Abstract: According to various aspects of the subject technology, a tool collar is provided. The tool collar may include a recessed portion comprising a component segment and a threaded segment, a pressure sleeve covering the recessed portion, and a threaded component mated to the threaded segment and configured to compress the pressure sleeve against a shoulder of a downhole tool. According to some aspects, a downhole tool is provided. The downhole tool may include a recessed portion comprising a component segment and a threaded segment, an unrecessed portion comprising a shoulder, a pressure sleeve covering the recessed portion of the downhole tool, and a threaded component mated to the threaded segment and configured to compress the pressure sleeve against the shoulder of the unrecessed portion.

Abstract: A hydraulic fracturing system includes a support structure having a first area at a first height and a second area at a second height, the first and second areas adjacent one another. The system also includes an electric powered, multi-plunger pump with an odd number of plungers, arranged in the first area, the electric powered pump coupled to a well, via outlet piping, and powered by at least one electric motor, also arranged in the first area. The system further includes a variable frequency drive (VFD), arranged in the second area, connected to the at least one electric motor, the VFD configured to control at least a speed of the at least one electric motor. The system also includes a transformer, arranged in the second area, the transformer positioned within an enclosure with the VFD, the transformer distributing power to the electric pump.

Abstract: An actuator of a downhole tool used in oil and gas exploration and production operations is operable to actuate a first implement in a first direction. A biasing device of the downhole tool is operable to actuate the first implement in a second direction, opposite the first direction. A dampener of the downhole tool is operable to slow an actuation speed of the first implement in the first direction, the second direction, or both. Actuating the first implement in the first direction also actuates a second implement of a flow control device (“FCD”) of the downhole tool, to which the first implement is connected, in the first direction, placing the FCD in a first (e.g., open) configuration. Actuating the first implement in the second direction also actuates the second implement of the FCD in the second direction, placing the FCD in a second (e.g., closed) configuration.

Abstract: Exemplary embodiments of an instantaneously expanding, ballistically actuated wellbore plug and associated systems and methods are disclosed. Exemplary embodiments of an instantaneously expanding, ballistically actuated wellbore plug include, among other things, a ballistic carrier carrying ballistic components and an initiator and housed within a hollow interior chamber of an outer carrier having an unexpanded form and an expanded form. Exemplary embodiments for a method for setting the plug within a wellbore casing include initiating the ballistic components with the initiator and causing the outer carrier to instantaneously transition from the unexpanded form to the expanded form, in which the outer carrier is in frictional, sealing engagement with the wellbore casing.

Abstract: A hydraulic fracturing system includes a turbine generator for producing electricity at a well site, the turbine generator producing electrical energy at a voltage. The system also includes an electric pump electrically coupled to the turbine generator and receiving operative power from the turbine generator. The system further includes switch gear arranged between the electric pump and the turbine generator, the switch gear distributing electrical energy from the turbine generator to the electric pump, wherein the voltage remains substantially constant from the turbine generator to the electric pump.

Abstract: An electrically driven oilfield pumping system may include a compound electro-hydraulic fracturing (frac) pump system that has a primary electric motor that selectively delivers power to one or more of at least two fracturing (frac) pumps. The primary electric motor may be a constant speed alternative current (AC) motor with a fixed rated speed.

Abstract: An electro-hydraulic control system for actuating a control valve includes a control module. The control module is coupled to the surface via two hydraulic lines and an electrical power line. The control module uses one of the hydraulic lines as an open line and the other line as a close line. The control module includes a normally closed (NC) solenoid valve (SOV) that is coupled to the electrical power line and may be controlled from the surface to open or close. The opening or closing of the NC SOV in cooperation with hydraulic pressure on an open or close line operates (i.e., closes or opens) the control valve.

Abstract: A retrievable bridge plug includes a housing that includes a slickline connector; a plurality of wheels coupled to the housing, each wheel adjustable from a retracted position within the housing to an extended position from the housing; a motor assembly within the housing and driveably coupled to the plurality of wheels; a seal coupled to the housing; and a controller configured to operate the motor assembly to move the housing through a wellbore on the plurality of wheels in the extended position in response to a particular force on the housing; and activate the seal to seal the wellbore from fluid circulation there through.

