Abstract: An artificial lift assembly and method relating thereto where a sleeve system is disposed above an electrical submersible pump. The sleeve system has a sliding sleeve at least partially carried within a ported case. The sliding sleeve blocks fluid flow through ports in the ported case. The sliding sleeve is restricted from movement relative to the ported case until a first predetermined pressure is applied to the sliding sleeve. Subsequent to the operating the electrical submersible pump, a plug is introduced to the sliding sleeve so as to block fluid flow through the sliding sleeve, Subsequent to introducing the plug, fluid pressure above the plug is increased until the sliding sleeve moves relative to the ported case such that fluid flow is allowed through the ports. Thereafter removing the artificial lift assembly from the wellbore.

Abstract: An electrical submersible pump assembly (ESP) has a centrifugal production pump with production pump stages. A gas separator upstream is from the production pump. A centrifugal charge pump is upstream from the gas separator. The charge pump has charge pump stages and a discharge that leads to an intake of the gas separator. Each of the production pump stages has a higher lifting capacity than each of the charge pump stages. The impellers of the production pump stages have vane exit angles greater than vane exit angles of the impellers of the charge pump stages.

Abstract: An artificial lift assembly and method relating thereto is designed to prevent inadvertent electrical discharge caused by fluids flowing through an electrical submersible pumping system, which is part of the assembly. The assembly uses a rupture disc to prevent fluid flow during introduction of the assembly into a wellbore and a dart and sleeve to prevent fluid flow during removal of the assembly from the wellbore.

Abstract: Systems and methods for controlling downhole linear motors to minimize connections to surface equipment. In one embodiment, an ESP system is coupled by a power cable to equipment at the surface of a well. The ESP system includes a linear motor and a reciprocating pump. The motor has a set of position sensors that sense the position of a mover in the motor. Combining circuitry (E.G., XOR gate) combines the outputs of the position sensors into a single composite signal in which signal components corresponding to the position sensors are indistinguishable. A single channel carries the composite signal from the ESP system to the surface equipment. A control system determines a starting position of the motor and determines its subsequent position based on transitions in the composite signal. The motor is then operated based on the position determined from the composite signal.

Abstract: Systems and methods for controlling downhole linear motors to minimize connections to surface equipment. In one embodiment, an ESP system is coupled by a power cable to equipment at the surface of a well. The ESP system includes a linear motor and a reciprocating pump. The motor has a set of position sensors that sense the position of a mover in the motor. Combining circuitry (E.G., XOR gate) combines the outputs of the position sensors into a single composite signal in which signal components corresponding to the position sensors are indistinguishable. A single channel carries the composite signal from the ESP system to the surface equipment. A control system determines a starting position of the motor and determines its subsequent position based on transitions in the composite signal. The motor is then operated based on the position determined from the composite signal.

Abstract: An apparatus and associated method is disclosed for a riser hanging system. The apparatus includes a first elongated member with a provision for a first external mechanical coupling at a distal location on the first elongated member. A second elongated member is mechanically coupled to the first elongated member at proximal locations on the first elongated member and the second elongated member. A third member is mechanically coupled to a first portion of the first elongated member. The third member includes a fourth member to move through at least a second portion of a length of the second elongated member. Mechanical couplers associated with the second elongated member are provided for a second external mechanical coupling of the riser to the apparatus. The riser may be hoisted using the apparatus for better control during coupling to the wellhead.

Abstract: A method of producing fluid from a wellbore includes operating a pump located proximate to a zone of fluid influx in the wellbore to draw a fluid from a reservoir into the wellbore at the zone of fluid influx. A first section of a tubing string is coupled to, and extends above, the pump, and a second section of the tubing string is coupled to, and extends below, the pump. A packer seals a first annular space around the first section of the tubing string. The method further includes operating the pump to move the fluid from the second section of the tubing string and into the first section of the tubing string.

Abstract: An artificial lift assembly and method relating thereto is designed to prevent inadvertent electrical discharge caused by fluids flowing through an electrical submersible pumping system, which is part of the assembly. The assembly uses a rupture disc to prevent fluid flow during introduction of the assembly into a wellbore and a dart and sleeve to prevent fluid flow during removal of the assembly from the wellbore.

