WO2016111689A1

WO2016111689A1 - Fluid conduit and electric submersible pump system

Info

Publication number: WO2016111689A1
Application number: PCT/US2015/010591
Authority: WO
Inventors: Brian Scott; Miguel Angel HIDALGO CHANGOLUISA
Original assignee: Schlumberger Canada Limited; Services Petroliers Schlumberger; Schlumberger Technology B.V.; Schlumberger Technology Corporation
Priority date: 2015-01-08
Filing date: 2015-01-08
Publication date: 2016-07-14

Abstract

An electric submersible pump (ESP) system can include a shaft that includes a shaft axis; a power cable connector; an electric motor configured to receive power via the power cable connector for rotatably driving the shaft; a pump operatively coupled to the shaft; and a conduit coupled directly or indirectly to the pump or the electric motor where the conduit includes an axial length and at least one non-circular cross-section. Various other apparatuses, systems, methods, etc., are also disclosed.

Description

FLUID CONDUIT AND ELECTRIC SUBMERSIBLE PUMP SYSTEM

BACKGROUND

[0001] An electric submersible pump (ESP) system can include a pump driven by an electric motor. As an example, an ESP system may be deployed in a well, for example, to pump fluid. Such an ESP system may be exposed to harsh

environmental and operational conditions. Various technologies, techniques, etc. described herein pertain to equipment that may be, for example, part of an ESP system.

SUMMARY

[0002] An electric submersible pump (ESP) system can include a shaft that includes a shaft axis; a power cable connector; an electric motor configured to receive power via the power cable connector for rotatably driving the shaft; a pump operatively coupled to the shaft; and a conduit coupled directly or indirectly to the pump or the electric motor where the conduit includes an axial length and at least one non-circular cross-section. Various other apparatuses, systems, methods, etc., are also disclosed.

[0003] This summary is provided to introduce a selection of concepts that are further described below in the detailed description. This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.

BRIEF DESCRIPTION OF THE DRAWINGS

[0004] Features and advantages of the described implementations can be more readily understood by reference to the following description taken in conjunction with the accompanying drawings.

[0005] Fig. 1 Ilustrates examples of equipment in geologic environments;

[0006] Fig. 2 llustrates an example of an electric submersible pump system;

[0007] Fig. 3 Ilustrates examples of equipment;

[0008] Fig. 4 llustrates an example of a system that includes a motor;

[0009] Fig. 5 Ilustrates an example of a system that includes at least one conduit;

[0010] Fig. 6 [0011] Fig. 7 illustrates examples of equipment; and

[0012] Fig. 8 illustrates example components of a system and a networked system.

DETAILED DESCRIPTION

[0013] The following description includes the best mode presently

contemplated for practicing the described implementations. This description is not to be taken in a limiting sense, but rather is made merely for the purpose of describing the general principles of the implementations. The scope of the described

implementations should be ascertained with reference to the issued claims.

[0014] Fig. 1 shows examples of geologic environments 120 and 140. In Fig. 1 , the 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). As an example, the geologic environment 120 may be outfitted with any of a variety of sensors, detectors, actuators, etc. For example, 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. As an example, one or more satellites may be provided for purposes of communications, data acquisition, etc. For example, Fig. 1 shows a satellite in communication with the network 125 that may be configured for communications, noting that the satellite may additionally or alternatively include circuitry for imagery (e.g., spatial, spectral, temporal, radiometric, etc.).

[0015] 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. For example, consider a well in a shale formation that may include natural fractures, artificial fractures (e.g., hydraulic fractures) or a combination of natural and artificial fractures. As an example, a well may be drilled for a reservoir that is laterally extensive. In such an example, 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.). As an example, 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.

[0016] As to the geologic environment 140, as shown in Fig. 1 , it includes two wells 141 and 143 (e.g., bores), which may be, for example, disposed at least partially in a layer such as a sand layer disposed between caprock and shale. As an example, the 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 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.

