing an example technique for reducing degradation of an electrical conductor, according to an embodiment.
  • the enhanced electrical conductor insulation is resistant to hydrolysis which can accompany the use of the electrical conductor in a harsh environment, such as a high- temperature and/or a high-pressure environment.
  • the enhanced insulation may reduce a degradation rate of a dielectric layer of the electrical conductor, by covering the dielectric layer and inhibiting migration of moisture to the dielectric layer.
  • the devices and techniques may improve hydrolysis resistance for other components of an electrical motor, such as an electric submersible pump (ESP) motor, for instance.
  • ESP electric submersible pump
  • the example devices and techniques can be used to improve the quality of magnet wire.
  • Magnet wire can be manufactured in different wire gauges (AWG), for example, often with one or more layers of dielectric tape helically wrapped around a single metallic wire.
  • the metallic wire comprises copper, but may also comprise other conductive metals or alloys, etc.
  • the magnet wire may be used in electric motors that power ESP systems and other products.
  • the magnet wire can be wound around a stator (and/or a rotor) of an electric motor to form an electro-magnet.
  • the dielectric layer of the magnet wire may be covered by a fluoroplastic layer prior to winding the magnet wire in the electric motor.
  • the fluoroplastic layer may increase the resistance of the magnet wire insulation to degradation due to hydrolysis, for example.
  • the fluoropolymer barrier may be extruded or taped over the dielectric layer(s).
  • the dielectric tape may be wrapped around the metallic wire in multiple overlapping layers.
  • the dielectric tape may comprise a polyimide material and may be coated with a fluoropolymer adhesive.
  • the polyimide dielectric tape may be coated with the fluoropolymer adhesive on one or both surfaces of the tape (in various thicknesses).
  • An additional fluoroplastic layer over the dielectric layer(s) having a fluoropolymer adhesive may increase resistance to hydrolysis and prevent premature failure of the dielectric layer(s) of the magnet wire and associated electric motor.
  • a coating of one or more polyimide layers covered with a fluoroplastic layer can be applied to various other components of a motor to increase the resistance of the components to hydrolysis, for example, and increase the service life of the components.
  • one or more polyimide layers covered with a fluoroplastic layer can be applied to motor components, including: lead wire insulation, motor lead extension insulation, ESP cable insulation, splices between cables and motor leads, splices between lead wires and magnet wires, a stator housing insulation sleeve, phase barrier films, slot liner films, as well as other components.
  • FIG. 1 presents an example system 100 wherein the techniques and devices described herein may be applied.
  • FIG. 1 shows examples of geologic environments 120 and 140.
  • Geologic environment 120 may be a sedimentary basin that includes layers (e.g., stratification) that include a reservoir 121 and that may be, for example, intersected by a fault 123 (e.g., or faults).
  • Geologic environment 120 may be outfitted with any of a variety of sensors, detectors, actuators, etc.
  • equipment 122 may include communication circuitry to receive and to transmit information with respect to one or more networks 125. Such information may include information associated with downhole equipment 124, which may be equipment to acquire information, to assist with resource recovery, etc.
  • Other equipment 126 may be located remote from a well site and include sensing, detecting, emitting or other circuitry. Such equipment may include storage and communication circuitry to store and to communicate data, instructions, etc.
  • one or more satellites may be provided for purposes of communications, data acquisition, etc.
  • FIG. 1 shows a satellite in communication with the network 125 that may be configured for communications.
  • the satellite may additionally or alternatively include circuitry for imagery (e.g., spatial, spectral, temporal, radiometric, etc.).
  • FIG. 1 also shows the geologic environment 120 as optionally including equipment 127 and 128 associated with a well that includes a substantially horizontal portion that may intersect with one or more fractures 129.
  • a well in a shale formation may include natural fractures, artificial fractures (e.g., hydraulic fractures) or a combination of natural and artificial fractures.
  • a well may be drilled for a reservoir that is laterally extensive.
  • lateral variations in properties, stresses, etc. may exist where an assessment of such variations may assist with planning, operations, etc. to develop the reservoir (e.g., via fracturing, injecting, extracting, etc.).
  • the equipment 127 and/or 128 may include components, a system, systems, etc., for fracturing, seismic sensing, analysis of seismic data, assessment of one or more fractures, etc.
  • the geologic environment 140 shown in FIG. 1, includes two wells 141 and 143 (e.g., bores), which may, for example, be disposed at least partially in a layer such as a sand layer disposed between caprock and shale.
  • geologic environment 140 may be outfitted with equipment 145, which may be, for example, steam assisted gravity drainage (SAGD) equipment for injecting steam for enhancing extraction of a resource from a reservoir.
  • SAGD steam assisted gravity drainage
  • SAGD is a technique that involves subterranean delivery of steam to enhance flow of heavy oil, bitumen, etc.
  • SAGD can be applied for Enhanced Oil Recovery (EOR), which is also known as tertiary recovery, because it changes properties of oil in situ.
  • EOR Enhanced Oil Recovery
  • a SAGD operation in geologic environment 140 may use well 141 for steam- injection and well 143 for resource production.
  • equipment 145 may be a downhole steam generator and equipment 147 may be an electric submersible pump (e.g., an ESP).
  • one or more electrical cables may be connected to the equipment 145 and one or more electrical cables may be connected to the equipment 147.
  • a cable may provide power to a heater to generate steam, to a pump to pump water (e.g., for steam generation), to a pump to pump fuel (e.g., to burn to generate steam), etc.
  • a cable may provide power to power a motor, power a sensor (e.g., a gauge), etc.
  • steam injected via well 141 may rise in a subterranean portion of the geologic environment and transfer heat to a desirable resource such as heavy oil.
  • a desirable resource such as heavy oil.
  • equipment 147 may then assist with lifting the resource in the well 143 to, for example, a surface facility (e.g., via a wellhead, etc.).
  • a downhole steam generator As an example, it may be fed by three separate streams of natural gas, air and water (e.g., via conduits) where a gas-air mixture is combined first to create a flame and then water is injected downstream to create steam.
  • the water can also serve to cool a burner wall or walls (e.g., by flowing in a passageway or passageways within a wall).
  • a SAGD operation may result in condensed steam accompanying a resource (e.g., heavy oil) to a well.
  • a production well includes artificial lift equipment such as an ESP, operation of such equipment may be impacted by the presence of condensed steam (e.g., water).
  • condensed steam may place demands on separation processing where it is desirable to separate one or more components from a hydrocarbon and water mixture.
  • Each of Geologic environments 120 and 140 of FIG. 1 may include harsh environments therein.
  • a harsh environment may be classified as being a high- pressure and high-temperature environment.
  • a so-called HPHT environment may include pressures up to about 138 MPa (e.g., about 20,000 psi) and temperatures up to about 205 degrees C (e.g., about 400 degrees F)
  • a so-called ultra-HPHT environment may include pressures up to about 241 MPa (e.g., about 35,000 psi) and temperatures up to about 260 degrees C (e.g., about 500 degrees F)
  • a so-called HPHT -he environment may include pressures greater than about 241 MPa (e.g., about 35,000 psi) and temperatures greater than about 260 degrees C (e.g., about 500 degrees F).
  • an environment may be classified to be in one of the aforementioned classes based on pressure or temperature alone.
  • an environment may have its pressure and/or temperature elevated, for example, through use of equipment, techniques, etc.
  • a SAGD operation may elevate temperature of an environment (e.g., by 100 degrees C or more).
  • an environment may be classified based at least in part on its chemical composition.
  • an environment includes hydrogen sulfide (H 2 S), carbon dioxide (CO 2 ), etc.
  • the environment may be corrosive to certain materials.
  • an environment may be classified based at least in part on particulate matter that may be in a fluid (e.g., suspended, entrained, etc.).
  • particulate matter in an environment may be abrasive or otherwise damaging to equipment.
  • matter may be soluble or insoluble in an environment and, for example, soluble in one environment and substantially insoluble in another.
  • Conditions in a harsh environment may be transient and/or persistent.
  • longevity of the equipment can depend on characteristics of the environment and, for example, duration of use of the equipment as well as function of the equipment.
  • a high-voltage power cable may itself pose challenges regardless of the environment into which it is placed, and additional challenges may be present in a harsh environment.
  • uncertainty may arise in one or more factors that could impact integrity or expected lifetime of the equipment.
  • a period of time may be on the order of decades
  • equipment that is intended to last for such a period of time should be constructed with materials that can endure the environmental conditions imposed thereon, whether imposed by an environment or environments and/or by one or more functions of the equipment itself.
  • FIG. 2 shows an example of an ESP system 200 that includes an ESP 210 as an example of equipment that may be placed in a harsh environment.
  • an ESP 210 may be expected to function in an environment over an extended period of time (e.g., on the order of years).
  • commercially available ESPs such as the REDA ESPs marketed by Schlumberger Limited, Houston, Tex.