Abstract: A gas separator operationally coupled between a submersible pump and a motor for use in downhole reservoirs includes an intake housing and an inner intake assembly. The intake housing includes at least two sets of intake ports along an upper section adjacent to the pump with ports in a set vertically offset and sets horizontally offset. The inner intake assembly includes a separation chamber, a self-orienting intake rotatable around a central axis and having at least one communication port, and a port controller. The port controller functions to position the communications port toward the bottom of the gas separator when the gas separator is positioned horizontally in a downhole wellbore. The intake housing allows reservoir fluid traveling downstream to pass through intake ports and into the separation chamber through the communication ports.

Abstract: A downhole flow control device comprises a body locatable within a wall of a tubular, wherein the body defines a flow path therethrough to accommodate flow in reverse first and second directions between internal and external locations of the tubular in use. The downhole flow control device further comprises a regulator member mounted within the body and being moveable between first and second positions in accordance with flow direction through the body. The regulator member is locatable in the first position during flow through the body in the first direction to provide a first restriction to flow. The regulator member is locatable in the second position during flow through the body in the second direction to provide a second restriction to flow.

Abstract: A header with associated lubricator is for fluid handling at the wellhead of an oil and gas well where a plunger/lubricator lift system is deployed, and provides a novel compact lubricator with attached header which can replace a conventional wellhead flow-tee without modifying or moving other wellhead equipment to accommodate the new lubricator and header replacing the old flow-tee. A sub seal is provided at the header/lubricator attachment(s). The header with associated lubricator encloses a conduit with seals in the attachment interfaces between the header and lubricator or between the header and exit attachment means, where the conduit may also comprise a means of flow restriction through machined geometry or by retaining a reduced diameter or valve component through various means of attachment. The flow restrictor means may also be serviced via service access means provided in the header or lubricator exterior wall.

Abstract: The disclosure provides a method for sampling groundwater. The method includes extracting groundwater from a monitoring well in a first flow rate; monitoring groundwater level in real-time, and calculating a decrease of the groundwater level during the extracting in the first flow rate based on the real-time monitored groundwater level; when the decrease of the groundwater level is equal to a first value, extracting groundwater from the monitoring well in a second flow rate, the second flow rate being smaller than the first flow rate; and when the groundwater level is in an equilibration state, extracting groundwater from the monitoring well and using the extracted groundwater at this time as a representative groundwater.

Abstract: An apparatus and method for pressure testing a tubing string of a fluid production well, the tubing string being provided with a progressing cavity pump at a downhole end, which apparatus and method can be used to help determine whether the tubing string has failed or the pump has failed. The apparatus comprises a plug member connected to the rod string assembly that includes the pump rotor, such that the rod string assembly can be lowered to seat the plug member in a seat member within the tubing string above the pump, thus sealing off and isolating the pump from the rest of the tubing string, allowing pressure testing of the tubing string above the pump.

Abstract: A method includes positioning a downhole acquisition tool in a wellbore in a geological formation. The method includes operating a pump module to gather information for a fluid outside of the downhole acquisition tool that enters the downhole acquisition tool from a first flowline, a second flowline, or both while the downhole acquisition tool is within the wellbore. Operating the pump module includes controlling a valve assembly to a first valve configuration that enables the fluid to flow into the downhole tool via the first flowline fluidly coupled to a first pump module.

Abstract: A method for hydraulically fracturing a subterranean formation includes sending a first command from a controller to a pump to achieve a first target flow rate for a fracturing fluid being injected into a subterranean formation during a fracturing operation. Monitoring an injection property of the fracturing operation. Determining a rate of change of the pressure over a first time period. Determining, by the controller, a second target flow rate based, at least in part, on the rate of change of the pressure. Sending a second command from the controller to the pump to achieve the second target flow rate for the fracturing fluid.

Abstract: Aspects of the present disclosure relate to apparatus and methods for regulating flow from a geological formation, and associated components thereof. In one implementation, an apparatus for regulating a multi-phase fluid stream flowing from a subterranean geological formation includes a conduit. The conduit includes an outer wall, a primary flow path for a fluid stream, and a first restriction having a throat portion. A first return path includes a return channel, and the return channel is fluidly connected to the primary flow path through a return inlet and a return outlet. The apparatus includes a gas siphon port formed in the outer wall of the conduit, and a gas siphon path extending from the conduit. The gas siphon path is fluidly connected to the gas siphon port.

