Abstract: A motorized pump system includes a switched reluctance motor with a motor rotor and a motor stator, and a pump surrounding the switched reluctance motor. The motor rotor is positioned radially inward or outward of the motor stator, and the pump includes a pump rotor integrated with the motor rotor. The pump rotor includes at least one impeller connected to the motor rotor.

Abstract: The disclosure relates to a hard-sealing soluble bridge plug, comprising a body made of soluble metal. The body comprises a wedge, a slip and a guide shoe which are connected from top to bottom in turn; at least one metal sealing ring is sleeved at the junction of the outer circumference of the wedge and the slip, and the metal sealing ring is made of soluble metal. The hard-sealing soluble bridge plug provided by the disclosure is applied to the field of fracturing and stimulation operation of an oil and gas well so that the hard-sealing soluble bridge plug is more convenient to store, more stable to seal and more firm to anchor, the setting success rate of the hard-sealing soluble bridge plug is effectively improved to better adapt to down hole environments. Furthermore, due to simple and compact structure, the hard-sealing soluble bridge plug is easy to machine and manufacture, and is effectively reduced in the cost of the soluble bridge plug.

Abstract: A hydrocarbon wellbore production apparatus includes a tailpipe and a control valve connected with the tailpipe. The tailpipe has a fluid inlet receiving well fluids entering the casing from a formation, and a fluid outlet above the fluid inlet to deliver well liquid to a connected pump inlet. The control valve is operable to (i) open when a lower fluid pressure below the flow control valve exceeds an upper fluid pressure above the flow control valve to allow upward flow through the flow control valve, (ii) close when the upper fluid pressure exceeds the lower fluid pressure by an amount which does not exceed a prescribed pressure limit value to hold fluid in the apparatus above the flow control valve, and (iii) open when the upper fluid pressure exceeds the lower fluid pressure by an amount which exceeds the pressure limit value to release excess fluid back down the tailpipe.

Abstract: A coiled tubing system includes a coiled tubing unit with a coiled tubing string carried by the unit, the coiled tubing string having a stinger end; an injector support frame having an upper and lower ends; a coiled tubing injector disposed at the upper end of the support frame and engaging the coiled tubing string; and a loading device supported between the coiled tubing injector and the lower end of the frame, the loading device attached to the stinger end of the coiled tubing string. The system may include a riser tube disposed between the upper end of the frame and the loading device, coupling a housing of the loading device to a base of the coiled tubing injector, the coiled tubing string extending through the riser. The system may include a support device supporting the loading device, the support device pivotally supporting the loading device relative to the frame.

Abstract: Downhole well completion system for control of flow to or from multiple compartments (1a,1b,1c,1d) in a targeted subterranean reservoir (30), comprising a plurality of interval control valves (2) connected in series forming a downhole string (24), said interval control valves (2) are manipulated from surface via hydraulic control lines (4a, 4b, 4c) to open or close flowports (20) of each interval control valve (2), wherein each interval control valve (2) comprises a command module (5) connected to at least two of said hydraulic control lines (4a, 4b), a first hydraulic control line is a command line (4a) to deliver applied pressure to the command module (5), which translates hydraulic pressure signals into axial movement of an inner ratchet rod (6) that determines the position of an integral pilot valve (7), a second hydraulic control line is a common-open or common-close line (4b), to provide hydraulic power to either open or close the flowports (20) of each interval control valve (2), and the inner ratchet

Abstract: A sucker rod string is formed from sucker rods and sucker rod couplings. The sucker rod couplings are formed from a spinodally-hardened copper alloy comprising from about 8 to about 20 wt % nickel, and from about 5 to about 11 wt % tin, the remaining balance being copper, and having a sliding coefficient of friction of 0.4 or less when measured against carbon steel. The sucker rod string has low friction and improved pumping stroke, enhanced pumping capacity, and less load in the overall system.