Abstract: Systems, methods, and apparatus are disclosed allowing relative movement between downhole tools while remaining in electrical communication. In one example, a first tool comprising a first connector body is configured for connecting to a second connector body of a second tool. A sliding connector housing has an electrical strip axially arranged along the connector housing, wherein the first or second connector body is moveably secured to the connector housing in sliding electrical contact with the electrical strip. The first and second connector bodies are releasably connectable to each other, thereby allowing relative movement between the first and second tools via the connector housing while maintaining electrical and fluid communication between the first and second tools.

Abstract: A downhole probe can be utilized in a wellbore to accurately determine a relative depth between measurement locations. The downhole probe includes a measurement unit for taking downhole measurements and a detachable anchor that can grip a wellbore wall to maintain a fixed location. The measurement unit may be moved relative to anchor between the measurement locations to unspool a tether coupled between the anchor and the measurement unit. The length of the tether unspooled may provide a more accurate indication of the relative distance between the measurement locations than surface-based measurements. The detachable anchor may be retrieved for deployment at additional measurement locations or may be abandoned in the wellbore.

Abstract: Blending apparatuses and related methods and computer program products are disclosed. In an aspect, blending apparatuses and related methods and computer program products of the present disclosure may include at least one energy source associated with the blending apparatuses such that at least one energy source may be used to provide at least one portion of the energy required for a given blending apparatus to function, thereby reducing or eliminating need for a separate energy source to power the blending apparatus, which reduces the overall spatial footprint required by the blending apparatus and other device(s) associated therewith. Energy generated by the at least one energy source may also be used to power one or more additional devices. Blending apparatuses of the present disclosure may additionally comprise at least one control station that allows one or more users to monitor, adjust, control, interact with the blending apparatuses, thereby increasing efficiency.

Abstract: An electric submersible pump includes a pump, an electric motor that is coupled to the pump by a rotatable shaft, a seal section that is positioned between the pump and the electric motor. The seal section contains an additive and a motor oil for the electric motor. The additive includes one or more superabsorbent polymers or imidate salts to contact the motor oil and to react with a wellbore fluid from a wellbore to prevent premature failure of the electric submersible pump from the wellbore fluid contamination of the motor oil.

Abstract: Apparatus and methods for autonomously shifting a downhole sliding sleeve. A shift tool includes a shifter arm, an artificial neural network, and a control circuit. The artificial neural network is trained to identify engagement of the shifter arm with a shifting feature of a sliding sleeve. The control circuit is configured to extend the shifter arm at a first pressure for seeking engagement with the shifting feature of the sliding sleeve, and responsive to the artificial neural network recognizing engagement of the shifter arm with the shifting feature of the sliding sleeve, extend the shifter arm at a second pressure for shifting the sliding sleeve.

Abstract: Apparatus and methods for autonomously shifting a downhole sliding sleeve. A shift tool includes a shifter arm, an artificial neural network, and a control circuit. The artificial neural network is trained to identify engagement of the shifter arm with a shifting feature of a sliding sleeve. The control circuit is configured to extend the shifter arm at a first pressure for seeking engagement with the shifting feature of the sliding sleeve, and responsive to the artificial neural network recognizing engagement of the shifter arm with the shifting feature of the sliding sleeve, extend the shifter arm at a second pressure for shifting the sliding sleeve.

Abstract: Apparatus and method for passive gas separation in a through-tubing-conveyed (TTC) pump system comprise abruptly reversing a flow direction of wellbore fluids from flowing up the wellbore to down into a liquids reservoir. The generally annular liquids reservoir is formed between a production tubing and a pump of the TTC pump system. Wellbore fluids flowing up the production tubing are diverted into the annulus via one or more outlet ports in the production tubing. The wellbore fluids flow up the annulus until encountering one or more inlet ports in the production tubing, which redirects the wellbore fluids from the annulus down into the liquids reservoir. The reversal of flow direction causes gas in the wellbore fluids to separate from liquids as the gas continues moving up the wellbore instead of changing direction with the liquids. The substantially gas free liquids are then pumped by the pump up to the surface.

