Abstract: An electric submersible pump (ESP) with reduced vibration is provided. In an implementation, an ESP section has radial bearings placed at shaft locations of reduced vibration to reduce wear. The locations of reduced vibration are selected to avoid areas of high vibration and vibrational waves that reinforce each other due to structure resonance and natural excitation frequencies. In an implementation, a radial bearing is positioned at a node of reduced vibration of a standing vibrational wave. In an implementation, a succession of multiple radial bearings are spaced at different intervals from each other to avoid conventional even spacing of the bearings that causes standing waves, resonance waves, and vibrational waves at natural excitation frequencies. In an implementation, a span between adjacent radial bearings is selected to spare other adjacent bearings at different spans the effects of vibrations that may extend over a range of excitation frequencies in the ESP section.

Abstract: An electric submersible pump system can include a shaft; at least one impeller operatively coupled to the shaft; and a bearing assembly that rotatably supports the shaft, where at least one component of the electric submersible pump includes a volumetric composite material that includes polycrystalline diamond material and at least one metallic material.

Abstract: A mixed-flow impeller for an electric submersible pump can include a lower end and an upper end; a hub that includes a through bore that defines an axis; blades that extend at least in part radially outward from the hub where each of the blades includes a leading edge and a trailing edge; an upper balance ring that includes a radially inward facing balance chamber surface and a radially outward facing diffuser clearance surface; and an upper guard ring disposed radially outwardly from the upper balance ring where the upper guard ring includes an axially facing diffuser clearance surface that is disposed axially between the trailing edges of the blades and the upper end.

Abstract: A technique facilitates operation of a pump, such as a submersible pump in an electric submersible pumping system. The pump has a sequential diffuser and impeller which are operationally engaged via a thrust device. In some embodiments, the diffuser and impeller also are operationally engaged via a front seal. A bypass channel is used to route a flow of fluid from a tip region of the impeller to an inlet region of the impeller without passing through the thrust device during operation of the pump.

Abstract: Apparatus and methods for performing subsea drilling operations. An example method may include receiving drilling fluid from a drilling fluid source at a first pressure by a pressure exchanger located within a subsea environment and receiving seawater from the subsea environment at a second pressure by the pressure exchanger to increase pressure of the drilling fluid within the pressure exchanger to a third pressure. The second and third pressures are substantially greater than the first pressure. The method may further include discharging the drilling fluid from the pressure exchanger into piping to communicate the drilling fluid to a drill forming a wellbore in a seabed and discharging the seawater from the pressure exchanger into the subsea environment.

Abstract: A technique employs a system and methodology for improving sand control in pumps. The technique may be used in centrifugal pumps by providing uniquely constructed rib feature to facilitate sand control and thus reduction of erosion due to sand in the pumped fluid. The improved sand control is useful in centrifugal pumps employed in a variety of oilfield applications, such as in electric submersible pumping systems positioned downhole in a wellbore to pump oil or other fluids. The rib feature may be used in combination with a shield and arranged along diffuser bowl walls or other diffuser walls within sequential pump stages.

Abstract: A technique facilitates formulation of predictions regarding the run life of a pumping system. Based on the predicted run life, and factors affecting that predicted run life, corrective actions may be selected and implemented. The corrective actions may involve adjustment of operational parameters regarding the pumping system so as to prolong the actual run life of the pumping system. The technique utilizes an algorithm which combines various models, e.g. physical models and degradation models, to provide various failure/run life predictions. The various models may utilize a variety of sensor data, such as actual sensor data and virtual sensor data, to both evaluate the state of the pumping system and the predicted nm life of the pumping system.

Abstract: A centrifugal pump stage with increased compressive load capacity is provided. In an implementation, a centrifugal pump stage includes a diffuser with outside wall capable of supporting increased axial forces. A mating surface of the outer wall can support axial forces generated by a stack of subsequent pump stages across the entire thickness of the outer wall. The diffuser can be a two-piece assembly including a load bearing module and a flow diffusing module. The load bearing module may be a cylinder of strong tubular alloy while the flow diffusing module can be separately cast in a manner that improves hydraulic efficiency. Various means for radially positioning the pump stages relieve the load bearing module from the task of aligning additional pump stages. A single rigid tube may also be used as the load bearing module for multiple pump stages. The tube may be made with a thin wall to increase pump volume.

Abstract: An electric submersible pump (ESP) can include a shaft; an electric motor configured to rotatably drive the shaft; a housing; a stack of diffusers disposed in the housing; and impellers operatively coupled to the shaft. Various other apparatuses, systems, methods, etc., are also disclosed.

Abstract: Wear rings for electric submersible pump (ESP) stages are provided. An example ESP has one or more running clearance seals reinforced with high-hardness wear rings. Ceramics and carbides may provide the high hardness for the wear rings, but such substances are more brittle than metals and have different coefficients of thermal expansion than metals. For protection, each high-hardness wear ring may be mounted with an elastic cushioning scheme. The elastic mounting preserves each wear ring from shock, stress, and breakage from thermal expansion and contraction of an adjacent pump part. Each high-hardness wear ring may also have a low-stress driving mechanism that cushions the rotational force imparted to the wear ring when the ESP pump is being powered. In some implementations, the elastic mounting scheme may also serve as the low-stress driving mechanism for the high-hardness wear ring.