Abstract: An actuator assembly of a downhole tool may include a high pressure chamber and a low pressure chamber. A pressure applied from the surface to the tool may enter both chambers. The low pressure chamber may include an inlet that restricts the flow of pressure and prevents the pressure within the low pressure chamber from increasing quickly. The high pressure chamber may also include an inlet that restricts the flow of pressure to prevent the pressure within the high pressure chamber from increasing quickly. The inlet of the high pressure chamber may also include a check valve that prevents pressure from bleeding off from the high pressure chamber through the check valve. The pressure within the high pressure chamber may actuate a piston to actuate the tool in response to the pressure applied from the surface falling within a predetermined pressure and time range.

Abstract: An orientation sub includes a pair of connectors that consists of a first connector and a second connector with the first connector. A center section joins the first connector to the second connector. The second connector connects the orientation sub to a tool. The center section has a predetermined geometric configuration with that self-orients the tool when the orientation sub and the tool are inserted into a well defined by casing.

Abstract: A hybrid bit with roller cones having inserts is disclosed, includes a bit body, blades and roller cones. All the fixed cutting elements at the inner cone section, nose section and shoulder section of blades herein constitutes two sets of corresponding fixed cutting elements respectively, forming two profile envelopes of fixed cutting elements at least in the interval at the nose section and shoulder section, the two profile envelopes of fixed cutting elements are spaced at high and low intervals at the nose section and shoulder section, forming two stages of cutting by fixed cutting elements; and the cutting position of the cone insert mainly corresponds to the nose section and shoulder section of blades, the outermost cutting profile envelope of cone inserts formed by all or part of cutting elements on cones herein is higher than the outermost cutting profile envelope of fixed cutting elements, forming the third stage of cutting.

Abstract: A hydraulic jar includes a tubular housing having central bore and an exterior. The housing includes a passage from the central bore to the exterior. A mandrel is axially movable within the housing, forming an annular space between the mandrel and the housing that includes a timing fluid. The mandrel includes an interior axial space that permits the flow of a drilling fluid. A timing device is fixed to the mandrel in the annular space. A trigger is capable of blocking the flow of drilling fluid through the axial space in the mandrel, and the mandrel moves axially in the housing when the trigger engages the mandrel. The timing device causes the mandrel to move at a first speed and at a second speed to create the impulse. The drilling fluid exits the central bore through the opening after the mandrel moves past the opening.

Abstract: Hydrocarbon wells including gas lift valves and methods of providing gas lift in a hydrocarbon well. The hydrocarbon wells include a wellbore extending within a subsurface region and a downhole tubular extending within the wellbore. The downhole tubular defines a tubular conduit, and the wellbore and the downhole tubular define an annular space therebetween. The hydrocarbon wells also include a lift gas supply system configured to provide a lift gas stream to the annular space and a closure material supply system configured to provide a closure material stream to the annular space. The hydrocarbon wells further includes a gas lift valve operatively attached to the downhole tubular. The gas lift valve includes a lift gas injection conduit and an actuation mechanism. The actuation mechanism selectively transitions to a closed state responsive to contact with the closure material. The methods include methods of operating the hydrocarbon wells.

Abstract: The disclosure provides a pressure escape system comprising: an intake port, wherein the intake port receives a downhole fluid; a sliding sleeve, wherein the sliding sleeve comprises fluid ports disposed through a portion of the sliding sleeve that is within a fluid flow path of the downhole fluid travelling from the intake port; a spring, wherein the spring is disposed within a housing and coupled to the sliding sleeve; and one or more exit ports, wherein the one or more exit ports are disposed through the housing and through the sliding sleeve.

Abstract: A directional drilling device includes a housing, a drive shaft extending through the housing, a plurality of magnetic field sensors positioned in the housing and in signal communication with a control device also positioned in the housing, wherein the magnetic field sensors are configured to determine a magnetic interference declination influenced by a magnetic interference field as a magnetic interference flux density and to transmit a magnetic interference declination value corresponding to a magnetic interference flux density to the control device, and a directional control device coupled to the housing and controllable by the control device to control a position of the directional drilling device, wherein the control device is configured to generate a correction value based on the magnetic interference declination value, and wherein the correction value corresponds to a deviation of the magnetic interference flux density from a reference magnetic flux density measured at a reference standard.