Abstract: An electric motor-actuated packer and/or anchor (EMAP/A) apparatus and method for use in downhole operations. The apparatus includes a packer subassembly and/or a slip subassembly and can be: set in a packer and anchor mode; set in an anchor-only mode without energizing the packer elements; repeatedly set and unset without run-in string manipulation; run in a multiple, or redundant, configuration within a given tool string, with each EMAP/A apparatus capable of being set/unset independently of the others; and combined within a tool string in a straddle packer configuration, with inverted and non-inverted EMAP/As providing the ability to isolate an interval of interest from both above and below the interval. Among other uses, the apparatus and method are well suited for application in a single-trip, e-coil conveyed completion system, and particularly one providing for radial hydraulic jetting.

Abstract: A downhole-type device includes an electric machine. The electric machine includes an electrical rotor configured to couple with a device to drive or be driven by the electric machine. An electrical stator surrounds the electric rotor. The electric stator includes a seal configured to isolate stator windings from an outside, downhole environment. An inner surface of the seal and an outer surface of the electric rotor define an annulus exposed to the outside environment. A bearing couples the electric rotor to the electric stator. A lubrication system is fluidically coupled to the downhole-type device. The lubrication system includes a topside pressure pump and a downhole-type distribution manifold configured to be used within a wellbore. The distribution manifold is fluidically connected to the topside pressure pump and the bearing to receive a flow of lubricant from the topside pressure pump.

Abstract: A bottom hole assembly for use in a subterranean well can include a whipstock, a mill releasably secured to the whipstock, an antenna, and a release mechanism configured to release the mill from the whipstock in response to a predetermined radio frequency signal received by the antenna. A method can include positioning a bottom hole assembly in a well, the bottom hole assembly including a mill and a whipstock releasably secured to the mill, and then releasing the mill from the whipstock by displacing a radio frequency identification tag into the bottom hole assembly. A well system can include a bottom hole assembly comprising an anchor, a whipstock and a mill, and a radio frequency identification tag displaceable with fluid flow into the bottom hole assembly.

Abstract: A hydraulic fracturing system includes a turbine generator for producing electricity at a well site, the turbine generator producing electrical energy at a voltage. The system also includes an electric pump electrically coupled to the turbine generator and receiving operative power from the turbine generator. The system further includes switch gear arranged between the electric pump and the turbine generator, the switch gear distributing electrical energy from the turbine generator to the electric pump, wherein the voltage remains substantially constant from the turbine generator to the electric pump.

Abstract: A downhole tool comprises at least one inlet and a first pump coupled to the at least one inlet via a first flow line. The first pump is to pump at a first pump rate to extract fluid via the at least one inlet from a subsurface formation in which a borehole is created and in which the downhole tool is to be positioned. A sample chamber is coupled to the inlet via a second flow line, and a second pump is coupled to the inlet via the second flow line. The second pump is to pump at a second pump rate to extract the fluid via the at least one inlet from the subsurface formation and for storage in the sample chamber. The first pump rate is greater than the second pump rate.

Abstract: A labyrinth section for a submersible pump includes an outer housing having a coupling sealingly engaged at each longitudinal end of the outer housing. An inner tube is sealingly engaged at each end to one of the couplings to define a sealed annular space. A plurality of labyrinth tube sections are disposed in the annular space, each comprising labyrinth tubes engaged with end plates. A plurality of the labyrinth tube sections enable movement of fluid through the labyrinth tubes, spaces external to the labyrinth tubes and between the end plates to fill the annular space. One of the labyrinth tube sections constrains fluid to move only within the labyrinth tubes and wherein the inner tube between the end plates of the one of the labyrinth tubes comprises a fluid port into an interior of the inner tube.

Abstract: A hydraulic fracturing system includes a support structure having a first area at a first height and a second area at a second height, the first and second areas adjacent one another. The system also includes an electric powered, multi-plunger pump with an odd number of plungers, arranged in the first area, the electric powered pump coupled to a well, via outlet piping, and powered by at least one electric motor, also arranged in the first area. The system further includes a variable frequency drive (VFD), arranged in the second area, connected to the at least one electric motor, the VFD configured to control at least a speed of the at least one electric motor. The system also includes a transformer, arranged in the second area, the transformer positioned within an enclosure with the VFD, the transformer distributing power to the electric pump.