[0017] As an example, a SAGD operation in the geologic environment 140 may use the well 141 for steam-injection and the well 143 for resource production. In such an example, the equipment 145 may be a downhole steam generator and the equipment 147 may be an electric submersible pump (e.g., an ESP).

[0018] As illustrated in a cross-sectional view of Fig. 1 , steam injected via the well 141 may rise in a subterranean portion of the geologic environment and transfer heat to a desirable resource such as heavy oil. In turn, as the resource is heated, its viscosity decreases, allowing it to flow more readily to the well 143 (e.g., a resource production well). In such an example, equipment 147 (e.g., an ESP) may then assist with lifting the resource in the well 143 to, for example, a surface facility (e.g., via a wellhead, etc.). As an example, where 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 in addition to a desired resource). In such an example, an ESP may experience conditions that may depend in part on operation of other equipment (e.g., steam injection, operation of another ESP, etc.).

[0019] Conditions in a geologic environment may be transient and/or persistent. Where equipment is placed within a geologic environment, 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. Where equipment is to endure in an environment over a significant period of time, uncertainty may arise in one or more factors that could impact integrity or expected lifetime of the equipment. As an example, where a period of time may be of the order of decades, equipment that is intended to last for such a period of time may be constructed to endure conditions imposed thereon, whether imposed by an environment or environments and/or one or more functions of the equipment itself.

[0020] 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 geologic environment. As an example, an ESP may be expected to function in an environment over an extended period of time (e.g., optionally of the order of years). As an example, commercially available ESPs (such as the REDA™ ESPs marketed by

Schlumberger Limited, Houston, Texas) may find use in applications that call for, for example, pump rates in excess of about 4,000 barrels per day and lift of about 12,000 feet or more.

[0021] In the example of Fig. 2, the ESP system 200 includes a network 201 , a well 203 disposed in a geologic environment (e.g., with surface equipment, etc.), 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.

[0022] As shown, the well 203 includes a wellhead that can include a choke (e.g., a choke valve). For example, 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.

[0023] As to the ESP 210, it is shown as including cables 21 1 (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, strain, current leakage, vibration, etc.) and optionally a protector 217.

[0024] As an example, an ESP may include a REDA™ Hotline high- temperature ESP motor. Such a motor may be suitable for implementation in a thermal recovery heavy oil production system, such as, for example, SAGD system or other steam-flooding system. [0025] As an example, an ESP motor can include a three-phase squirrel cage with two-pole induction. As an example, an ESP motor may include steel stator laminations that can help focus magnetic forces on rotors, for example, to help reduce energy loss. As an example, stator windings can include copper and insulation.

[0026] As an example, the one or more sensors 216 of the ESP 210 may be part of a digital downhole monitoring system. For example, consider the

commercially available Phoenix™ Multisensor xt150 system marketed by

Schlumberger Limited (Houston, Texas). A monitoring system may include a base unit that operatively couples to an ESP motor (see, e.g., the motor 215), for example, directly, via a motor-base crossover, etc. As an example, such a base unit (e.g., base gauge) may measure intake pressure, intake temperature, motor oil

temperature, motor winding temperature, vibration, currently leakage, etc. As explained with respect to Fig. 4, a base unit may transmit information via a power cable that provides power to an ESP motor and may receive power via such a cable as well.

[0027] As an example, a remote unit may be provided that may be located at a pump discharge (e.g., located at an end opposite the pump intake 214). As an example, a base unit and a remote unit may, in combination, measure intake and discharge pressures across a pump (see, e.g., the pump 212), for example, for analysis of a pump curve. As an example, alarms may be set for one or more parameters (e.g., measurements, parameters based on measurements, etc.).