  • the ESP system 200 includes a network 201, a well 203 disposed in a geologic environment, a power supply 205, the ESP 210, a controller 230, a motor controller 250 and a VSD unit 270.
  • the power supply 205 may receive power from a power grid, an onsite generator (e.g., natural gas driven turbine), or other source.
  • the power supply 205 may supply a voltage, for example, of about 4.16 kV or more.
  • the well 203 includes a wellhead that can include a choke (e.g., a choke valve).
  • a choke e.g., a choke valve
  • the well 203 can include a choke valve to control various operations such as to reduce pressure of a fluid from high pressure in a closed wellbore to atmospheric pressure.
  • Adjustable choke valves can include valves constructed to resist wear due to high-velocity, solids-laden fluid flowing by restricting or sealing elements.
  • a wellhead may include one or more sensors such as a temperature sensor, a pressure sensor, a solids sensor, etc.
  • the ESP 210 it is shown as including cables 211 (e.g., or a cable), a pump 212, gas handling features 213, a pump intake 214, a motor 215, one or more sensors 216 (e.g., temperature, pressure, current leakage, vibration, etc.) and optionally a protector 217.
  • the well 203 may include one or more well sensors 220, for example, such as the commercially available OPTICLINE sensors or WELLWATCHER BRIGHTBLUE sensors marketed by SCHLUMBERGER LIMITED (Houston, Tex.). Such sensors are fiber-optic based and can provide for real-time sensing of temperature, for example, in SAGD or other operations. As shown in the example of FIG.
  • a well can include a relatively horizontal portion. Such a portion may collect heated heavy oil responsive to steam injection. Measurements of temperature along the length of the well can provide for feedback, for example, to understand conditions downhole of an ESP 210.
  • Well sensors may extend thousands of feet into a well (e.g., 4,000 feet or more) and beyond a position of an ESP 210.
  • the controller 230 can include one or more interfaces, for example, for receipt, transmission, or receipt and transmission, of information with the motor controller 250, a VSD unit 270, the power supply 205 (e.g., a gas fueled turbine generator, a power company, etc.), the network 201, equipment in the well 203, equipment in another well, etc.
  • the power supply 205 e.g., a gas fueled turbine generator, a power company, etc.
  • the controller 230 can include or provide access to one or more modules or frameworks. Further, the controller 230 may include features of an ESP motor controller and optionally supplant the ESP motor controller 250. For example, the controller 230 may include the UNICONN motor controller 282 marketed by SCHLUMBERGER LIMITED (Houston, Tex.). In the example of FIG.
  • the controller 230 may access one or more of the PIPESIM framework 284, the ECLIPSE framework 286 marketed by SCHLUMBERGER LIMITED (Houston, Tex.) and the PETREL framework 288 marketed by SCHLUMBERGER LIMITED (Houston, Tex.) (e.g., and optionally the OCEAN framework marketed by SCHLUMBERGER LIMITED (Houston, Tex.)).
  • the motor controller 250 may be a commercially available motor controller such as the UNICONN motor controller.
  • the UNICONN motor controller can connect to a SCADA system, the ESPWATCHER surveillance system, etc.
  • the UNICONN motor controller can perform some control and data acquisition tasks for ESPs, surface pumps or other monitored wells.
  • the UNICONN motor controller can interface with the PHOENIX monitoring system, for example, to access pressure, temperature and vibration data and various protection parameters as well as to provide direct current power to downhole sensors.
  • the UNICONN motor controller can interface with fixed speed drive (FSD) controllers or a VSD unit, for example, such as the VSD unit 270.
  • FSD fixed speed drive
  • the UNICONN motor controller can monitor ESP system three-phase currents, three-phase surface voltage, supply voltage and frequency, ESP spinning frequency and leg ground, power factor and motor load.
  • the U ICO motor controller can monitor VSD output current, ESP running current, VSD output voltage, supply voltage, VSD input and VSD output power, VSD output frequency, drive loading, motor load, three-phase ESP running current, three-phase VSD input or output voltage, ESP spinning frequency, and leg-ground.
  • the UNICONN motor controller can include control functionality for VSD units such as target speed, minimum and maximum speed and base speed (voltage divided by frequency); three jump frequencies and bandwidths; volts per hertz pattern and start-up boost; ability to start an ESP while the motor is spinning; acceleration and deceleration rates, including start to minimum speed and minimum to target speed to maintain constant pressure/load (e.g., from about 0.01 Hz/10,000 s to about 1 Hz/s); stop mode with PWM carrier frequency; base speed voltage selection; rocking start frequency, cycle and pattern control; stall protection with automatic speed reduction; changing motor rotation direction without stopping; speed force; speed follower mode; frequency control to maintain constant speed, pressure or load; current unbalance; voltage unbalance; overvoltage and undervoltage; ESP backspin; and leg-ground.
  • VSD units such as target speed, minimum and maximum speed and base speed (voltage divided by frequency); three jump frequencies and bandwidths; volts per hertz pattern and start-up boost; ability to start an ESP while the
  • the ESP motor controller 250 includes various modules to handle, for example, backspin of an ESP, sanding of an ESP, flux of an ESP and gas lock of an ESP. As mentioned, the motor controller 250 may include any of a variety of features.
  • the VSD unit 270 may be a low voltage drive (LVD) unit, a medium voltage drive (MVD) unit or other type of unit (e.g., a high voltage drive, which may provide a voltage in excess of about 4.16 kV).
  • a VSD unit can include a step-up transformer, control circuitry and a step-up transformer while, for a MVD, a VSD unit can include an integrated transformer and control circuitry.
  • the VSD unit 270 may receive power with a voltage of about 4.16 kV and control a motor as a load with a voltage from about 0 V to about 4.16 kV.
  • the VSD unit 270 may include commercially available control circuitry such as the SPEEDSTAR MVD control circuitry marketed by SCHLUMBERGER LIMITED (Houston, Tex.).
  • the SPEEDSTAR MVD control circuitry is suitable for indoor or outdoor use and comes standard with a visible fused disconnect switch, precharge circuitry, and sine wave output filter (e.g., integral sine wave filter, ISWF) tailored for control and protection of high-horsepower ESPs.
  • ISWF integral sine wave filter
  • the SPEEDSTAR MVD control circuitry can include a plug-and- play sine wave output filter, a multilevel PWM inverter output, a 0.95 power factor, programmable load reduction (e.g., soft-stall function), speed control circuitry to maintain constant load or pressure, rocking start (e.g., for stuck pumps resulting from scale, sand, etc.), a utility power receptacle, an acquisition system for the PHOENIX monitoring system, a site communication box to support surveillance and control service, a speed control potentiometer.
  • the SPEEDSTAR MVD control circuitry can optionally interface with the UNICONN motor controller, which may provide some of the foregoing functionality.
  • the VSD unit 270 is shown along with a plot of a sine wave (e.g., achieved via a sine wave filter that includes a capacitor and a reactor), responsiveness to vibration, responsiveness to temperature and as being managed to reduce mean time between failures (MTBFs).
  • the VSD unit 270 may be rated with an ESP to provide for about 40,000 hours (5 years) of operation at a temperature of about 50 C with about a 100% load.
  • the VSD unit 270 may include surge and lightning protection (e.g., one protection circuit per phase). As to leg-ground monitoring or water intrusion monitoring, such types of monitoring can indicate whether corrosion is or has occurred. Further monitoring of power quality from a supply, to a motor, at a motor, may occur by one or more circuits or features of a controller.
  • Overall system efficiency can affect power supply from the utility or generator.
  • monitoring of ITHD, VTHD, PF and overall efficiency may occur (e.g., surface measurements).
  • Such surface measurements may be analyzed in separately or optionally in conjunction with a pump curve.
  • VSD unit related surface readings e.g., at an input to a VSD unit
  • VSD unit related surface readings can optionally be input to an economics model. For example, the higher the PF and therefore efficiency (e.g., by running an ESP at a higher frequency and at close to about a 100% load), the less harmonics current (lower ITHD) sensed by the power supply. In such an example, well operations can experience less loses and thereby lower energy costs for the same load.
  • an ESP 210 may include a hydraulic diaphragm electric submersible pump (HDESP), which is a positive-displacement, double-acting diaphragm pump with a downhole motor.
  • HDESPs find use in low-liquid-rate coalbed methane and other oil and gas shallow wells that use artificial lift to remove water from the wellbore.
  • a HDESP can be set above or below the perforations and run in wells that are, for example, less than about 2,500 ft deep and that produce less than about 200 barrels per day.
  • HDESPs may handle a wide variety of fluids and, for example, up to about 2% sand, coal, fines and H 2 S/CO 2 .
  • an ESP 210 may include a REDA HOTLINE high-temperature ESP motor.
  • a motor 215 may be suitable for implementation in a thermal recovery heavy oil production system, such as, for example, SAGD system or other steam-flooding system.