Abstract: A submersible pump housing with seal bleed ports is provided. In an implementation, a pump housing for electric submersible pumps (ESPs), such as a centrifugal ESP, has end seals that are located inside or further inboard toward the high thrust pressure generated by the pump, than the threaded ends of the pump housing. The inboard seals contain and seal off the pump pressure and spare the threaded regions that are more pressure-vulnerable from the pump's high pressure interior, thereby increasing the pressure rating of the entire housing. Leak ports or bleed ports are provided further outboard of the end seals to relieve fluid seeping from inside the submersible pump housing past each end seal. A plate may be added to direct small amounts of fluid escaping from the end seals away from the wellbore casing in which an ESP is situated.

Abstract: Inflatable packers are provided with one or more components to improve longevity and/or functionality. One or more of the packer components utilizes reinforced materials incorporated in a manner that enables the improved longevity and/or functionality.

Abstract: A centrifugal pump stage with increased compressive load capacity is provided. In an implementation, a centrifugal pump stage includes a diffuser with outside wall capable of supporting increased axial forces. A mating surface of the outer wall can support axial forces generated by a stack of subsequent pump stages across the entire thickness of the outer wall. The diffuser can be a two-piece assembly including a load bearing module and a flow diffusing module. The load bearing module may be a cylinder of strong tubular alloy while the flow diffusing module can be separately cast in a manner that improves hydraulic efficiency. Various means for radially positioning the pump stages relieve the load bearing module from the task of aligning additional pump stages. A single rigid tube may also be used as the load bearing module for multiple pump stages. The tube may be made with a thin wall to increase pump volume.

Abstract: A submersible pump can include a male part that includes an outer diameter; a female part that includes an inner diameter; an elastomeric seal element disposed between the male part and the female part; and a non-elastomeric seal element disposed between the male part and the female part. Various other apparatuses, systems, methods, etc., are also disclosed.

Abstract: A submersible pump housing with seal bleed ports is provided. In an implementation, a pump housing for electric submersible pumps (ESPs), such as a centrifugal ESP, has end seals that are located inside or further inboard toward the high thrust pressure generated by the pump, than the threaded ends of the pump housing. The inboard seals contain and seal off the pump pressure and spare the threaded regions that are more pressure-vulnerable from the pump's high pressure interior, thereby increasing the pressure rating of the entire housing. Leak ports or bleed ports are provided further outboard of the end seals to relieve fluid seeping from inside the submersible pump housing past each end seal. A plate may be added to direct small amounts of fluid escaping from the end seals away from the wellbore casing in which an ESP is situated.

Abstract: A technique provides an electric submersible pumping system to facilitate a well treatment, such as a hydraulic fracturing well treatment. The electric submersible pumping system is positioned downhole and oriented to intake a fluid delivered downhole for use in the well treatment. Once the fluid is delivered downhole, the electric submersible pumping system pumps, pressurizes and discharges this fluid to perform the well treatment, e.g. the hydraulic fracturing treatment. The pumping system reduces the pressure at which the treatment fluid must be delivered downhole.

Abstract: A system and methodology facilitate connection between components of an electric submersible pumping system. The technique utilizes at least one connector designed to connect a first component to a second component of an electric submersible pumping system. The connector is designed as a flangeless connector which secures engagement of the two components without relative rotation between the first component and the second component. Additional flangeless connectors may be positioned between other pairs of components to provide the enhanced connection throughout the electric submersible pumping system.

Abstract: A technique provides an electric submersible pumping system to facilitate a well treatment, such as a hydraulic fracturing well treatment. The electric submersible pumping system is positioned downhole and oriented to intake a fluid delivered downhole for use in the well treatment. Once the fluid is delivered downhole, the electric submersible pumping system pumps, pressurizes and discharges this fluid to perform the well treatment, e.g. the hydraulic fracturing treatment. The pumping system reduces the pressure at which the treatment fluid must be delivered downhole.

Abstract: A technique provides an electric submersible pumping system to facilitate a well treatment, such as a hydraulic fracturing well treatment. The electric submersible pumping system is positioned downhole and oriented to intake a fluid delivered downhole for use in the well treatment. Once the fluid is delivered downhole, the electric submersible pumping system pumps, pressurizes and discharges this fluid to perform the well treatment, e.g. the hydraulic fracturing treatment. The pumping system reduces the pressure at which the treatment fluid must be delivered downhole.

Abstract: To perform a cleanout operation in a wellbore, a cleaning tool having a coiled tubing and an electrical pump assembly is run into the wellbore. The electrical pump assembly that is located in the wellbore is activated. In response to fluid flow generated by the electrical pump assembly, removal of debris from the wellbore is caused by directing fluid containing the debris into the coiled tubing for delivery to an earth surface.