[0028] Where a system includes a base unit and a remote unit, such as those of the Phoenix™ Multisensor x150 system, the units may be linked via wires. Such an arrangement provide power from the base unit to the remote unit and allows for communication between the base unit and the remote unit (e.g., at least

transmission of information from the remote unit to the base unit). As an example, a remote unit is powered via a wired interface to a base unit such that one or more sensors of the remote unit can sense physical phenomena. In such an example, the remote unit can then transmit sensed information to the base unit, which, in turn, may transmit such information to a surface unit via a power cable configured to provide power to an ESP motor. Where a remote unit and a base unit are coupled via wires, damage to the wires can result in loss of functionality of the remote unit. [0029] In the example of Fig. 2, the well 203 may include one or more well sensors 220, for example, such as the commercially available OpticLine™ sensors or WellWatcher BriteBlue™ sensors marketed by Schlumberger Limited (Houston, Texas). 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. 1 , 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. Well sensors may extend thousands of feet into a well (e.g., 4,000 feet or more) and beyond a position of an ESP.

[0030] In the example of Fig. 2, 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.

[0031] As shown in Fig. 2, the controller 230 may 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, Texas). In the example of Fig. 2, the controller 230 may access one or more of the PIPESIM™ framework 284, the ECLIPSE™ framework 286 marketed by Schlumberger Limited (Houston, Texas) and the PETREL™ framework 288 marketed by Schlumberger Limited (Houston, Texas) (e.g., and optionally the OCEAN™ framework marketed by Schlumberger Limited (Houston, Texas)).

[0032] In the example of Fig. 2, 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. As an example, the UniConn™ motor controller can interface with the aforementioned 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.

[0033] For FSD controllers, 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.

[0034] For VSD units, the UniConn™ 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.

[0035] In the example of Fig. 2, 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. The motor controller 250 may include any of a variety of features, additionally, alternatively, etc.

[0036] In the example of Fig. 2, the VSD unit 270 may be a low voltage drive (VSD) 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). As an example, 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, Texas).

[0037] Fig. 3 shows cut-away views of examples of equipment such as, for example, a portion of a pump 320, a protector 370 and a motor 350 of an ESP. The pump 320, the protector 370 and the motor 350 are shown with respect to cylindrical coordinate systems (e.g., r, z, Θ). Various features of equipment may be described, defined, etc. with respect to a cylindrical coordinate system. As an example, a lower end of the pump 320 may be coupled to an upper end of the protector 370 and a lower end of the protector 370 may be coupled to an upper end of the motor 350. As shown in Fig. 3, a shaft segment of the pump 320 may be coupled via a connector to a shaft segment of the protector 370 and the shaft segment of the protector 370 may be coupled via a connector to a shaft segment of the motor 350. As an example, an ESP may be oriented in a desired direction, which may be vertical, horizontal or other angle. As shown in Fig. 3, the motor 350 is an electric motor that includes a connector 352, for example, to operatively couple the electric motor to a power cable, for example, optionally via one or more motor lead extensions (see, e.g., Fig. 4).

[0038] Fig. 4 shows a block diagram of an example of a system 400 that includes a power source 401 as well as data 402 (e.g., information). The power source 401 provides power to a VSD block 470 while the data 402 may be provided to a communication block 430. The data 402 may include instructions, for example, to instruct circuitry of the circuitry block 450, one or more sensors of the sensor block 460, etc. The data 402 may be or include data communicated, for example, from the circuitry block 450, the sensor block 460, etc. In the example of Fig. 4, a choke block 440 can provide for transmission of data signals via a power cable 41 1 (e.g., including motor lead extensions "MLEs"). A power cable may be provided in a format such as a round format or a flat format with multiple conductors. MLEs may be spliced onto a power cable to allow each of the conductors to physically connect to an appropriate corresponding connector of an electric motor (see, e.g., the connector 352 of Fig. 3). As an example, MLEs may be bundled within an outer casing (e.g., a layer of armor, etc.).