  • an ESP motor 215 can include a three-phase squirrel cage with two-pole induction.
  • an ESP motor 215 may include steel stator laminations that can help focus magnetic forces on rotors, for example, to help reduce energy loss.
  • stator windings can include magnet wire comprising copper conductors and insulation.
  • a motor 215 may include a pothead.
  • a pothead may, for example, provide for a tape-in connection with metal-to-metal seals (e.g., to provide a barrier against fluid entry).
  • a motor 215 may include one or more types of potheads or connection mechanisms.
  • a pothead unit may be provided as a separate unit configured for connection, directly or indirectly, to a motor housing.
  • a motor 215 may include dielectric oil (e.g., or dielectric oils), for example, that may help lubricate one or more bearings that support a shaft rotatable by the motor 215.
  • a motor 215 may be configured to include an oil reservoir, for example, in a base portion of a motor housing, which may allow oil to expand and contract with wide thermal cycles.
  • a motor 215 may include an oil filter to filter debris.
  • a motor housing can house stacked laminations with electrical windings extending through slots in the stacked laminations.
  • the electrical windings may be formed from magnet wire that includes an electrical conductor and at least one polymeric dielectric insulator surrounding the electrical conductor.
  • a polymeric insulation layer may include a single layer or multiple layers of a dielectric tape that may be helically wrapped around the electrical conductor and that may be bonded to the electrical conductor (e.g., and to itself) through use of an adhesive.
  • One example implementation may comprise an insulation system for components of ESP motors with exceptional resistance to harsh environments and/or greatly improved long term reliability.
  • a system may be include a primary dielectric layer (such as a polyimide film, for example) which may be coated with a fluoropolymer adhesive that is wrapped and bonded to a motor component (such as magnet wire, for example).
  • a fluoropolymer barrier is extruded or taped over the top of the dielectric layer. The fluoropolymer barrier protects the dielectric layer from well fluids or moisture and extends the run life of the system, including improving hydrolysis resistance of insulating layer(s).
  • FIG. 3 shows various examples of motor equipment.
  • a pothead unit 301 includes opposing ends 302 and 304 and a through bore, for example, defined by a bore wall 305. As shown, the ends 302 and 304 may include flanges configured for connection to other units (e.g., a protector unit at the end 302 and a motor unit at the end 304).
  • the pothead unit 301 includes cable passages 307-1, 307-2 and 307-3 (e.g., cable connector sockets) configured for receipt of cable connectors 316-1, 316-2 and 316-3 of respective cables 314-1, 314-2 and 314-3.
  • the cables 314-1, 314-2 and 314-3 and/or the cable connectors 316-1, 316-2 and 316-3 may include one or more polymers.
  • a cable may include polymer insulation while a cable connector may include polymer insulation, a polymer component (e.g., a bushing), etc.
  • the cables 314-1, 314-2 and 314-3 may be coupled to a single larger cable.
  • the single larger cable may extend to a connector end for connection to a power source or, for example, equipment intermediate the cable and a power source (e.g., an electrical filter unit, etc.).
  • a power source may be a VSD unit that provides three-phase power for operation of a motor, such as motor 215.
  • FIG. 3 also shows a pothead unit 320 that includes a socket 321.
  • a cable 322 may include a plug 324 that can couple to the socket 321 of the pothead unit 320.
  • the cable 322 may include one or more conductors 326.
  • a cable 322 may include at least one fiber optic cable or one or more other types of cables.
  • FIG. 3 shows a perspective cut-away view of an example of a motor assembly 340 (which may include a motor 215, for example) that includes a power cable 344 (e.g., MLEs, etc.) to supply energy, a shaft 350, a housing 360 that may be made of multiple components (e.g., multiple units joined to form the housing 360), stacked laminations 380, windings 370 of wire (e.g., magnet wire) and a rotor 390 coupled to the shaft 350 (e.g., rotatably driven by energizing the windings 370).
  • a power cable 344 e.g., MLEs, etc.
  • the shaft 350 may be fitted with a coupling 352 to couple the shaft 350 to another shaft.
  • a coupling may include, for example, splines that engage splines of one or more shafts.
  • the shaft 350 may be supported by bearings 354-1, 354-2, 354-3, etc. disposed in the housing 360.
  • the housing 360 includes opposing axial ends 362 and 364 with a substantially cylindrical outer surface 365 extending therebetween.
  • the outer surface 365 can include one or more sealable openings for passage of oil (e.g., dielectric oil), for example, to lubricate the bearings and to protect various components of the motor assembly 340.
  • the motor assembly 340 may include one or more sealable cavities.
  • a passage 366 allows for passage of one or more conductors of the cable 344 (e.g., or cables) to a motor cavity 367 of the motor assembly 340 where the motor cavity 367 may be a sealable cavity.
  • the motor cavity 367 houses the windings 370 and the laminations 380.
  • an individual winding may include a plurality of conductors (e.g., magnet wires).
  • a cross-section 372 of an individual winding may reveal a plurality of conductors that are disposed in a matrix (e.g., of material or materials) or otherwise bound together (e.g., by a material or materials).
  • the motor housing 360 includes an oil reservoir 368, for example, that may include one or more passages (e.g., a sealable external passage and a passage to the motor cavity 367) for passage of oil.
  • equipment may be placed in a harsh environment, such as a geologic environment, for example, where such equipment may be subject to conditions associated with a function or functions of the equipment and/or be subject to conditions associated with the harsh environment. Equipment may experience conditions that are persistent (e.g., relatively constant), transient or a combination of both.
  • equipment components may include at least one polymer composition.
  • the motor assembly 340 may include one or more materials that include, or that are, such a polymer composition. Such material may be for purposes of binding, for purposes of insulating, for purposes of reducing moisture content, for purposes of increasing temperature rating, etc.
  • Such material may be for multiple purposes, for example, to bind and insulate as well as to reduce moisture content.
  • such material may be included in a cavity, which may be a sealable cavity that may include one or more materials susceptible to hydrolysis. The inclusion of the material may reduce moisture load, for example, where it is chemically and/or structurally resistant to entraining or otherwise carrying moisture.
  • FIG. 4 illustrates a technique 400 for reducing degradation of motor 340 components, as well as example motor 340 components wherein the techniques and devices described herein may be applied, according to various examples.
  • a motor 340 component is surrounded with a dielectric layer.
  • the dielectric layer surrounds or covers a portion of the motor 340 component desired to be protected.
  • the dielectric layer is covered with a fluoroplastic layer.
  • the dielectric layer provides some electrical insulation or physical protection for the motor 340 component.
  • the fluoroplastic layer provides additional protection, including in the form of hydrolysis reduction, to the motor 340 component.
  • the motor 340 components protected in this manner may include one or more of the motor 340 components shown in FIGS. 2 and 3. Some of these motor 340 components are described below.
  • the dielectric layer comprises a polyimide material, such as a polyimide tape.
  • the polyimide tape includes a fluoropolymer adhesive on one or both surfaces of the tape.
  • the fluoroplastic layer covers the polyimide tape (with or without the fluoropolymer adhesive) applied to the motor 340 component.
  • the table 410 shows potential fluoroplastics which may be used in this manner, including potential temperature use ratings for the fluoroplastics.
  • the low temperature copolymers PVDF or PVDF/HFP, ETFE, FEP
  • PVDF low temperature copolymers
  • ETFE ETFE
  • FEP high temperature resins
  • PFA ECA
  • PTFE PTFE
  • one technique for application is extrusion, but it is also possible to apply the material as a tape that is wrapped and subsequently heat fused.
  • These fluoroplastic barriers can be extruded over polyimide tapes with or without double sided adhesives.
  • a polyimide tape with a double sided adhesive can be used to improve bonding between the layers.
  • a double sided blended fluoropolymer adhesive can be used in conjunction with an Epitaxial Co-Crystallized Alloy fluoroplastic (example: DUPONT ECCTREME ECA 3000), for example.
  • the taped adhesive can be heated to near melt point prior to polymer overcoat extrusion by means of induction heat, radiant heat, or other methods.
  • a modified fluoroplastic with maleic anhydride may be used to enhance bonding between the fluoropolymer and the polyimide. This solution can be very cost effective for lower temperature applications (below 250C).
  • a polyimide coated magnet wire (or other motor 340 component) is coated by a high temperature fluoroplastic prior to being installed in the motor.
  • Perfluoroplastics PFP are inherently highly resistant to high temperatures, water, motor oil, and all typical well fluids and gases. They also have excellent dielectric properties which are retained up to the melt point (250C or more depending on material).
  • the polyimide layer is retained underneath as the primary dielectric layer due to its very high breakdown strength.
  • the fluoroplastic layer serves as a secondary dielectric and fluid barrier.
  • heat aging can cause a composition that includes PFP (e.g., a perfluoropolymer mixture) to undergo epitaxial co-crystallization (ECC).
