Abstract: A shift uphole-to-open sleeve assembly is provided for insertion along a tubular string for multi-stage, selectable wellbore treatment. The sleeve assemblies are very short in length, being too short for in-sleeve engagement, and instead have a downhole shoulder engageable for opening using dogs of a conventional shifting tool. Use of a common J-mechanism having four axial inappropriately places the sealing packer of a downhole tool above the sleeve ports. Multiple extra J-mechanism cycles are required to position the packer downhole thereof. Herein a modified downhole tool is disclosed including a biased repositioning sub to eliminate many of the extra tool cycles. In embodiments the short sleeve can replace casing collars.

Abstract: An indexing mechanism includes a piston. An indexing sleeve encases a portion of the piston. The indexing mechanism is longitudinally fixed to the piston, and is rotatable relative to the piston. The indexing sleeve includes an indexing track. An indexing ring surrounds less than an entirety of the indexing sleeve. The indexing ring is rotatable relative to the piston. The indexing ring includes an indexing pin that extends into the indexing track.

Abstract: An electronic power conversion component includes an electrically conductive package base comprising a source terminal, a drain terminal, at least one I/O terminal and a die-attach pad wherein the source terminal is electrically isolated from the die-attach pad. A GaN-based semiconductor die is secured to the die attach pad and includes a power transistor having a source and a drain, wherein the source is electrically coupled to the source terminal and the drain is electrically coupled to the drain terminal. A plurality of wirebonds electrically couple the source to the source terminal and the drain to the drain terminal. An encapsulant is formed over the GaN-based semiconductor die, the plurality of wirebonds and at least a top surface of the package base.

Abstract: Provided is an electro/hydraulic valve for use in a hydrocarbon production well, an electrically surface-controlled subsurface safety valve, and a method of operating an electrically surface-controlled subsurface safety valve. The electro/hydraulic valve for use in a hydrocarbon production well, in one aspect, includes a fluid chamber, and an electro/thermal expansion pump having a fluid inlet and a fluid outlet, and further wherein an inlet check valve is positioned in fluid communication between the fluid chamber and the fluid inlet and an outlet check valve is positioned in fluid communication between the fluid outlet and a hydraulically controlled actuation member.

Abstract: A downhole device and method to trigger, shift, and/or operate a downhole device of a drilling string in a wellbore is disclosed. At a high level, the disclosed device causes a portion of drilling fluids to bypass the drill bit and into the annulus. The bypass may be triggered upon certain conditions related to the rotation speeds of the drill string or other conditions such as the pressure of the drilling fluids. For example, the drill string may be rotated in some protocol of operation (e.g., stop at certain rpm, and/or stop at certain other rpm) to describe a recognizable series of signals to an accelerometer and/or microprocessor that will communicate to pumps or valves to operate or pause/stop operations.

Abstract: A toe valve to control the injection of fluid into a toe of an oil or gas well and including: a body with a bore, the body having a port adapted to permit fluid flow between the bore and an outlet on an external surface of the toe valve when the port is open; a closure member adapted to move from an initial closed position in which the port is closed, to an open position in which the port is open; and an actuating mechanism which can be actuated to urge the closure member from the initial closed position toward the open position, and which can be reset when the closure member is moving between the closed and open positions to return the closure member to the initial closed position.

Abstract: A pressure bleed-off module for an oil well includes: an inlet receiving fluid from an annulus vent of the well; an outlet sending the received fluid to a kill valve of the well; and two paths coupled in parallel between the inlet and the outlet. Each path channels a flow of the received fluid from the inlet to the outlet and includes: a pressure relief valve dividing the path into an inlet side coupled to the inlet and an outlet side coupled to the outlet, opening when the pressure of the fluid in the inlet side exceeds a threshold, and closing when the inlet fluid pressure is below the threshold; pressure gauges measuring the inlet fluid pressure and the pressure of the fluid in the outlet side; a pressure recorder recording the measured inlet and outlet fluid pressures; and a sampling point for draining the fluid in the outlet side.

Abstract: A diverter for obstructing and temporarily sealing a perforation in a well casing in a subterranean formation during hydraulic fracturing. The diverter comprises an outer surface and circuitry within the outer surface for determining a pressure proximate the diverter.