Abstract: Downhole vibratory tools that use fluid flow to reciprocate a rotor in a vibration chamber and associated methods and processes. In a first illustrative embodiment, an elongated external housing allows connection to a drillstring, behind a downhole drill. From a top sub, fluid flows through a first flow plate and spiral flow chamber to enter a central vibration chamber in a spiral direction and exits the vibration chamber through a counterpart second flow plate and spiral flow chamber. A rotor is disposed in the vibration chamber. The spiral flow through the vibration chamber causes the rotor to reciprocate around the vibration chamber, thereby creating vibrations that are transmitted to the drillstring. Methods of use include deploying the vibration tool to improve rates of penetration and enhances reach by creating resonance vibrations against the wall of a wellbore to effectively break static friction.

Abstract: Apparatus and methods for pressurizing well operations fluids. An example apparatus may include a plurality of pressure exchangers each operable to receive a first fluid via a low-pressure inlet, receive a second fluid via a high-pressure inlet to thereby pressurize and then discharge the first fluid via a high-pressure outlet, and discharge the clean fluid via a low-pressure outlet. The apparatus may further include a fluid control device fluidly connected with the pressure exchangers downstream from the low-pressure outlets. The fluid control device may be a pump operable to draw the clean fluid discharged via the low-pressure outlets and thereby reduce the pressure at the low-pressure outlets and the low-pressure inlets.

Abstract: A supersonic vacuum generator device for oil wells including: a cylindrical chamber; a suction device; a central accelerator core inside the cylindrical chamber; a tubular chamber connected to the cylindrical chamber, the tubular chamber including an internal fluid feed space; a concentric accelerator core inside the tubular chamber and connected to the central accelerator core, the concentric accelerator core includes a central vacuum tube having a cylindrical shape with a fluid accumulation chamber; a conical section connected to the fluid accumulation chamber and to a reduced diameter fluid passage that diverges with an angle range between 3.5 to 9 degrees with respect to a center line of the fluid passage; a one-way valve located on each one of the inlets of the central accelerator core; and a one-way valve located on the central vacuum tube.

Abstract: An electrical submersible pump (ESP) and method for pumping fluid from a wellbore. The ESP has a motorized pump with an external rotor motor topology. The motorized pump fits into casing in the wellbore. The motorized pump includes a motor having a motor stator and a motor rotor. The motor stator is at a radial center of the motorized pump. The motorized pump has a centrifugal pump radially surrounding the motor stator. The centrifugal pump includes an impeller and a diffuser.

Abstract: A method of investigating an earth formation. A tool having a pressure sensor is used in a borehole to collect formation fluid pressure data over time. A pressure derivative curve is generated from the formation fluid pressure data by conducting a piecewise linear regression of the data having optimal window length values L determined by calculating a derivative with respect to L of a pressure derivative value (DD), and selecting values of L where DD has a transition that departs from oscillatory behavior to gradual change. The pressure derivative is calculated with piecewise linear regression with the optimal window length values 2L. Different L values are generated for different groups of data points obtained over time. The pressure derivative is then used for flow regime determination.

Abstract: A bypass plunger includes a plunger body that includes a head portion located at one end of the plunger body and a tail portion located at an opposite end of the plunger body. The head portion includes at least one flow port, and the tail portion includes at least one passageway. A valve component is disposed within an internal bore of the plunger body and is moveable between an open position and a closed position. At least one plug is located within a respective one of the flow ports and/or a respective one of the passageways, and is configured to reduce or prevent flow through the respective flow port or the respective passageway.

Abstract: A horizontal gas and liquid bypass separator for use in a hydrocarbon producing well bore is provided for allowing gas to bypass over the top of a pump intake in a horizontal portion of a well bore. The separator includes at least one valve having a body, a conduit extending longitudinally through the body, a channel extending transversely through the body from an outer surface of the body to the conduit, and a plunger positioned within the conduit. The plunger is translatable within the channel to selectively seal the conduit relative to the channel to thereby inhibit gas from entering the conduit when the plunger is translated to a closed position and to allow liquid to flow within the conduit when the plunger is translated to an open position.

Abstract: An artificial lift system is provided for use for pumping fluid from a downhole wellbore to surface. The system comprises a progressive cavity pump, said progressive cavity pump comprising a stator run on a tubing string and a rotor run on a rod string into the stator and a shuttle valve positioned upstream of the progressive cavity pump, wherein said shuttle valve comprises a non-weighted shuttle and wherein said non-weighted shuttle is moveable axially within said shuttle valve from force of fluid alone. An upstream shuttle valve is further provided for use upstream of a progressive cavity pump, wherein said shuttle valve comprises a non-weighted shuttle that is moveable axially within said shuttle valve from a force of fluid alone, to open and close the shuttle valve. A method is further still provided for pumping fluid from a wellbore in an artificial lifts system.