  • ECC epitaxial co-crystallization
  • a composition that includes perfluoroalkoxy (PFA) and polytetrafluoroethylene (PTFE), together as a PFP may undergo ECC responsive to heat aging to form an ECC PFP.
  • ECC may be described as a phenomenon of separate crystals of different molecules (e.g., copolymers, etc.) becoming co-crystals such that a melting temperature is a single melting temperature that is greater than a melting temperature of, for example, one of the molecules alone.
  • an increase in melting temperature may indicate that crystals of one polymer (e.g., PFA) and those of a melt flowable other polymer (e.g., PTFE at low molecular weight, such as, for example, provided by a PTFE micropowder) have transformed to a different crystalline state (e.g., a co-crystalline state).
  • co-crystallization may be a crystallographic transformation from a blend of separate crystals, for example, primarily of PFA crystals and PTFE crystals, to co-crystals of thereof.
  • a mixture may include a melt-fabricable tetrafluoroethylene/perfluoro(alkyl vinyl ether) copolymer (e.g., where the perfluoroalkyl contains 1 to 5 carbon atoms) and melt flowable polytetrafluoroethylene (PTFE).
  • a composition may be or include a commercially available DUPONT ECCTREME ECA 3000 fluoroplastic resin.
  • such a resin may be a PFP that may be heat aged to become an ECC PFP.
  • a PFA may be a copolymer of tetrafluoroethylene (TFE) and perfluoro(alkyl vinyl ether) (PAVE), for example, where a linear or branched perfluoroalkyl group contains 1 to 5 carbon atoms.
  • a PAVE monomer may be one or more of those in which a perfluoroalkyl group contains 1, 2, 3 or 4 carbon atoms (e.g., PMVE, PEVE, PPVE and PBVE, respectively).
  • a copolymer may be made, for example, using several PAVE monomers, such as the TFE/perfluoro(methyl vinyl ether)/perfluoro(propyl vinyl ether) copolymer (e.g., "MFA" as PFA).
  • identity and amount of PAVE present in PFA may be such that the melting temperature of the PFA is greater than about 300 degrees C.
  • PFA may be referred to as a fluoroplastic rather than a fluoroelastomer, for example, where, as a fluoroplastic, PFA is semicrystalline (e.g., partially crystalline).
  • PFA may be sufficiently flowable in a molten state to allow for melt processing (e.g., extrusion, etc.), for example, to produce a component having a desirable strength (e.g., characterized by PFA by itself exhibiting an MIT Flex Life of at least 1000 cycles, preferably at least 2000 cycles using 8 mil (0.21 mm) thick film).
  • a melt flow rate (MFR) of PFA e.g., prior to heat treatment
  • PFA may be fluorine-treated, for example, for a stable-CF 3 end group as a predominant end group (e.g., less than about 50).
  • PFA may be provided without fluorine treatment, for example, whereby its end groups may be unstable end groups arising from aqueous dispersion polymerization to form PFA.
  • PTFE polytetrafluoroethylene
  • PTFE polytetrafluoroethylene
  • it may be characterized to be non-melt flowable, for example, where it has a high molecular weight.
  • PTFE may be provided with a low molecular weight (LMW) and, as such, be characterized to be melt flowable.
  • LMW low molecular weight
  • Such PTFE may be referred to as, for example, LMW PTFE.
  • a LMW PTFE may be melt flowable yet, for example, not melt fabricable (e.g., by virtue of brittleness).
  • a LMW PTFE extruded fiber may break upon flexing.
  • LMW PTFE may be characterized as being of high crystallinity (e.g., optionally exhibiting a heat of crystallization of at least 50 J/g).
  • LMW PTFE may be characterized as being of high crystallinity with, for example, melt flowability (e.g., flowable in a molten state).
  • LMW PTFE may be, for example, obtained by direct polymerization under conditions that prevent very long polymer chains from forming, by irradiation degradation of PTFE, etc.
  • LMW PTFE may be solid, for example, with a melting temperature of at least about 300 degrees C. (e.g., or higher).
  • PTFE e.g., LMW PTFE
  • PTFE micropowder e.g., consider ZONYL micropowder marketed by the DUPONT COMPANY
  • DUPONT ZONYL fluoroadditives may be characterized as being finely divided white powders of polytetrafluoroethylene (PTFE) resin that, in comparison to TEFLON PTFE molding and extrusion powders, may be characterized as being, for example, of lower molecular weight of smaller particle size(s) (e.g., about 2 ⁇ to about 20 ⁇ ).
  • proportions of PFA and PTFE to make a component may include an amount of PTFE, for example, to provide for an increased temperature resistance (e.g., compared to a component fabricated from mainly PFA).
  • a composition may include at least 12 percent by weight PTFE (e.g., LMW PTFE, PTFE micropowder, etc.) or more (e.g., consider 50 percent by weight PTFE).
  • a composition may include a percent by weight of PTFE and a remaining amount a percent by weight of PFA (e.g., PTFE % plus PFA % is approximately 100%).
  • a single type of PTFE and a single type of PFA may be used to form a composition from which a component may be made, coated, etc.
  • one or more additional constituents may be included in a composition (e.g., dielectric material, pigment, conductive material, non-conductive material, fiber, inorganic, etc.).
  • a PTFE and PFA formed composition may exhibit a dielectric constant of no greater than about 2.4 (e.g., at 20 degree C), for example, enabling the composition and the component made therefrom to be electrically insulating (e.g., electrically non-conductive).
  • a PFP may become an ECC PFP that demonstrates one or more enhanced properties (e.g., modulus retention, improved fatigue resistance, better permeation resistance and higher melting point) when subjected to a post-heat treatment.
  • ECC PFP ECC PFP that demonstrates one or more enhanced properties (e.g., modulus retention, improved fatigue resistance, better permeation resistance and higher melting point) when subjected to a post-heat treatment.
  • a provided PFP (e.g., as a resin) may be processed into shapes, tubes, wire coatings, etc. and, once processed and exposed to temperatures in excess of about 290 degrees C, the PFP may be transformed via epitaxial co-crystallization (ECC), for example, to alter one or more of its material properties.
  • ECC epitaxial co-crystallization
  • a melt-point shift may be experienced and indicative of a co-crystallization effect.
  • the plot of FIG. 4 demonstrates that upon heat aging and thermal transformation, a PFP resin's melting point increases by about 5 degrees C. (e.g., PFP with a melt point of about 320 ⁇ 3 degrees C. as measured by differential scanning calorimetry may be increased by heat-aging at about 315 degrees C. for about 48 hours such that the PFP undergoes a thermal and structural transformation and demonstrates a melt point of about 325 ⁇ 3 degrees C).
  • ECC may occur by heat aging at a temperature at which a composition retains its shape and does not flow, indicating that the composition is in the solid state.
  • shape retention may mean that the shape of a melt-fabricated article is discernible after heat aging (e.g., the article substantially retains its shape during and after heat aging).
  • a PFP processed to an ECC PFP may demonstrate a reduction in permeation, for example, where such processing includes exposing the PFP to temperatures of about 300 degrees C.
  • the ECC PFP may exhibit reduced permeation to CH4, CO2 and O2.
  • Higher permeation resistance for example, resulting from changes in polymer morphology during heat treatment, may provide an ECC PFP approximating a 50% reduction in permeation over non-ECC PFPs.
  • a PFP may exhibit relatively low permeation and an ECC PFP may exhibit a lower permeation.
  • PFP and/or ECC PFP may carry less moisture than another marketed high-temperature material, for example, due to the PFP and/or the ECC PFP having lower permeation compared to that other marketed high-temperature material (e.g., lower permeation as to water).
  • an ECC PFP may exhibit reduced creep (e.g., increased modulus retention), increased chemical resistance, increased flex life/stress-crack resistance, and a lower dissipation factor (e.g., when compared to a perfluoroalkoxy polymer alone (PFA)).
  • creep e.g., increased modulus retention
  • chemical resistance e.g., increased chemical resistance
  • increased flex life/stress-crack resistance e.g., when compared to a perfluoroalkoxy polymer alone (PFA)
  • a PFP may be included in one or more motor 340 components, covering a dielectric layer, such as a polyimide layer.
  • a dielectric layer such as a polyimide layer.
  • an ECC PFP may be included in one or more motor 340 components (e.g., as a PFP component that has been heat aged prior to installation and/or use of the component in an assembly), covering a dielectric layer.
  • FIG. 4 shows various motor 340 components for which an application of a dielectric layer covered by a fluoroplastic layer may be applied, as described herein.
  • other electrical components not directly related to motors, may also benefit from like applications of a dielectric layer covered by a fluoroplastic layer.