Abstract: An apparatus for generating power includes a fluid chamber configured to receive borehole fluid, one or more conductive coils surrounding the fluid chamber, a reciprocating magnetic shuttle disposed in the fluid chamber and dividing the fluid chamber into a first volume and a second volume, a first conduit connected to the first volume, and a second conduit connected to the second volume, the first conduit and the second conduit extending from a tubular conduit to an annulus. The apparatus includes a switching assembly configured to alternate between a first operating state where the first volume is in fluid communication with the annulus and a second operating state where the first volume is in fluid communication with the tubular conduit, to alternate a direction of differential pressure between the first volume and the second volume and cause the magnetic shuttle to move in a reciprocating motion and generate an electric current.

Abstract: A method of providing an underbalance in a wellbore that includes positioning a surge assembly within the wellbore; bypassing a differential chamber that extends along a portion of the length of the surge assembly when flowing fluid through a fluid passageway that extends along the length of the surge assembly; and placing the fluid passageway in fluid communication with the air chamber to create an underbalance in the fluid passageway.

Abstract: A resettable pressure activated device, comprises an inner wall, a return spring, a resilient element and an axially movable piston arranged around the inner wall. The piston comprises a radially extending piston area in fluid communication with a central bore within the inner wall such that the piston moves in an activation direction when a bore pressure within the central bore exceeds the pressure around the device by a predetermined release pressure.

Abstract: A system (1) for stimulating a well with an annulus (3) formed by a string (2) and a wellbore (4), wherein the system (1) comprises a pressure activated injection assembly (200) configured to open at an activation pressure below an injection pressure and a mechanically operated sand control assembly (100) configured to flush the annulus (3) after injection. The system (1) comprises a pressure activated flushing device (500) mounted uphole from the injection assembly (200) and configured to open radial flush ports (501, 502) between the interior of string (2) and the annulus (3) at a flushing pressure above the injection pressure. An optional release mechanism for the pressure activated injection assembly (200) is also disclosed.

Abstract: An isolation valve for use in a wellbore includes a housing having a bore; a flapper movable between an open position and a closed position, the flapper operable to isolate an upper portion of the bore from a lower portion of the bore when the flapper is in the closed position; and a collet pivotable between a first position configured to move the flapper to the closed position, and a second position configured to engage the flapper in the closed position, thereby retaining the flapper in the closed position.

Abstract: A method of controlling fluid flow through a circulation valve disposed in a borehole includes flowing a fluid at a first flowrate through a first jet and a second jet disposed in a throughbore of a sliding sleeve disposed in a housing of the circulation valve, flowing the fluid at a second flowrate through the first jet and the second jet to actuate the sliding sleeve from a first position to a second position, and flowing the fluid from the throughbore of the sliding sleeve through a housing port of the housing in response to actuating the sliding sleeve from the first position to a second position.

Abstract: A downhole tool comprising a body and a sealing element, wherein the sealing element is composed of a composite material comprising a rubber and a degradable acrylate-based polymer, and wherein at least a portion of the degradable acrylate-based polymer degrades when exposed to an aqueous fluid in a wellbore environment.

Abstract: A downhole control method for use in a wellbore that includes deploying a first stand-alone hydraulic reservoir downhole; measuring a first downhole fluid parameter; and actuating a first inflow control device, based on the first measured downhole fluid parameter, using the first stand-alone hydraulic reservoir. In one aspect, the first stand-alone hydraulic reservoir and the first inflow control device comprise an open-hole completion system.

Abstract: A hydraulic port collar includes a housing having one or more housing ports. The hydraulic port collar includes a port collar bore disposed within the housing forming an inner surface of the housing. The hydraulic port collar includes a sliding sleeve disposed within the port collar bore. The sliding sleeve has a sliding sleeve inner surface and a sliding sleeve outer surface. The hydraulic port collar includes a dissolvable or fragmentable landing seat radially aligned with and abutting the sliding sleeve inner surface.