Abstract: Downhole flow control valves include a valve assembly, driven gear, drive gear, and motor. The valve assembly includes an outer sleeve and inner sleeve. The outer sleeve has openings and a fixed guide. The inner sleeve is disposed within the outer sleeve and includes an outer surface and an axially abutting surface defining a stair-stepped pathway. The fixed guide abuts against the axially abutting surface. The abutment of the fixed guide against the axially abutting surface of the inner sleeve causes the inner sleeve to translate axially between an open position and a closed position relative to the outer sleeve when rotated through operation of the motor, drive gear and driven gear. Systems for controlling fluid flow from lateral branches of a multilateral wellbore include at least a plurality of the downhole flow control valves and a downhole electrical power source for generating electrical power to operate the motor.

Abstract: The present invention pertains to a cable comprising: —at least one conductor coated by an insulation coating layer, —a first protective layer surrounding said insulation coating layer, said first protective layer at least comprising, but preferably being made of a tetrafluoroethylene (TFE) copolymer comprising from 0.8% to 2.5% by weight of recurring units derived from at least one perfluorinated alkyl vinyl ether having formula (I) here below: CF2?CF—O—Rf, wherein Rf is a linear or branched C3-C5 perfluorinated alkyl group or a linear or branched C3-C12 perfluorinated alkyl group comprising one or more ether oxygen atoms, said TFE copolymer having a melt flow index comprised between 1.0 and 6.0 g/10 min, as measured according to ASTM D1238 at 372° C. under a load of 5 Kg [polymer (F)]; —optionally, a second protective layer surrounding said first protective layer, and —an armor shell surrounding said first or second protective layer. The invention also pertains to use of the cable in downhole wells.

Abstract: An actuation device for well operations can include a tubular body including a plurality of key slots, a threaded shaft disposed within the tubular body that rotates relative to the tubular body and is fixed axially relative to the tubular body, an actuator disposed within the tubular member that moves axially relative to the tubular body, wherein the actuator includes a ramp portion and a threaded neck portion that engages with the threaded shaft such that when the threaded shaft rotates, the actuator moves axially relative to the tubular body, and a plurality of keys, each disposed in one of the plurality of key slots and in operative communication with the ramp portion such that as the actuator moves axially relative to the tubular body, each key is urged radially outwardly from the tubular body.

Abstract: A tool for monitoring conditions within a subterranean well includes a first body segment, the first body segment being an elongated member with an axial protrusion having a reduced outer diameter. A second body segment is sized for mating with the first body segment. A metal specimen circumscribes the axial protrusion of the first body segment so that an outer diameter surface of the metal specimen defines an outer diameter of the tool. A connection assembly releasably secures the first body segment to the second body segment.

Abstract: A method and apparatus according to which a flow control device includes a housing and a flapper valve. The housing defines an internal passage in which the flapper valve extends. The flapper valve includes a seat and a flapper pivotably coupled to the seat. The seat includes an internal passage and an external surface. The internal passage of the seat extends along a longitudinal central axis that is offset from a longitudinal central axis along which the external surface of the seat extends and a longitudinal central axis along which the internal passage of the housing extends. This offset allows an internal annular recess of the housing to accommodate the flapper pivoting away from the longitudinal central axis of the internal passage of the seat by a distance of equal to or greater than a radius of the internal passage of the seat.

Abstract: An adaptable anchor includes a frame; an arm articulated to the frame; a pad connected to the arm at a distance from the articulation with the frame; a wedge movably mounted to the frame and in wedging contact with the arm; a biasing member disposed to selectively apply a biasing energy between the frame and the wedge; and a degradable retainer preventing application of the biasing energy until degraded. An embodiment of a borehole system includes a borehole in a subsurface formation; a tubular member disposed in the borehole; and an adaptable anchor as in any prior embodiment in operable contact with the tubular member. An embodiment of a method for anchoring a tool in a borehole includes running the adaptable anchor into a borehole; degrading the degradable retainer; urging the wedge into contact with the arm with the biasing member; and displacing the pad.