  • components and/or uses may include those related to motor winding insulation 420 (including lead wire insulation, motor lead extension insulation, and the like), cable insulation or jacketing 422 (such as ESP cable insulation, for example), splices and/or repairs 424 (including splices between cables and motor leads, splices between lead wires and magnet wires, etc.), a stator housing insulation sleeve 426, motor slot liner films 428, phase barrier films 430, extruded fluid barriers 432, protective tubing 434, lead and/or brush wire 436, structural components 438 (e.g., in electrical connectors, etc.), signal wire insulation 440, high temperature adhesive 442, and so forth, (e.g., cable manufacturing process aids, etc.).
  • motor winding insulation 420 including lead wire insulation, motor lead extension insulation, and the like
  • cable insulation or jacketing 422 such as ESP cable insulation, for example
  • splices and/or repairs 424 including splices between cables and motor leads,
  • the dielectric layer has dielectric properties which make it suitable for electrical applications, for example, including motor 340 magnet wire.
  • the coefficient of friction of the dielectric layer may enhance motor winding. For example, where a winding is of considerable length (e.g., for a motor of about 10 feet or more), a low coefficient of friction may enhance a winding process (e.g., ensure smoother fitting and tightness of coated wire).
  • the dielectric layer comprising a polyimide tape including a fluoropolymer adhesive
  • the dielectric layer begins protecting the motor 340 windings from hydrolysis, and may make the windings less susceptible to moisture.
  • the addition of the fluoroplastic layer further protects the windings from hydrolysis resulting from moisture.
  • An electrical conductor (such as a magnet wire, for example) including "the layers" 620 (i.e., one or more dielectric layers (with or without fluoropolymer adhesive) plus at least one fluoroplastic layer) is further discussed with reference to FIG. 6.
  • a winding having, at least in part, the dielectric layer comprising a polyimide tape including a fluoropolymer adhesive and a fluoroplastic layer may introduce less moisture (e.g., water) into a motor cavity when compared to a more hygroscopic material or other material that may retain moisture (e.g., due to permeation or another phenomenon).
  • a motor may include one or more materials susceptible to hydrolysis. In such an example, a motor assembly process may aim to reduce moisture to a minimum.
  • the layers” 620 may exhibit a high dielectric strength, low loss and fluid resistance that make it suitable for use in or as power cable insulation 422.
  • the layers” 620 may serve as a secondary insulation layer and include lower profile materials such as polyimide tapes.
  • a power cable that includes insulation 422 including "the layers” 620 may have enhanced voltage stress control and a fluid barrier (e.g., to water, hydrocarbons, etc.).
  • splices and/or repairs 424 processability of a PCP material can allow for in situ injection molded splices 424 between cables or repairs of existing fluoropolymer cables or cables that include "the layers" 620.
  • a PFP covering a dielectric layer may be provided to form a splice or to repair a defect in a manufactured cable or component, which may be in the field, in a factory or other location.
  • a PFP may be extruded or injected at a temperature of about 650 degrees F. to about 700 degrees F. for purposes of melt and flow (e.g., about 343 degrees C. to about 371 degrees C).
  • cable ends may be stripped to their conductive cores, the cores cold welded and then "the layers" 620 introduced as a coating (e.g., via an injection mold process) about the cold welded cores.
  • the layers introduced as a coating (e.g., via an injection mold process) about the cold welded cores.
  • a continuous layer may be formed about the cold welded cores, which may physically adjoin adjacent layers.
  • a labyrinth joint that includes a metal spring that energizes seals may be coated with or filled with "the layers" 620.
  • "the layers" 620 may be injected into a labyrinth space, or the like.
  • a stator housing insulation sleeve 426 may include "the layers" 620.
  • the stator housing insulation sleeve 426 includes a layer of dielectric material (such as a polyimide layer, for instance) and includes a layer of fluoropolymer covering the dielectric layer, which inhibits hydrolysis of the stator housing and related components.
  • a motor slot liner film 422 and/or a phase barrier film 430 may include "the layers" 620.
  • a motor slot liner film 422 and/or a phase barrier film 430 may be used to separate motor phases (e.g., wires, sections, etc. associated with individual phases of a multiphase motor).
  • either or both films 422 and 430 with "the layers,” results in reduced moisture retention and/or moisture content, and may be used in a motor cavity to be sealed.
  • a motor slot liner film 422 and/or a phase barrier film 430 with "the layers" 620 applied may be introduced into a motor cavity prior to sealing of the cavity to reduce overall moisture content in the motor cavity (e.g., compared to a film that would introduce more moisture).
  • one or both of "the layers" 620 may be extruded over (e.g., directly or indirectly) a material or component that is to be protected from hydrolysis.
  • the extruded "layers” may be heat aged to form an ECC, or the like, that can act as a barrier to protect the material or component.
  • ECC electrostatic chemical vapor deposition
  • such an approach may be applied to form a protective layer for power cable, wireline cables or as a moisture protection layer for magnet wire.
  • the extruded material may bond as a cohesive layer onto another layer (e.g., as an extruded, continuous tube).
  • a coating of "the layers" 620 may help protect an underlying material or component from chemical attack (e.g., moisture, hydrocarbon, corrosive gas, etc.).
  • the layers" 620 may be provided as a coating for a material susceptible to hydrolysis.
  • a material that includes cyanate ester may be subject to hydrolysis.
  • the material may be coated with "the layers" 620 that act to reduce migration of water to the material.
  • the layers" 620 may be provided to perform, for example, two functions: (i) a moisture barrier function; and (ii) a reduction in total moisture function.
  • a moisture barrier function For example, where a material in a piece of equipment is susceptible to moisture, it may be coated with "the layers" 620 to form a barrier to moisture and to reduce moisture in the equipment (e.g., when compared to another type of barrier that may carry more moisture into the equipment).
  • the layers” 620 may be used to form protective tubing, for example, for use in one or more applications such as, for example, internal motor components like magnet wire leads, splices, and brush wire leads.
  • PFA may have a temperature rating for such components of about 500 degrees F. (e.g., about 260 degrees C.) while PTFE may have a temperature rating for such components of about 550 degrees F. (e.g., about 288 degrees C).
  • such wire may include insulation that is polyimide tape covered with fluoroplastic.
  • such insulation may be processed using heat to form an ECC-based insulation.
  • use of an insulation having "the layers" 620 in such wire may enhance function by enhancing electrical properties, for example, when compared to an insulation having a polyimide layer alone (e.g., which may be subject to hydrolysis).
  • one or more of "the layers" 620 may be compounded with one or more fillers to create a high strength, high dielectric strength part that exhibits fluid and temperature resistance.
  • a part may be an electrical connector component.
  • a piece of equipment may include one or more cavities that may be sealed (e.g., hermetically sealed). Such sealing may form one or more seals (e.g., hermetic seals) that act to reduce risk of moisture entering the cavities and causing hydrolysis of a material or materials therein.
  • seals e.g., hermetic seals
  • the layers may be provided in a cavity prior to sealing of the cavity. In such an example, "the layers” 620 may function as one or more of (i) a structural component, (ii) an insulator, (iii) a moisture barrier, and (iv) a component with a low moisture content.
  • heat treatment may occur after sealing (e.g., after sealing a cavity of an ESP system), for example, where such heat treatment may occur during use, during placement, after placement, etc., and cause "the layers" 620 to become more rigid, for instance.
  • signal wire insulation 440 may be or include "the layers" 620.
  • signal wire as well as other electrical conductors discussed herein, may also benefit from having one or more dielectric layers covered by a fluoroplastic layer. This use of "the layers” 620 inhibits degradation of the signal wire insulation 440 which may be caused by hydrolysis, for example, when the signal wire is used in a harsh environment.
  • polyimide films that find use in magnet wire insulation may be held in place with laminated or dispersion coated PFP-based adhesives.
  • the adhesive may be applied to one or both sides of the films. Coating polyimide tape on one side or both sides with PFP or a PFP-based material may provide a barrier to moisture that may improve resistance to hydrolysis of polyimide. Further resistance to moisture, and resulting degradation, is accomplished by coating the layer(s) of polyimide film with a fluoroplastic layer.
  • ESP Motor Windings for High Temperature Environments (assigned to SCHLUMBERGER RESERVOIR COMPLETIONS), which is incorporated by reference herein, describes an ESP system and various components thereof and one or more components that may include, for example, polyimide.
  • polyimide film As an example of a polyimide film, consider KAPTON film (e.g., KAPTON FWR polyimide film) marketed by the DUPONT COMPANY. While the KAPTON FWR polyimide film may exhibit "improved" hydrolysis resistance, such improved resistance is described as being related to overlap (e.g., greater than 50% overlap).
  • a film that includes polyimide may be coated (e.g., on one or both sides) with PFP or material that includes PFP, for example, to protect polyimide in the film from hydrolysis.
  • such film may be in the form of tape, for example, where overlap may exist upon application of such film to a component. In such an example, overlap may be selected based on one or more criteria and may optionally be less than about 50%.
  • a component may include (e.g., be formed at least in part by) cyanate ester.
  • Cyanate ester may be susceptible to hydrolysis, for example, at elevated temperatures.