Abstract: The present invention relates to an intelligent switching valve for reservoir reformation and production monitoring and control. The intelligent switching valve comprises a connection short section, an electric short section, a fluid storage short section, a hydraulic control short section and a slide sleeve short section. The middle part of the intelligent switching valve is a full bore. In a working process, a casing coupling and a casing are connected and are mounted under the shaft as components of a well cementation casing. Wireless communication with ground equipment is realized through low-frequency electromagnetic waves to finish receiving/transmitting of working instructions and data. The switching valve is opened and closed under electric and hydraulic control and external assisting is not needed in an opening or closing process. The number of times of opening and closing is not limited and the number of stages is not limited.

Abstract: A chemical injection valve can include a valve stem reciprocably disposed relative to a primary seal, and a variable flow restrictor upstream of the primary seal relative to a direction of flow through the chemical injection valve. The variable flow restrictor restricts the flow when the valve stem is disengaged from the primary seal. A chemical injection system can include a chemical treatment pumped through a chemical injection valve and into an interior of a tubular string in a well, the chemical injection valve including a valve stem, a primary seal sealingly engaged with the valve stem in a closed position and disengaged from the valve stem in an open position, and a flow restrictor that restricts the flow of the chemical treatment downstream from the primary seal in the open position.

Abstract: A casing landing and cementing tool has a wellbore obstruction-clearing tool at a downhole end thereof and a check valve uphole of any fluid vulnerable components to isolate the vulnerable components from the threat of cement incursion. The check valve is manufactured of drillable materials, the plunger being axially actuable but non-rotatable, the valve body being threadably secured within the tool. In one aspect the tool is a sleeve bit rotatably and reciprocally coupled about a mandrel secured to a non-rotating casing string, the check valve located in the mandrel. In another aspect, the tool is a bit coupled to a rotatable casing string, the check valve located in the bit.

Abstract: A reclosable multi-zone isolation tool including a piston assembly with a lock out feature. The tool has an outer and inner tubular having an annular flow path defined there between, and a central flow path defined by the inner tubular. The annular flow path is in fluid communication with the first zone, while the central flow path is in fluid communication with the second zone. A sleeve is positioned in the annular flow path and axially moveable between an open and closed position. A mandrel is positioned within the inner tubular and coupled to the sleeve to actuate the sleeve between the open and closed position. A pressure responsive piston assembly is coupled to the mandrel in order to actuate the sleeve to the open position. Once in the open position, the piston assembly is “locked out,” thereby allowing the mandrel and sleeve to move relative to the piston between the open and closed positions.

Abstract: A power control device includes a communication device configured to be disposed in a borehole and configured to couple electrical power from a power source to a downhole component from a conductor disposed along a borehole string, a circuit breaker system including a first circuit breaker disposed at a connection between the conductor and the downhole component and configured to be closed to connect the downhole component to the conductor, and a controller configured to monitor at least one of a current level and a voltage level at the connection and at the conductor. The controller is configured to control the circuit breaker system and autonomously perform opening the first circuit breaker in response to detecting a deviation in the at least one of the current levels and voltage levels at the connection, to isolate the downhole component from the conductor and the power source.

Abstract: A slip for a downhole tool is provided. The slip may include an annular body having a first axial end, a second axial end, an inner surface, an outer surface, and an axial length. The annular embody further includes a taper on the inner surface that extends along the axial length of the annular body, and a left-hand thread pattern defined by the outer surface and extending from the first axial end along a portion of the axial length, each thread of the left-hand thread pattern having a crest that is angled toward the first axial end.

Abstract: An apparatus and method relating to down-hole production equipment for use in an oil well environment is provided. The apparatus and method are for selectively isolating fluid flow through a production packer or other down-hole tubular device. The apparatus and method use a ball valve, which is moved from an open position to a closed position by lateral or axial movement of the tubing string as opposed to by rotating the tubing string.

Abstract: A downhole valve system includes a downhole valve positionable in a wellbore and a downhole valve actuator coupled to the downhole valve. An annulus is defined between the downhole valve and the wellbore. The downhole valve actuator includes a pressure chamber that encloses a pressurized fluid at a particular pressure and a breakable member. The downhole valve actuator is adjustable to a first position to close the downhole valve when the particular pressure is greater than an annulus pressure at a first pressure in the annulus, and the downhole valve actuator is adjustable to a second position to lock the downhole valve in an open position independent of the relative values of the particular pressure and the annulus pressure, with the annulus pressure set at a second pressure greater than the first pressure to break the breakable member.