Abstract: A stator assembly for a downhole-type well tool includes a stator housing including an internal chamber, an electric stator, a flow channel in the stator housing, and a heat exchanger. The electrical stator is disposed within the stator housing and in contact with the heat exchanger, the electrical stator to drive a rotor. The flow channel in the stator housing includes an inlet and an outlet, and the heat exchanger includes a first heat exchanger portion in contact with the electric stator in the internal chamber and a second heat exchanger portion at least partially disposed in the flow channel. The flow channel flows coolant fluid along the second heat exchanger portion to transmit heat across the heat exchanger from the electric stator to the coolant fluid.

Abstract: A method of cementing an oil or gas well for abandonment comprises cutting the production tubing 6 above the production packer 8, setting a tubing plug 9 in the tubing and then cutting the tubing. A bridge plug may be installed at the level of the cut, which spans the full diameter of the well casing 3. An agitator assembly 20 comprising an agitator 24, packer 21 and burst sub 23, with a running tool fitted to the top, is run down the tubing on wire line. Cement is then injected into the tubing 6, which flows through the agitator assembly and causes the tubing to vibrate. The cement fills the tubing but also flows back up the A annulus between the casing and production tubing. Vibration of the tubing assists the formation of a good quality cement plug extending all around the annulus over a substantial length of the well.

Abstract: Downhole completion system (100) arranged in a borehole, comprising a production casing (2) having an axial extension with an opening (4) for providing fluid communication between the borehole and the inside of the casing, a sleeve (5) arranged at least partly movably along or rotatably around the axial extension for opening, choking or closing the fluid communication and a sleeve control (7) for moving the sleeve (5) to open, choke or close the opening (4), wherein the sleeve control comprises a first part having at least one member (9) engaging the profile, a second part having a fixation unit (11) fixating the sleeve control in the casing, an actuator (12) for moving the first part in relation to the second part, a power supply (14), such as a battery, supplying power to the actuator (12), and a first communication module (15) for receiving control signals from surface.

Abstract: A downhole tool actuation system including: a tubing having a longitudinal axis and a main flowbore supportive of tubing pressure; an indexing mechanism in fluidic communication with the main flowbore, the indexing mechanism configured to count N number of tubing pressure cycles; a port isolation device movable between a blocking condition and an actuation condition, the port isolation device in the blocking condition for N?1 cycles of the indexing mechanism, and movable to the actuation condition at the Nth cycle of the indexing mechanism; and, a chamber sealed from the main flowbore in the blocking condition of the port isolation device, the chamber exposed to the tubing pressure in the actuation condition of the port isolation device. The downhole tool actuation system is configured to actuate a downhole tool upon exposure of the chamber to tubing pressure.

Abstract: A system includes a rotatable fluid distribution system having a first block and a second block, the first block is configured to receive a supply of pressurized fluid, the second block is configured to distribute the supply of pressurized fluid to one or more actuators of a running tool, a wellhead component, or both, and the first block and the second block are configured to rotate with respect to one another about an axis to adjust which of the one or more actuators of the running tool, the wellhead component, or both, receives the supply of pressurized fluid.

Abstract: A valve including a housing, a body having an aperture radially therethrough fluidly connecting a volume radially inwardly of the body with a volume radially outwardly of the body, a bulkhead sealedly disposed between the body and the housing, the bulkhead having a port therein, a piston extending through the bulkhead and sealed thereto, the piston having a bias end and a carrier end, a biasing member connected to the bias end of the piston, the piston exposed at a carrier end to fluid pressure from the volume radially inwardly of the body, a port closure operably connected to the piston.

Abstract: A composite drill gun for use in a wellbore environment can include a detonation housing containing a detonation source, a composite carrier containing one or more encapsulated charges, and a detonation train connecting the detonation source to the encapsulated charges. The detonation source and each individual encapsulated charge are all sealed with respect to the wellbore environment, and thus the carrier need not be sealed with respect to the wellbore environment. The carrier can be made out of composite materials without worry of leaks into the interior of the carrier, as the detonation source and encapsulated charges are all sealed with respect to the wellbore environment. The composite carrier can be easily drilled out of the wellbore after detonation.