  • PFP or a material that includes PFP may be used in conjunction with material that includes cyanate ester.
  • PFP e.g., optionally ECC PFP
  • a material that includes PFP e.g., optionally ECC PFP
  • Fig. 5 is a drawing of an example power cable 500 wherein the techniques and devices described herein may be applied, according to an embodiment.
  • a round ESP cable 500 rated for operation up to about 5 kV can include one or more copper conductors 510, conductor shield 520, oil and heat resistant EPDM rubber insulation 530 (e.g., where The E refers to ethylene, P to propylene, D to diene and M refers to a classification in ASTM standard D-1418; e.g., ethylene copolymerized with propylene and a diene), insulation shield 540, metallic shield 550, a barrier layer 560 (e.g., lead/fluoropolymer or without for low cost cables), a jacket 570 (e.g., oil resistant EPDM or nitrile rubber), and armor 580, 590 (e.g., galvanized or stainless steel or MONEL alloy marketed by I CO ALLOYS
  • a similar flat ESP cable 501 for operation up to about 5 kV can include one or more copper conductors, oil and heat resistant EPDM rubber insulation, a barrier layer (e.g., lead/fluoropolymer or without for low cost cables), a jacket layer (oil resistant EPDM or nitrile rubber or without for low cost cables), and armor (galvanized or stainless steel or MONEL alloy marketed by INCO ALLOYS INTERNATIONAL INC., Huntington, W. Va.).
  • a barrier layer e.g., lead/fluoropolymer or without for low cost cables
  • a jacket layer oil resistant EPDM or nitrile rubber or without for low cost cables
  • armor galvanized or stainless steel or MONEL alloy marketed by INCO ALLOYS INTERNATIONAL INC., Huntington, W. Va.
  • the aforementioned round ESP cable 500 and flat ESP cable 501 may include "the layers" 620 as part of the insulation 530 or insulation shield 540 of the electrical conductors 510.
  • such "layers” may be substituted, at least in part, for the EPDM rubber insulation, be provided as a barrier layer for lead (Pb), etc.
  • a cable 500, 501 may be formed using "layers" that may be rated above about 5 kV.
  • a 5 kV round ELBE G5R can include solid conductor 510 sizes of about #1 AWG (e.g., 1 AWG/1), about #2 AWG (e.g., 2 AWG/1) and about #4 AWG (e.g., 4 AWG/1).
  • #1, #2 and #4 AWG correspond to approximately 42.4 mm 2 , 33.6 mm 2 , and 21.1 mm 2 , respectively.
  • a 5 kV flat EHLTB G5F cable 501 can include a solid conductor 510 size of #4 AWG (e.g., 4 AWG/1).
  • dimensions may be, for round configurations, about 1 to 2 inches in diameter and, for flat configurations, about half an inch by about 1 inch to about 2 inches.
  • weights may range from about 1 lbm/ft to about 3 lbm/ft.
  • the conductor 510 it may be solid or compacted stranded high purity copper and coated with a metal (e.g., tin, lead, nickel, silver or other metal or alloy).
  • a metal e.g., tin, lead, nickel, silver or other metal or alloy.
  • the conductor shield 520 it may be a semiconductive material with a resistivity less than about 5000 ohm-m and be adhered to the conductor 510 to reduce or eliminate voids therebetween.
  • the conductor shield 520 may be provided as an extruded polymer (e.g., a polymer mixture) that penetrates into spaces between strands of the stranded conductor 510.
  • extrusion of the conductor shield 520 it may optionally be co-extruded or tandem extruded with the insulation 530.
  • nanoscale fillers may be included for low resistivity and suitable mechanical properties (e.g., for high temperature thermoplastics).
  • the insulation 530 may be bonded to the conductor shield 520.
  • the insulation 530 may comprise "the layers" 620.
  • the insulation shield 540 it may be a semiconductive material having a resistivity less than about 5000 ohm-m.
  • the insulation shield 540 may be adhered to the insulation 530, but, for example, removable for splicing, without leaving any substantial amounts of residue.
  • the insulation shield 540 may be extruded polymer, for example, co-extruded with the insulation 530.
  • the metallic shield 550 may be or include lead (Pb), as lead tends to be resistant to downhole fluids and gases.
  • lead Pb
  • One or more lead layers may be provided, for example, to create an impermeable gas barrier.
  • the barrier 560 it may include PTFE fluoropolymer, for example, as tape that may be helically taped.
  • the barrier 560 may include "the layers" 620 and/or be formed using a PFP that is heat ageable to form an ECC PFP.
  • the cable jacket 570 may be round (e.g., cable 500) or as shown in an alternative example, rectangular (e.g., "flat," cable 501).
  • a cable jacket may include one or more layers of EPDM, nitrile, HNBR, fluoropolymer, chloroprene, or other material (e.g., to provide for resistance to a downhole and/or other environment).
  • each conductor assembly phase may include solid metallic tubing, such that splitting out the phases is more easily accomplished (e.g., to terminate at a connector, to provide improved cooling, etc.).
  • the cable jacket 570 may be formed using "the layers" 620.
  • metal or metal alloy may be employed, optionally in multiple layers for improved damage resistance.
  • Fig. 6 is a drawing of an example electrical conductor cable 600 wherein the techniques and devices described herein may be applied, according to an embodiment.
  • the cable 600 of FIG. 6 is intended to be generic, and represent many types of cables, wires, or conductors, intended for many applications.
  • the cable 600 comprises an electrical conductor 602, a dielectric layer 604 surrounding the electrical conductor 602, and a fluoroplastic layer 606 covering the dielectric layer 604.
  • FIG. 6 illustrates an example of "the layers" 620, which comprises one or more of the dielectric layer 604 (with or without adhesive layers 608 and/or 610) and at least one fluoroplastic layer 606.
  • the fluoroplastic layer 606 comprises an epitaxial co- crystallized alloy fluoroplastic or a fluoroplastic modified with maleic anhydride.
  • the fluoroplastic layer 606 comprises one of: polyvinylidene difluoride (PVDF), PVDF/hexafluoropropylene (HFP), ethylene tetrafluoroethylene (ETFE), fluorinated ethylene propylene (FEP), perfluoroalkoxy (PFA), ethyl cyanoacrylate (ECA) or polytetrafluoroethylene (PTFE).
  • each dielectric layer 604 comprises a polyimide layer 604 and one or more fluoropolymer layers 608, 610.
  • each dielectric layer 604 comprises a polyimide tape coated with a fluoropolymer adhesive.
  • the polyimide tape is coated with the fluoropolymer adhesive on one or both sides of the tape (see FIG. 8).
  • the fluoroplastic layer 606 covers a layer (e.g. 610) of fluoropolymer adhesive.
  • a thickness of the polyimide tape 604 is between 2 to 10 mils. Further, in some implementations, a thickness of the fluoropolymer layer 606 is 1 to 5 mils. In alternate implementations, either the polyimide tape 604 and/or the fluoropolymer layer 606 may be thinner or thicker, and be effective in reducing hydrolysis damage to a component such as a cable 600.
  • the cable 600 comprises a magnet wire.
  • the magnet wire may be part of a stator of an electric motor, where the electrical conductor 602 (and the associated insulation layers 604, 606, 608, 610) is wound around the stator to form an electro-magnet.
  • windings of the electrical conductor 602 are secured in place via a structural composite.
  • the structural composite may comprise a fibrous reinforcement including one or more of: glass, quartz, or aramid and/or an organic or inorganic polymer matrix including one or more of: epoxy, bismaleimide, cyanate ester, silicone, Ring-Opening Metathesis Polymers (ROMP), or preceramic polymers.
  • the stator and windings of the electrical conductor 602 are fully encapsulated within a fluoroplastic layer.
  • Manufacturing techniques for polyimide film insulated magnet wire often include a tape wrapping process.
  • the tape is wrapped around the wire at a desired overlap.
  • Multiple tape heads may be used to achieve thicker layers, and tape may be wrapped at different angles to provide robustness.
  • the tape may be passed through high temperature ovens to melt and consolidate the adhesive, creating a bond.
  • the taped wire may be passed through a roller to apply additional pressure to the tape and squeeze out any trapped air.
  • FIG. 6 represents an example of one of the MLEs 600 suitable for use in the system 200 of FIG. 2 or optionally one or more other systems (e.g., SAGD, etc.). While one example of FIG. 6 mentions MLE or "lead extension", it may be implemented as a single conductor assembly cable 600 for any of a variety of downhole uses.
  • a power cable for artificial lift equipment can include one or more cable assemblies 600, each including a copper conductor 602 (e.g., solid, stranded, compacted stranded, etc.), a conductor shield with resistivity less than about 5000 ohm-m surrounding the conductor 602, insulation 604, 606, an insulation shield having a resistivity less than 5000 ohm-m surrounding the insulation, a metallic shield surrounding the insulation shield, and a polymer barrier surrounding the metallic shield.