[0039] As shown, the power cable 41 1 connects to a motor block 415, which may be a motor (or motors) of an ESP and be controllable via the VSD block 470. In the example of Fig. 4, the conductors of the power cable 41 1 electrically connect at a wye point 425. The circuitry block 450 may derive power via the wye point 425 and may optionally transmit, receive or transmit and receive data via the wye point 425. As shown, the circuitry block 450 may be grounded.

[0040] As an example, power cables and MLEs that can resist damaging forces, whether mechanical, electrical or chemical, may help ensure proper operation of a motor, circuitry, sensors, etc.; noting that a faulty power cable (or MLE) can potentially damage a motor, circuitry, sensors, etc. Further, as mentioned, an ESP may be located several kilometers into a wellbore. Accordingly, time and cost to replace a faulty ESP, power cable, MLE, etc., can be substantial (e.g., time to withdraw, downtime for fluid pumping, time to insert, etc.).

[0041] As an example, one or more fluid conduits that may include non- circular cross-sections. As an example, such a conduit may be implemented in conjunction with an electrical submersible pump. As an example, a system may include a fluid conduit and an electrical submersible pump (ESP), for example, where the fluid conduit may extend from a location above the ESP and at least in part along a length of the ESP, optionally to a location below the ESP. In such an example, the fluid conduit may include a non-circular cross-section, which may, for example, provide for a particular cross-sectional arrangement of equipment in a casing (e.g., optionally to provide a clearance or clearances between various pieces of equipment).

[0042] As an example, a conduit may include a non-circular cross-section and be configured to deliver fluid. In such an example, fluid may be delivered to dilute another fluid such as, for example, viscous oil. In such an example, the conduit may include an outlet at or below an intake to an ESP that is configured to pump the fluid (e.g., to pump oil that may be diluted oil).

[0043] As an example, a method may include optimizing space, for example, in a cross-section of a downhole assembly. As an example, a method can include optimizing space between an ESP and a wellbore casing to locate a discrete fluid conduit, for example, via use of one or more non-circular tubes (e.g., conduits).

[0044] As an example, an ESP (or ESPs) may be installed in a wellbore casing where a void space exists between the ESP and the inner surface of the wellbore casing. As an example, a method may account for a) one or more mechanical clearances (e.g., for an ESP to be lowered and raised within a casing) and b) fluid passage around (e.g., past) one or more sections of the ESP. In such an example, where the ESP takes up considerable area within the casing, the remaining void space may be challenging to effectively subdivide to provide a discrete fluid conduit where such a conduit is circular, for example, having a cross-sectional area to accommodate a desired amount of fluid flow (e.g., a flow rate, axial flow velocity, etc.).

[0045] Fig. 5 shows an example of a system where clearances may be "tight" between one or more ESP components and an inner surface of a casing (e.g., at a cross-section, for example, at an axial position). As noted, depending on orientation of the ESP, an axial position may be a depth (e.g., for a vertical portion of a well) or may be specified with respect to another coordinate or coordinates (e.g., for a horizontal portion of a well). Fig. 5 shows an outer casing, a packer, production tubing (e.g., as an inner casing), tubular production in fluid communication with the pump of the ESP, MLEs, and a reduced area for positioning of one or more fluid conduits (e.g., between MLEs and the inner surface of the production tubing (e.g., inner casing).

[0046] As an example, in the system 500, one or more conduits that include at least a portion thereof with a non-circular cross-section may be used, for example, in an area with smaller clearances (e.g., due to MLEs, etc.). In such an example, such conduits may optionally provide greater flow area than circular tubes. As an example, a method that implements one or more fluid conduits where each includes at least one non-circular cross-sectional portion (e.g., along a length), more efficient injection of suitable volumes of treatment fluid for purposes such as corrosion, scale, or hydrate inhibition, dilution of reservoir fluid of a high viscosity or density, etc. may be possible.

[0047] Fig. 6 shows a cross-sectional view of an example of a system that includes a casing, an ESP, a power cable (e.g., or MLEs) and two conduits that include substantially rectangular cross-sections in the particular cross-section of the cross-sectional view.