Abstract: A system includes a hanger running tool, which has a tool body, a first piston configured to move a first lock member between first locked and unlocked positions between the tool body and a hanger, and a second piston configured to move a second lock member between second locked and unlocked positions between the hanger and a tubing.

Abstract: A system for use in a well includes a completion system having a shoulder contact region, an electric submersible pumping system deployed downhole via a cable for landing on the completion system, a tubular member coupled to the electric submersible pumping system and extending downhole from the electric submersible pumping system, and a shoulder mechanism slidably mounted on the tubular member for engagement with the shoulder contact region during landing, the shoulder mechanism being selectively settable along the tubular member to counter tensile loading in the cable. The shoulder mechanism is set against the tubular member via anchors actuated against the tubular member, and the anchors are actuated by a piston movably mounted within a housing of the shoulder mechanism.

Abstract: A downhole actuator (30) comprises a tubular housing (34) which includes an indexing profile (42) on an inner surface thereof, and an indexing sleeve (46) mounted within the housing (34). The indexing sleeve (46) comprises an engaging arrangement including first and second axially spaced engagement members (52, 54) which cooperate with the indexing profile (42) of the housing (34) to be sequentially engaged by an actuation object (48) passing through a central bore (50) of the indexing sleeve (46) to drive the indexing sleeve (46) one discrete step of movement through the housing (34) towards an actuation site.

Abstract: A modular donwhole tool system with a single electric hydraulic drive assembly. The assembly includes an electric hydraulic interface for coupling to any of a variety of different modular donwhole tools. Such tools may include a plug setting actuator, sleeve shifting actuator, valve effecting actuator and a variety of other radially or axially driven hydraulically powered actuators. Indeed, a variety of different actuators may be combined within the same system, tailored based on given downhole application needs. Thus, a viable off-the-shelf modular based on-site assemblage may be available to an operator for running off of a single electric hydraulic drive assembly.

Abstract: A downhole tool for increasing a cross-sectional area of a wellbore is provided. The downhole tool may include a first drilling assembly including a first reaming tool for selectively increasing the cross-sectional area of the wellbore. A first ball seat may receive a first ball. At least one of the first ball seat and the first ball may deform to allow the first ball to pass through the first ball seat when a predetermined pressure is applied thereto. A first piston may be coupled to the first ball seat. The first ball seat and the first piston may stroke when the first ball is received within the first ball seat, thereby actuating the first reaming tool between an active state and an inactive state.

Abstract: Disclosed herein are various embodiments of devices, methods and systems for securing or coupling a string of downhole geophysical sensors to the sidewall of a borehole, using an expandable member configured to be deployed into an expanded position when at least one geophysical sensor is located at a desired depth in a borehole, the expandable member being configured to engage at least portions of the sidewalls and prevent the passage of a securing or coupling material around or through the geophysical sensor when the securing or coupling material is poured around the geophysical sensor when the expandable member is in the open or expanded position. This allows the securing and acoustic coupling of downhole geophysical sensors to the sidewall of a borehole while avoiding problems caused by transmission of surface noise into the subsurface resulting from pouring securing or coupling material to fill the entire well bore.

Abstract: A self-propelled, remotely-controlled equipment deployment vehicle is configured to deliver equipment to a desired location within the horizontal portion of a deviated wellbore. The deployment vehicle includes a cargo frame, an electric motor and an active mobility assembly. The active mobility assembly is connected to the cargo frame and powered by the electric motor. The cargo frame can be configured to transport, offload and accurately position the selected cargo. Alternatively, the equipment deployment vehicle can be configured with a passive mobility assembly that allows the equipment deployment vehicle to be pushed or pulled along the horizontal section of the wellbore without power.

Abstract: A distributed artificial lift system is configured for use in a wellbore that includes a vertical section and at least one lateral section connected to the vertical section. The distributed artificial lift system includes a first remote assembly positioned within the first lateral section. The first remote assembly includes an equipment deployment vehicle and cargo selected from the group consisting of electric remote pumping units, tubing, tubing connectors, tubing adaptors, sensor packages, gas separators, perforating tools, injection pumps and other downhole components. The first remote assembly is optionally self-propelled and remotely-controlled.