Abstract: A well has a wellbore extending from a surface. Tubing extends within the wellbore for supporting a downhole pump. Sucker rods extend within the tubing for reciprocating a travelling valve. A load calculator determines loading on the sucker rods during a pump cycle. A variable speed driver reciprocates the sucker rods and travelling valve. A real time speed controller varies a speed of the driver in response to loading information from the load calculator for smoothing the rod load in a beam pump cycle. A target rod load is obtained and a surface linear speed of rods is varied by either slowing or speeding a driver for varying a surface linear speed of the rods when rod loading is above or below the target rod load.

Abstract: A jet pump, a jet pump data tool system, and method of use thereof. The jet pump includes a body having an intake, a first aperture, and a second aperture between the first aperture and the intake. A carrier is seated in the body and receivable in the first aperture. The carrier includes a venturi for drawing wellbore fluid from the intake into the venturi. A housing for a data tool extends from the carrier. The housing is in fluid communication with the intake for allowing wellbore fluid to be exposed to the data tool. The carrier is seatable in the body by flowing power fluid and the carrier into the first aperture. The carrier is retrievable from the body by flowing power fluid into the second aperture.

Abstract: An automatic clutch device includes an axial force generating mechanism formed by an electric motor adjacent to the outer periphery of an end of an input shaft of a transmission, and a rotation-linear motion conversion mechanism for converting the rotation of the rotor of the electric motor to a linear motion of a release bearing. The rotation-linear motion conversion mechanism includes plural tubes having different diameters and slidably fitted one in another to form a telescopic tube assembly on the input shaft; and cam mechanisms each disposed between a respective opposed pair of the tubes for converting the rotation of the larger-diameter one of the pair of tubes to a linear motion of the smaller-diameter one of the pair.

Abstract: A device is taught for pumping fluid from a downhole reservoir up to surface. The device comprises a conduit extending through at least a portion an axial bore of the rotor unit and in communication with one or more recirculation inlets for receiving a recirculation stream of fluid and directing under pressure through the conduit, wherein an inside diameter and length of the conduit define a flow restriction; and one or more recirculation outlets defined in a stator unit downstream of the pump fluid intake, for delivering the recirculation stream of the fluid under pressure from the conduit and directing it at the pump fluid intake. A method is also taught for washing particulate from an intake end of a pump.

Abstract: A plunger lift method can include introducing a plunger sleeve and a plunger closure into a well, engaging the sleeve with the closure, securing the sleeve and closure to each other in a flow passage of the well, and then retrieving the sleeve and closure from the well. A plunger lift system can include a plunger sleeve configured for reciprocal displacement in a flow passage of the well, a plunger closure configured to block flow through a flow path of the sleeve and being displaceable in the flow passage separate from the sleeve. A plunger retrieval device may displace with the sleeve in the flow passage and secure the closure against displacement away from the sleeve. Another plunger retrieval device may be positioned in a lubricator, whereby the plunger retrieval device engages the closure and secures the closure against displacement away from the sleeve in the lubricator.

Abstract: A method and system for servicing a well. Servicing a well often includes running a service string into a production string, which may include a rod string. A service portion is provided in the production string during completion. The service portion is located at or uphole of a large rod string feature. The service portion has a greater inside diameter than production tubing and other standard production string components. The service portion provides sufficient clearance for the service string alongside the large feature. The large feature may be, for example, a PCP stator, a centralizer, or a rod collar. The large feature may be pulled uphole into the service portion prior to running in the service string, allowing servicing downhole of the large feature without pulling the entire rod string. The service portion may also mitigate rod wear in deviated or other portions of the well.

Abstract: A downhole isolation tool for insertion in a wellbore and seated engagement to a downhole assembly, for allowing, when a sliding sleeve thereof is slidably positioned in a first position and when coupled to a lower end of said pump apparatus, fluids within a hydrocarbon formation to be drawn through such tool and allowed to pass to the pump apparatus for pumping uphole, and when such sliding sleeve is positioned in a second position and decoupled from said lower end of the pump assembly, for preventing said fluids from passing therethrough and uphole.

Abstract: A technique facilitates construction of a sealed electrical connector, e.g. sealed pothead assembly. Depending on the application, the electrical connector may be used to connect a power cable and a powered component such as an electric submersible pumping system. The electrical connector comprises at least one connector component and at least one electrical component. An injection molding process is used to construct an injection molded feature sealed to a corresponding component, e.g. to the at least one electrical component. The injection molded feature is readily formed and located between the at least one electrical component and the at least one connector component to form a simple and reliable seal which prevents unwanted passage of fluids.