[0048] As an example, a non-circular cross-section conduit may be prepared in a continuous length (e.g., optionally longer than an intended ESP assembly) and coiled around a shipping reel for transportation and subsequent deployment, retraction, etc.

[0049] As an example, one or more conduits may be prepared in various lengths, for example, to suit configuration of one or more ESP components. In such an example, a length may be coupled (e.g., attached) to one or more ESP

components (e.g., with suitable clamp devices, etc.). As an example, at connection points in an ESP string, one or more conduits that include at least one non-circular cross-section may be connected using a "jumper assembly" such as, for example, a short length of conduit fitted with end connectors.

[0050] Fig. 7 shows examples of lengths of conduits and a non-circular conduit jumper assembly. As an example, an ESP may be deployed (e.g., positioned) in a well with a first length of conduit that includes a non-circular cross- sectional area (e.g., along at least a portion of the conduit). As an example, a second length of conduit may optionally be joined to the first length, for example, via a jumper. As an example, the first length may be provided for optional use, for example, for use where particular conditions arise. As an example, a length may be closed (e.g., at an upper end, a lower end, and/or at an intermediate point). Such a length may be operatively opened, for example, responsive to flow, coupling of a jumper, interaction with a tool, responsive to a command, responsive to pressure, etc. As an example, such a conduit may be configured for one or more purposes, which may provide some degree of flexibility to an ESP installation that includes one or more of such conduits.

[0051] As an example, above an ESP, a conduit used to produce fluid to a surface (e.g., a wellhead, a Christmas tree, etc.) may be matched by use of a parallel or concentric tube that provides the conduit for treatment fluids to be pumped from surface down to the ESP assembly. As to the example of a concentric conduit, a flow crossover tool may be provided and used, for example, to connect the treatment fluid conduit to one or more of the conduits that each may include at least one non-circular cross-sectional area (e.g., rectangular, rounded annular section, etc.).

[0052] An electric submersible pump (ESP) system can include a shaft that includes a shaft axis; a power cable connector; an electric motor configured to receive power via the power cable connector for rotatably driving the shaft; a pump operatively coupled to the shaft; and a conduit coupled directly or indirectly to the pump or the electric motor where the conduit includes an axial length and at least one non-circular cross-section.

[0053] As an example, a non-circular cross-section may be a rectangular cross-section. As an example, a conduit may include a non-circular cross-section and a circular cross-section. As an example, a non-circular cross-section of a conduit may be along a portion of an axial length of a conduit, which may be adjacent to a power cable connector of an ESP.

[0054] As an example, an ESP system can include a jumper disposed at an end of the conduit to couple the conduit to another conduit. As an example, a conduit may be a fluid conduit (e.g., for liquid, gas, multiphase, etc., optionally including solid(s)).

[0055] As an example, an ESP system can include an inlet for a pump where a conduit extends to at least the inlet. As an example, a conduit may include an arced wall (e.g., in cross-section at an axial position at a point along an axial length).

[0056] As an example, a conduit can include an arc section of an annulus (e.g., in cross-section). As an example, an axial length of a conduit may be defined along a z dimension and a cross-sectional area of a non-circular cross-section of the conduit may be determined by the following equation: I x w, where I is a length and where w is a width. As an example, a cross-sectional area of a non-circular cross- section may be determined by the following equation: n(r₀ ² - n²)*f where r₀ is an outer radius, η is an inner radius and f is a factor representing an angular span that is less than 360 degrees.

[0057] As an example, a conduit that includes a non-circular cross-section may be positioned to avoid direct contact with a cable of a ESP, for example, to avoid contact with one or more MLEs, a communication cable (e.g., for a remote sensor), etc.

[0058] As an example, one or more methods described herein may include associated computer-readable storage media (CRM) blocks. Such blocks can include instructions suitable for execution by one or more processors (or cores) to instruct a computing device or system to perform one or more actions.