  • a cable may include a jacket molded about the one or more conductor assemblies and optionally armor surrounding the jacket.
  • a cable that may be rated for use at over 5 kV may include one or more of a semiconductive conductor shield and a semiconductive insulation shield.
  • a power cable 600 for downhole equipment can include a copper conductor 602 (e.g., optionally solid); a conductor shield with resistivity less than about 5000 ohm-m surrounding the conductor; insulation 604, 606 (e.g., optionally a PFP heat ageable to form an ECC PFP); an insulation shield having a resistivity less than about 5000 ohm-m surrounding the insulation; a metallic shield surrounding the insulation shield; a polymer barrier surrounding the metallic shield; a braided layer surrounding the metallic shield; and armor surrounding the braided layer.
  • a copper conductor 602 e.g., optionally solid
  • insulation 604, 606 e.g., optionally a PFP heat ageable to form an ECC PFP
  • an insulation shield having a resistivity less than about 5000 ohm-m surrounding the insulation a metallic shield surrounding the insulation shield; a polymer barrier surrounding the metallic shield; a braided layer surrounding the metallic shield; and armor surrounding the braided layer.
  • a braid of a braided layer various types of materials may be used such as, for example, polyethylene terephthalate (PET) (e.g., applied as a protective braid, tape, fabric wrap, etc.). PET may be considered as a low cost and high strength material.
  • PET polyethylene terephthalate
  • a braid layer can help provide protection to a soft lead jacket during an armor wrapping process. In such an example, once downhole, the function of the braid may be minimal.
  • nylon or glass fiber tapes and braids may be implemented. Yet other examples can include fabrics, rubberized tapes, adhesive tapes, and thin extruded films.
  • the braid layer may be formed using "the layers" 620.
  • a layer may be formed over the braid layer, for example, using "the layers” 620.
  • one or more of "the layers" 620 may be extruded.
  • a conductor (e.g., solid or stranded) may be surrounded by a semiconductive material layer that acts as a conductor shield where, for example, the layer has a thickness greater than approximately 0.005 inch.
  • a cable 600 can include a conductor 602 with a conductor shield that has a radial thickness of approximately 0.010 inch.
  • a cable 600 can include a conductor 602 with a conductor shield that has a radial thickness in a range from greater than approximately 0.005 inch to approximately 0.015 inch.
  • a conductor 602 may have a conductor size in a range from approximately #8 AWG (e.g., OD approx. 0.128 inch or area of approx. 8.36 mm 2 ) to approximately #2/0 "00" AWG (e.g., OD approx. 0.365 inch or area of approx. 33.6 mm 2 ).
  • a conductor 602 configuration may be solid or stranded (e.g., including compact stranded).
  • a conductor 602 may be smaller than #8 AWG or larger than #2/0 "00" AWG (e.g., #3/0 "000” AWG, OD approx. 0.41 inch or area of approx. 85 mm 2 ).
  • one or more layers of a cable 600 may be made of a material that is semiconductive (e.g., a semiconductor).
  • a layer e.g., or layers
  • a layer may include a polyimide material and a graphite filler (e.g., expanded graphite, etc.).
  • the polyimide/graphite layer 604 is covered with a fluoroplastic layer 606 to inhibit moisture migration to the polyimide/graphite layer 604.
  • a cable 600 may include a conductor 602 that has a size within a range of approximately 0.1285 inch to approximately 0.414 inch and a conductor shield layer that has a radial thickness within a range of approximately greater than 0.005 inch to approximately 0.015 inch.
  • a cable 600 may include a conductor 602 with a conductor shield (e.g., a semiconductor layer) and insulation (e.g., an insulation layer) where the conductor shield and the insulation are extruded.
  • the conductor shield may be extruded onto the conductor 602 followed by extrusion of the insulation onto the conductor shield.
  • Such a process may be performed, for example, using a co-extrusion, a sequential extrusion, etc.
  • a shield and/or insulation may be formed using "the layers" 620.
  • insulation 604 may include one layer or multiple layers of a high temperature polymeric dielectric material such as polyimide (see FIG. 8).
  • the polymeric insulating material may be in the form of tape that may be applied helically or longitudinally (e.g., by wrapping polyimide tape 604 onto a conductor 602 in an overlap configuration).
  • a thickness of a polymer insulator layer 802 may be from about 0.0005 inch to about 0.005 inch.
  • a polymer insulator layer may be a polyimide film 802, for example, optionally coated on one side or both sides (e.g., directly and/or indirectly) with a material that may be heat aged.
  • a PFP 804 e.g., a fluoropolymer adhesive
  • the polyimide material 802 may be coated with a fluoroplastic material (e.g., fluoroplastic layer 606, for example) to protect the polyimide material 802 from degradation due to hydrolysis.
  • the thickness of the fluoropolymer adhesive 804 may be a variable, depending on the application, for instance. Additionally, the adhesive 804 may be a blend of PFP-type materials. As further shown in FIG. 8, a hydrolysis resistant polyimide film may also be used to further increase longevity of the insulation layers.
  • a polymer insulator may be commercially available (e.g., consider various polymers marketed under the mark DUPONT).
  • the DUPONT polymer 150PRN411 may be used as polymer insulation; where "150" indicates a 1.5 mils overall tape thickness, where "PRN” indicates an UN polyimide film with a high temperature fluoropolymer adhesive, where "4" indicates a 0.0004 inch thick high temperature adhesive on the bottom side of the tape, where the first "1" indicates the thickness of the polyimide film and where the second "1" indicates a 0.0001 inch thick high temperature adhesive on the top side of the tape.
  • the polyimide layer 604 and/or the fluoroplastic layer 606 may be deposited via an extrusion process.
  • the polyimide layer 604 may be co- extruded with another material such as, for example, a PFP-based material (e.g., the fluoroplastic layer 606).
  • a cable 600 may include a conductor shield, insulation and an insulation shield that have been extruded separately (e.g., by separate extruders with a delay to allow for hardening, etc.).
  • a cable 600 may include a conductor shield, insulation and insulation shield formed via co-extrusion, for example, using separate extrusion bores that feed to an appropriate cross-head, extrusion die or dies that deposit the layers in a substantially simultaneous manner (e.g., within about a minute or less).
  • an extrusion process may be controlled to allow for some amount of intermixing at an interface between two layers, for example, to provide for more complete bonding between the two "layers" (604, 606).
  • an extrusion process may be performed to minimize defects, voids, contamination, etc., via intermixing at the interface (e.g., via co-extrusion of the two layers).
  • an insulation shield as mentioned, ease of removal may be beneficial when making connections. Further, electrical stresses tend to diminish for layers positioned outside of an insulation layer.
  • extrusion may provide for a reduction in the overall dimension of a cable (e.g., in some oil field applications, well clearance may be a concern).
  • Extruded layers tend to be smoother than tape, which can help balance out an electrical field.
  • a tape layer or layers over a conductor can have laps and rough surfaces that can cause voltage stress points. Taping for adjacent layers via multiple steps may risk possible contamination between the layers.
  • a co-extrusion process may be configured to reduce such contamination.
  • co-extrusion may help to eliminate voids, contamination, or rough spots at a conductor shield/insulation interface, which could create stress points where discharge and cable degradation could occur.
  • a conductor shield may be extruded, optionally co- extruded with insulation thereon.
  • FIG. 7 shows example techniques 705, 707 and 709 for extruding material as part of a cable manufacturing process.
  • the technique 705 includes providing a spool 710 with a conductor 711 carried thereon, providing material 712 for an extruder 713 and providing material 714 for an extruder 715.
  • the conductor 71 1 is feed from the spool 710 to the extruder 713 which receives the material 712 (e.g., in a solid state), melts the material 712 and deposits it onto the conductor 71 1.
  • the conductor 71 1 with the material 712 deposited thereon is feed to the extruder 715, which receives the material 714 (e.g., in a solid state), melts the material 714 and deposits it onto the material 712.
  • an extruder 717 provides for co-extrusion of the materials 712 and 714 onto the conductor 711 as received from the spool 710.
  • a co-extrusion process may include multiple extruder bores and a cross-head, die, dies, etc. to direct molten material onto a conveyed conductor (e.g., which may be bare or may have one or more layers deposited therein).
  • the material 712 may be a semiconductor to form a conductor shield and the material 714 may be an insulator to form insulation over the conductor shield.
  • the materials 712 and 714 may be selected to allow for some amount of cross-linking at their interfaces upon deposition (e.g., in part facilitated by heat energy imparted via extrusion).
  • FIG. 7 shows a cross-section of an example of a cable 600 as produced by the technique 705 or the technique 707 as including a conductor 711 (i.e., conductor 602), a conductor shield 712 and insulation 714 (i.e., "the layers" 620).
  • a conductor 711 i.e., conductor 602
  • a conductor shield 712 i.e., "the layers" 620.