Abstract: In a stator injection molding centralization technique, a mold core is disposed inside a stator tube, thereby forming an annulus between the stator tube and mold core. The mold core includes a pitch length defined between a first and second lobe tip of the mold core. A centralizing member is positioned in the annulus, which has a length at least as long as the pitch length of the mold core. During the injection molding process, elastomeric material is injected into the annulus behind the centralizing member, which is located adjacent to the injection point. As the elastomer is injected, it displaces the centralizing member ahead of it along the annulus. As the centralizing member moves through the annulus, it supports the mold core, thus preventing the sag effect.

Abstract: A separator for separating gas from a liquid mixture in a production stream of a well. The separator includes an outer tube and an inner tube positioned concentrically with the outer tube. The production stream is directed through the outer tube where gas in the production stream can separate from liquid in the production stream. The separated liquid is then directed through the inner tube to a pump. The separated gas is directed through a gas bypass to an area above a fluid intake for the pump.

Abstract: A bypass plunger includes a plunger body that includes a head portion located at one end of the plunger body and a tail portion located at an opposite end of the plunger body. The head portion includes at least one flow port, and the tail portion includes at least one passageway. A valve component is disposed within an internal bore of the plunger body and is movable between an open position and a closed position. At least one plug is located within a respective one of the flow ports and/or a respective one of the passageways, and is configured to reduce or prevent flow through the respective flow port or the respective passageway.

Abstract: A top-drive system and a drilling rig. The top-drive system includes a sheave configured to receive a drilling line, a frame coupled with the sheave and configured to transmit a weight of a tubular string suspended therefrom to the sheave, a controller, and a sensor in communication with the controller. The sensor is configured to directly measure one or more physical parameters of a drilling operation and provide data representing the one or more physical parameters to the controller.

Abstract: A manifold trailer and pairing system are disclosed. Methods may include pressurizing a low pressure manifold of a manifold trailer, the low pressure manifold having a first low pressure valve and a second low pressure valve; opening a selected low pressure valve of the first and second low pressure valves; detecting a first pressure on a selected pump, via a first pressure sensor, indicative of a fluid communication between the selected low pressure valve and the selected pump; detecting a second pressure associated with a main line or a wellhead; comparing the first pressure on the selected pump to the second pressure associated with the main line or the wellhead to derive a pressure differential; and engaging the selected pump if the pressure differential is within a given threshold.

Abstract: The invention relates to an artificial lifting system comprising a progressive cavity motor for hydrocarbon's extraction. In the invention's system a pump injects a fluid stored in the surface to the progressive cavity motor, located in the basement; the rotation that occurs by the passage of fluid is transmitted to a progressive cavity pump such that the hydrocarbon is pushed toward the surface.

Abstract: A piston rod and piston head are the driven components within a pump. An upstream end of the piston rod is attached within an aperture of the piston head. At least one flute extends between the upstream end of the piston rod and the aperture, and the at least one flute is configured to provide a flowpath for a fluid, such as paint, to flow downstream of the piston head and piston rod. The flutes facilitate a smooth downstream flow of the fluid, thereby reducing hydraulic resistance and reducing wear caused by the fluid.

Abstract: In order to address the above noted problems, embodiments of the present invention use distributed acoustic sensing to monitor the fluid level in an ESP activated well so as to monitor the condition and performance of the ESP. Embodiments of the invention use the ESP as an acoustic source in order to monitor the annulus fluid level within the well and to monitor the frequency of the ESP. Additionally, embodiments of the present invention may use distributed acoustic sensing to monitor the flow rates of the production fluid above and below the ESP to determine the pump's efficiency. In particular, some embodiments utilize one or more optical fibers to measure the acoustic waves generated by the ESP, wherein the fiber cabling has already been deployed along the length of the well. As such, the present invention is a non-invasive, in-situ method for monitoring the condition and performance of an ESP.

Abstract: Sucker rods include end fittings having an outer wedge portion proximate to an open end, an inner wedge portion proximate to a closed end, and an intermediate wedge portion between the outer and inner wedges. Each wedge includes a leading edge, a trailing edge, and an angle between the leading and trailing edges. The triangular configuration, length of the leading edge, the length of the trailing edge, and size of the angle in each wedge portion cause distribution of force, such that compressive forces distributed to the rod proximate the closed end exceed compressive forces distributed to the rod proximate the open end.