[0059] According to an embodiment, one or more computer-readable media may include computer-executable instructions to instruct a computing system to output information for controlling a process. For example, such instructions may provide for output to sensing process, an injection process, drilling process, an extraction process, an extrusion process, a pumping process, a heating process, etc.

[0060] Fig. 8 shows components of a computing system 800 and a networked system 81 0. The system 800 includes one or more processors 802, memory and/or storage components 804, one or more input and/or output devices 806 and a bus 808. According to an embodiment, instructions may be stored in one or more computer-readable media (e.g., memory/storage components 804). Such

instructions may be read by one or more processors (e.g., the processor(s) 802) via a communication bus (e.g., the bus 808), which may be wired or wireless. The one or more processors may execute such instructions to implement (wholly or in part) one or more attributes (e.g., as part of a method). A user may view output from and interact with a process via an I/O device (e.g., the device 806). According to an embodiment, a computer-readable medium may be a storage component such as a physical memory storage device, for example, a chip, a chip on a package, a memory card, etc.

[0061 ] According to an embodiment, components may be distributed, such as in the network system 810. The network system 810 includes components 822-1 , 822-2, 822-3, . . . 822-N. For example, the components 822-1 may include the processor(s) 802 while the component(s) 822-3 may include memory accessible by the processor(s) 802. Further, the component(s) 802-2 may include an I/O device for display and optionally interaction with a method. The network may be or include the Internet, an intranet, a cellular network, a satellite network, etc.

Conclusion

[0062] Although only a few examples have been described in detail above, those skilled in the art will readily appreciate that many modifications are possible in the examples. Accordingly, all such modifications are intended to be included within the scope of this disclosure as defined in the following claims. In the claims, means- plus-function clauses are intended to cover the structures described herein as performing the recited function and not only structural equivalents, but also equivalent structures. Thus, although a nail and a screw may not be structural equivalents in that a nail employs a cylindrical surface to secure wooden parts together, whereas a screw employs a helical surface, in the environment of fastening wooden parts, a nail and a screw may be equivalent structures. It is the express intention of the applicant not to invoke 35 U.S.C. § 1 12, paragraph 6 for any limitations of any of the claims herein, except for those in which the claim expressly uses the words "means for" together with an associated function.

Claims

CLAIMS What is claimed is:

1 . An electric submersible pump (ESP) system comprising:

a shaft that comprises a shaft axis;

a power cable connector;

an electric motor configured to receive power via the power cable connector for rotatably driving the shaft;

a pump operatively coupled to the shaft; and

a conduit coupled directly or indirectly to the pump or the electric motor wherein the conduit comprises an axial length and at least one non-circular cross- section.

2. The ESP system of claim 1 wherein the non-circular cross-section comprises a rectangular cross-section.

3. The ESP system of claim 1 wherein the conduit comprises a circular cross- section.

4. The ESP system of claim 1 wherein the non-circular cross-section of the conduit is along a portion of the axial length adjacent to the power cable connector.

5. The ESP system of claim 1 further comprising a jumper disposed at an end of the conduit to couple the conduit to another conduit.

6. The ESP system of claim 1 wherein the conduit is a fluid conduit.

7. The ESP system of claim 1 comprising an inlet for the pump wherein the conduit extends to at least the inlet.

8. The ESP system of claim 1 wherein the conduit comprises an arced wall.

9. The ESP system of claim 1 wherein the conduit comprises an arc section of an annulus.

10. The ESP system of claim 1 wherein the axial length of the conduit is defined along a z dimension and wherein the cross-sectional area of the non-circular cross- section is determined by the following equation: I x w, where I is a length and where w is a width.

1 1 . The ESP system of claim 1 wherein the cross-sectional area of the non- circular cross-section is determined by the following equation: n(r₀ ² - n²)*f where r₀ is an outer radius, η is an inner radius and f is a factor representing an angular span that is less than 360 degrees.