Abstract: Systems, program product, and methods for monitoring linearity of a down-hole pumping system assembly during deployment within a bore of a casing of a well positioned to extract hydrocarbons from a subterranean reservoir and selecting an optimal operational position for the down-hole pumping system assembly within the bore of the casing, are provided. Various embodiments of the systems allow an operator to ensure that a motor and pump of a down-hole pumping system assembly are installed in an optimal position in a well by ensuring alignment across the pump stages casing and motor casing. The system includes a groove extending along an outer surface of a housing of the pumping system assembly, and an optical sensing fiber mounted in the groove.

Abstract: An apparatus, method and system for removing fluids from a well comprising a rotary pump for positioning within the well, the rotary pump including an inlet end and a discharge end, the rotary pump comprising at least one pump impeller intermediate the inlet end and discharge end, the at least one pump impeller rotating at a rate greater than 3600 rpm; a driver for driving the at least one pump impeller to a rate greater than 3600 rpm, the driver positioned within the wellbore and operatively connected to the rotary pump; a magnetic bearing system, the magnetic bearing system operatively connected to the rotary pump and/or driver; and a digital controller positioned within the wellbore to control the magnetic bearing system. A method for removing liquids from a well and an apparatus and method for producing gas from a wellbore or injecting a fluid into a wellbore are also provided.

Abstract: The disclosure contained herein describes systems, units, and methods usable to stimulate a formation including a pump usable to pressurize fluid, an electric-powered driver in communication with and actuating the pump, and an electrical power source in communication with and powering the electric-powered driver. The electrical power source can include on-site generators and/or grid power sources, and transformers can be used to alter the voltage received to a voltage suitable for powering the electric-powered driver. Air moving devices associated with the electric-powered driver can be used to provide air proximate to the pump to disperse gasses. In combination with fluid supply and/or proppant addition subsystems, the pump can be used to fracture a formation.

Abstract: Apparatus and method for collecting and preserving in representative condition a fluid sample from a reservoir which comprises: positioning a sample receptacle in the vicinity of a subterranean zone to be sampled, allowing or causing the sample to first flow into the sample receptacle, wherein the movement of the sample into the sample receptacle is restricted by the movement of a sampling piston, and wherein the movement of the sampling piston is further controlled by the rotation of an electrical motor connected to the sample piston such that the rotation of the electric motor translates to lateral movement of the sample piston, the lateral movement of the sample piston in turn allowing sample to enter the sample receptacle, and wherein once an adequate volume of sample has been collected, reversing the direction of the electrical motor will serve to cause the sample piston to exert pressure on the collected sample.

Abstract: This disclosure is drawn to methods, systems, devices and/or apparatus related to power control in applications over long cables. Specifically, the disclosed methods, systems, devices and/or apparatus relate to power control that considers the maximum power available at the end of a long cable (or from a battery) to a load over a broad range of load conditions. Some example systems may include a power supply located at the Earth's surface and a power converter coupled to the power supply via a cable having a first end coupled to the power supply and a second end coupled to the power converter. Some example power converters may be configured to measure the power being consumed by the electrical load in the well, and adjust operating parameter(s) of the electrical load based, at least in part, on the maximum power available at the second end of the cable.

Abstract: The present invention provides a method and system for providing on-site electrical power to a fracturing operation, and an electrically powered fracturing system. Natural gas can be used to drive a turbine generator in the production of electrical power. A scalable, electrically powered fracturing fleet is provided to pump fluids for the fracturing operation, obviating the need for a constant supply of diesel fuel to the site and reducing the site footprint and infrastructure required for the fracturing operation, when compared with conventional systems.

Abstract: The present invention provides a method and system for providing on-site electrical power to a fracturing operation, and an electrically powered fracturing system. Natural gas can be used to drive a turbine generator in the production of electrical power. A scalable, electrically powered fracturing fleet is provided to pump fluids for the fracturing operation, obviating the need for a constant supply of diesel fuel to the site and reducing the site footprint and infrastructure required for the fracturing operation, when compared with conventional systems.