Abstract: A plunger for oil and gas wells includes a shaft and a sleeve carried by the shaft. The sleeve defines a passageway located between a surface of the sleeve and a portion of the shaft, and the sleeve is longitudinally translatable relative to the shaft from a first configuration to a second configuration and vice versa. In the first configuration the plunger inhibits fluid flow through the passageway, and in the second configuration the plunger permits fluid flow through the passageway. The plunger further includes a force dissipating element interposed between the shaft and the sleeve. The force dissipating element at least partially dissipates forces caused by at least one of (1) the sleeve stopping relative to the shaft after translating from the first configuration to the second configuration; and (2) the sleeve stopping relative to the shaft after translating from the second configuration to the first configuration.

Abstract: A material detection and sealing device includes a body comprising a bottom end and a top end, and configured to fit within a casing string. The device includes a valve located within the body configured to open and close an orifice formed through the body. The device also includes a density meter located on or within the body configured to continuously sense the density of a neighboring fluid. The valve is configured to close upon the density meter sensing a certain density condition.

Abstract: An assembly for circulating tool fluid of a downhole tool includes a tool fluid source line extending into a subterranean well from a wellhead spool assembly to the downhole tool. A tool fluid return line extends out of the subterranean well from the downhole tool to the wellhead spool assembly. A tool fluid reservoir is located at a surface outside of the subterranean well. The tool fluid source line is in one way fluid communication with the tool fluid reservoir and the tool fluid is free of fluid communication with wellbore fluids.

Abstract: A downhole tool configured to pass through a narrowed diameter, the downhole tool having a mandrel made of a composite material; a fingered member disposed around the mandrel; a first cone disposed around the mandrel; a fingered bearing plate disposed around the mandrel; and a fingered lower sleeve disposed around and coupled to the mandrel.

Abstract: A hydraulically-retrievable, reversible flow operation jet pump threadably attached to a tubing string which is powered by fluid supplied through the tubing string. A pump housing, or container, of the jet pump includes a hollow cylinder with an internal diameter closely matching that of the attached tubing string. A jet pump assembly is retainably, scalably disposed within the pump housing. A jet pump reducing nozzle-mixing chamber-diffuser assembly is retainably disposed within the carrier. Power fluid pumped through the nozzle-mixing chamber-diffuser assembly conventionally draws in objective fluid in which the jet pump is immersed, and transports it out of the pump to the desired receiving station. The jet pump assembly can be oriented in either of two directions within the pump housing, for selected fluid direction flow.

Abstract: A method of fluid sampling and device thereof, the device and method enabling the user to safely and efficiently collect fluid samples, including groundwater samples from a monitoring well, by providing a fluid sampling device that includes a container having a sampling surface and tube housing that securely holds tubing, sample containers, and other equipment and provides a drainage area so that the user may focus on collecting unadulterated samples while any fluid discharges and incidental spillage are safely captured in the container.

Abstract: A bypass plunger combines a unitary or one-piece hollow body-and-valve cage, retains a dart valve within the valve cage portion of the hollow body using a threaded retaining nut secured by crimple detents. A series of helical grooves surround the central portion of the outer surface of the hollow body of the plunger to control spin during descent. A canted-coil-spring disposed within the retaining nut functions as a clutch. The valve cage includes ports that may be configured to control flow through the plunger during ascent. Other embodiments include clutch assemblies using canted-coil springs with split bobbins, and valve stems surfaced to achieve specific functions. Combinations of these features provide enhanced performance, durability and reliability at reduced manufacturing cost, due primarily to the simplicity of its design.

Abstract: Systems and methods for operating a linear motor (e.g., for an ESP), where the motor's mover moves in a reciprocating motion within a bore of the stator. Hard stops are located at the ends of the bore. The motor has a first set of sensors in the stator positioned proximate to the bore. When the mover moves in the bore, the sensors produce corresponding output signals, except when the mover is in a position near, but not in contact with a hard stop. While the sensors produce output signals, the motor is driven in a first direction toward the hard stop. When the sensors stop producing the output signals, the mover has reached the first position, and the motor is controlled to reverse the direction of the mover.

Abstract: A pipe adapter includes a first tubular element, a second tubular element, and an annular securing member disposed around and fixed to a second portion of the first tubular element. The annular securing member has a flange portion that contacts and secures the second tubular element axially relative to the first tubular element while also allowing the second tubular element to rotate relative to the first tubular element and the annular securing member. An annular sealing member is located around the first portion of the second tubular element to provide an axial seal along the adapter.