  • insulation 714 i.e., "the layers” 620.
  • one or more other components may be fabricated via extrusion where, for example, a cross-section may exhibit multiple layers where at least one layer includes a composition that may undergo or has undergone epitaxial co-crystallization.
  • an electric motor 340 such as an electric submersible pump motor, for example, can include a housing; and a hermetically sealed cavity defined at least in part by the housing that includes at least one material susceptible to hydrolysis, and a polymeric material that includes "the layers" 620.
  • an electric submersible pump motor 340 may include a fluorinated dielectric oil disposed in a hermetically sealed cavity where the cavity also includes, for example, at least one material susceptible to hydrolysis and a polymeric material that includes "the layers" 620.
  • a material susceptible to hydrolysis may be or include polyimide.
  • a polymeric material may contact polyimide where the polymeric material includes a fluoroplastic.
  • an ESP motor 340 may include a stator where, for example, a shaft of includes a rotor disposed in a hermetically sealed cavity.
  • a hermetically sealed cavity may be sealed against entry of water vapor and, for example, include polymeric material that includes "the layers" 620.
  • the motor 340 includes magnet wire, at least a portion of the magnet wire wound around the stator to form an electro-magnet.
  • the magnet wire includes an electrical conductor 602, a polyimide tape with a fluoropolymer adhesive dielectric layer 604 surrounding the electrical conductor, and a fluoroplastic layer 606 covering the dielectric layer 604.
  • the magnet wire is wound through the slots which are lined with dielectric slot liner film.
  • this slot liner film comprises either a hydrolysis resistant polyimide base film or a high strength expanded polytetrafluoroethylene (ePTFE) sheet. Other materials such as PEEK, standard polyimide, and PTFE may be used as well.
  • the windings may be held in place by use of a completely encapsulated stator (with similar polymer matrices).
  • a completely encapsulated stator with similar polymer matrices.
  • the stator slots are completely filled with a thermosetting resin, possibly one with a thermally conductive component.
  • Either a varnished or fully encapsulated stator could utilize a surface treatment of the polyimide wire to enhance bonding between the insulation and the varnish or encapsulant; this treatment could be thermal, chemical or plasma based.
  • the mechanical strength of the stator can be increased resulting in improved vibration resistance.
  • the insulated magnet wire can be encapsulated without being surface treated. In this case, the fluoropolymer coating will prevent adhesion which will allow the wires to slide during thermal cycling of the stator.
  • the motor 340 includes one or more additional components, as discussed above, including one or more of: lead wire insulation, motor lead extension insulation, ESP cable insulation, splices between cables and motor leads, splices between lead wires and magnet wires, a stator housing insulation sleeve, phase barrier films, or slot liner films.
  • a polyimide dielectric layer and a fluoroplastic layer are applied to one or more of the additional components, covering at least a portion of the one or more of the additional components to reduce hydrolysis at the one or more of the additional components.
  • FIG. 9 illustrates a representative process 900 for reducing degradation of an electrical conductor cable (such as cable 600, for example) in accordance with one or more embodiments.
  • the process 900 is described with reference to FIGS. 1-8.
  • the process includes surrounding an electrical conductor (such as conductor 602, for example) with a dielectric layer (such as dielectric layer 604, for example).
  • a dielectric layer such as dielectric layer 604, for example.
  • the dielectric layer comprises a polyimide tape with a fluoropolymer adhesive.
  • the dielectric tape is coated with the fluoropolymer adhesive on a top surface of the dielectric tape and a bottom surface of the dielectric tape.
  • the process includes wrapping the electrical conductor with multiple overlapping layers of a dielectric tape coated with a fluoropolymer adhesive.
  • the process includes covering the dielectric layer with a fluoroplastic layer (such as fluoroplastic layer 606, for example).
  • a fluoroplastic layer such as fluoroplastic layer 606, for example.
  • the process includes reducing a degradation rate of the dielectric layer by inhibiting migration of moisture to the dielectric layer via the fluoroplastic layer.
  • the process includes heating the dielectric tape with fluoropolymer adhesive to near a melting point of the dielectric tape prior to covering the dielectric layer with the fluoroplastic layer.
  • the process includes extruding the fluoroplastic layer over the dielectric layer.
  • the process includes wrapping the dielectric layer with a fluoroplastic tape and heat fusing the fluoroplastic tape to the dielectric layer.
  • the process includes covering the dielectric layer with a fluoroplastic layer that is at least 1 to 5 mils thick.
  • the process includes wrapping a portion of the electrical conductor on a stator of an electric submersible pump (ESP) motor.
  • the process may include reducing adhesion of the electrical conductor to itself by encapsulating the dielectric layer with the fluoroplastic layer without surface treating the fluoroplastic layer.

Abstract

Des mises en œuvre représentatives de dispositifs et de techniques selon l'invention fournissent une isolation de conducteur électrique améliorée. Par exemple, l'isolation de conducteur électrique améliorée est résistante à l'hydrolyse qui peut accompagner l'utilisation du conducteur électrique dans un environnement agressif, tel qu'un environnement à haute température et/ou à pression élevée. Dans un exemple, l'isolation améliorée peut réduire un taux de dégradation d'une couche diélectrique du conducteur électrique. Dans d'autres exemples, les dispositifs et les techniques peuvent améliorer la résistance à l'hydrolyse pour d'autres composants d'un moteur électrique, tel qu'un moteur électrique de pompe étanche à l'immersion, par exemple.
PCT/US2014/053031 2014-08-28 2014-08-28 Isolation de conducteur électrique améliorée WO2016032469A1 (fr)

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Cited By (5)

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Publication number Priority date Publication date Assignee Title
US10598407B2 (en) 2017-11-03 2020-03-24 Emerson Electric Co. Gas powered water heater controller and related methods
IT202100020936A1 (it) * 2021-08-03 2023-02-03 Univ Degli Studi Padova Metodo per l’isolamento elettromagnetico di componenti di un motore elettrico
WO2023064569A1 (fr) * 2021-10-14 2023-04-20 Schlumberger Technology Corporation Outillage pour stators esp encapsulés
US11901785B2 (en) 2016-08-03 2024-02-13 Schlumberger Technology Corporation Polymeric materials
US11955782B1 (en) 2022-11-01 2024-04-09 Typhon Technology Solutions (U.S.), Llc System and method for fracturing of underground formations using electric grid power

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US4420876A (en) * 1981-05-06 1983-12-20 The Boeing Company Method of coil assembly for hot melt induction heater apparatus
JPH10164795A (ja) * 1996-11-29 1998-06-19 Tokyo Parts Ind Co Ltd スピンドルモータの軸受構造
US6117508A (en) * 1997-06-27 2000-09-12 Dyneon Llc Composite articles including a fluoropolymer blend
US20030204021A1 (en) * 2002-04-26 2003-10-30 Teknor Apex Company Blends of fluoropolymer and plasticized polyvinyl chloride
US20140152155A1 (en) * 2012-12-05 2014-06-05 Ge Oil & Gas Esp, Inc. High temperature downhole motors with advanced polyimide insulation materials

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Publication number Priority date Publication date Assignee Title
US4420876A (en) * 1981-05-06 1983-12-20 The Boeing Company Method of coil assembly for hot melt induction heater apparatus
JPH10164795A (ja) * 1996-11-29 1998-06-19 Tokyo Parts Ind Co Ltd スピンドルモータの軸受構造
US6117508A (en) * 1997-06-27 2000-09-12 Dyneon Llc Composite articles including a fluoropolymer blend
US20030204021A1 (en) * 2002-04-26 2003-10-30 Teknor Apex Company Blends of fluoropolymer and plasticized polyvinyl chloride
US20140152155A1 (en) * 2012-12-05 2014-06-05 Ge Oil & Gas Esp, Inc. High temperature downhole motors with advanced polyimide insulation materials

Cited By (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US11901785B2 (en) 2016-08-03 2024-02-13 Schlumberger Technology Corporation Polymeric materials
US10598407B2 (en) 2017-11-03 2020-03-24 Emerson Electric Co. Gas powered water heater controller and related methods
US11313587B2 (en) 2017-11-03 2022-04-26 Emerson Electric Co. Method of manufacturing an electromagnetic actuator for a gas powered water heater controller
IT202100020936A1 (it) * 2021-08-03 2023-02-03 Univ Degli Studi Padova Metodo per l’isolamento elettromagnetico di componenti di un motore elettrico
WO2023012662A1 (fr) * 2021-08-03 2023-02-09 Università Degli Studi Di Padova Procédé d'isolation électromagnétique de composants de moteur électrique
WO2023064569A1 (fr) * 2021-10-14 2023-04-20 Schlumberger Technology Corporation Outillage pour stators esp encapsulés
US11955782B1 (en) 2022-11-01 2024-04-09 Typhon Technology Solutions (U.S.), Llc System and method for fracturing of underground formations using electric grid power

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