Abstract: A drill bit comprises a bit body having a longitudinal axis and a blade extending radially outward from the longitudinal axis along a face region and axially along a gauge region. A gauge region includes a cutting element located proximate to an uphole edge of the blade in the gauge region. A remainder of the gauge region is free of cutting elements mounted thereon. A method of drilling a borehole comprises rotating the bit about the longitudinal axis, engaging a formation with cutting elements mounted to the face region, and increasing a lateral force applied substantially perpendicular to the longitudinal axis such that the cutting element engages the formation and such that side cutting exhibited by the tool is initially minimal and substantially constant and subsequently increases in a substantially linear manner with increasing lateral force.

Abstract: A technique facilitates wellbore operations and utilization of wellbore equipment, e.g. equipment comprising actuation devices for downhole tools. According to an embodiment, the system comprises a pump solution for an electrically control device, e.g. an electrically controlled valve. The system may comprise hydraulic circuitry which utilizes bellows to effectively enclose the hydraulic circuitry. Consequently, the system enables an electrically control downhole system having components hydraulically actuated via a closed loop hydraulic system.

Abstract: A smart system for circulating LCM can implement a method. While a wellbore is being drilled in a geologic formation, drilling parameters identifying wellbore drilling conditions of a wellbore drilling system drilling the wellbore are received. The wellbore drilling system flows a wellbore drilling fluid including particulates of different size distributions. The particulates operate as LCM to reduce loss of the wellbore drilling fluid in the geologic formation. Size distributions of the particulates in the wellbore drilling fluid flowing through multiple different wellbore fluid flow pathways of the wellbore drilling system are received. The size distributions represent a concentration of the particulates in the wellbore drilling fluid. A release of certain particulates into the wellbore drilling fluid is controlled based, in part, on the received drilling parameters and the received size distributions of the particulates.

Abstract: The present disclosure relates to an integrated collet and a downhole plugging system, and a plugging method thereof. The integrated collet includes a collet body, wherein the collet body can form a seal with an inner wall of a downhole casing and is anchored to the inner wall of the downhole casing; an internal channel is formed inside the collet body along an axial direction; and an inner wall of the internal channel of the collet body is a conical surface.

Abstract: A downhole tool actuator includes a housing defining an axial bore and a first port extending radially from the axial bore, as well as a piston disposed and movable within the axial bore of the housing. The piston includes a receptacle wall, a shaft extending axially from the receptacle wall, and a contact member extending across the shaft. The receptacle wall defines a chamber and a second port extending radially from the chamber. The contact member is positioned outside of the housing and is configured to engage a downhole tool.

Abstract: Embodiments herein relate to apparatus for selecting between direct manipulations of a downhole tool and shifting of the operational mode of a downhole tool, and more particularly to a mode selector tool coupled with a J-Slot mechanism for the downhole tool, the selector enabling either an unimpeded shifting of, or a locking, of the J-Slot mechanism and connected downhole tool.

Abstract: Systems and methods include a plug activated mechanical isolation device that controls fluid flow inside a tubular in a wellbore. The device includes a sleeve for coupling to the tubular, and the sleeve includes an internal bore and port for fluid flow therethrough. A channel element is positioned in the internal bore and includes an internal channel and an orifice for fluid flow between the internal channel and internal bore. The channel element is attached to the sleeve via a breakable attachment portion, and the orifice is aligned with at least one port of the sleeve. The channel element is slidable within the sleeve, upon breakage of the breakable attachment portion with a force, to move the orifice out of alignment with the port of the sleeve so that a portion of the channel element covers the port of the sleeve to block fluid flow through the port.