Abstract: In accordance to one or more aspects of the disclosure an indexing track for controlling a dual valve assembly includes a plurality of interconnected pressure-up and pressure-down slots that define sequence paths to translate the pin and to actuate the dual valve assembly to a first position when the pin is in a first track position, to a second position when the pin is in a mid-track position, and a third position when the pin is in a third track position.

Abstract: A tool includes a housing between an outer wall and an inner wall that surrounds a longitudinal tool bore. First and second axially spaced ports connect the housing to the tool bore. An unlocking piston seals across the first port and an arming sleeve seals across the second port. A Locking ring is held in place by a retaining ring and prevents the arming sleeve from sliding towards the unlocking piston to open the second port. An unlocking tool bore pressure at the first port moves the unlocking piston axially to displace the retaining ring and unlock the tool. A lower, arming tool bore pressure moves the arming sleeve in the unlocked tool to open the second port and arms the tool. An actuating tool bore pressure, which is less that the unlocking pressure, actuates a valve piston via the open second port.

Abstract: A transportable drilling rig having a self-elevating drill floor includes a base structure comprising multiple base towers that can be transported to a wellsite and positioned around an intended wellbore location. A horizontal base frame is installed between lower regions of the towers to form a stable rig base structure, and a drill floor can then be constructed over the base frame and between the base towers. A suitable rig mast can then be erected on the drill floor. Floor-lifting cables are anchored to upper regions of the base towers and disposable around corresponding sheave assemblies associated with the drill floor. The free ends of the floor-lifting cables can be engaged by the traveling block in the rig mast, whereupon the rig's drawworks can be actuated to elevate the drill floor and mast as required and then locked to the base towers.

Abstract: A CAN bus explosion proof node structure is disclosed which includes a physical parameter sensor, a physical parameter measurement circuit, a master controller, a data storage module, a communication interface module, and a power voltage and current limiting module. The master controller performs service processing of the digital signals, compares them with respective threshold levels to determine whether dangerous situations occur for the explosion proof node, and sends out an alarm when dangerous situations occur for the explosion proof node. The power voltage and current limiting module limits a maximum open circuit voltage and a maximum short circuit current of input power so that explosive gas and dust will not ignite when the nodes are in normal operation or experience failures.

Abstract: An inflow control device (ICD) that may include a piston located in a flow passage, a barrier that prevents fluid flow through the ICD, and a shear device that prevents movement of the piston. A method of actuating one or more ICDs may include preventing actuation of the devices by maintaining a pressure in an interior of a well tool (or tubing string) below an actuation pressure of the devices, where each device may include a piston located within a flow passage, a barrier that prevents fluid flow through the ICD, and a shear device that initially prevents movement of the piston. The method may include increasing the pressure in the well tool (or tubing string) to be greater than or equal to the actuation pressure, thereby shearing the shear device and moving the piston.

Abstract: The present application includes an assembly and method for a plunger tool configured to remove contaminants from a well bore. The assembly includes a hollowed body, a dart configured to selectively close off the passage of working fluid through the body, and a wear pad coupled to an exterior surface of the body to protect the body from corrosive wear. The assembly may further include a dart having a core member and wear coating. The dart is configured to be interchangeable within the body and without the need to disassembly the body. The wear coating compressing for insertion and being sheared off during removal the dart. The body includes an internal lip to prevent the undesired removal of the dart.

Abstract: A wellbore fluid treatment apparatus includes a tubing string including a first port with a first closure disposed thereover to close the first port to fluid flow and a second port spaced axially uphole from the first port and having a second closure disposed thereover to close the second port to fluid flow; and an actuator tool configured to move through the tubing string and (i) to set a seal in the tubing string downhole of the first port; (ii) to actuate the first closure to open the first port; and (iii) to actuate the second closure to open the second port. A method for treating a well may employ the tool.

Abstract: A mechanism for selectively activating a plurality of downhole pathways. The method includes a casing segment which includes a plurality of casing ribs, a valve which includes a sleeve coupled for movement between an open and normally closed position, a rocker member mounted to the sleeve, a dart for pumping in hole including a dart profile matched to the rocker member profile such that the dart profile couples to the rocker member profile when in close proximity and, in turn, the sleeve moves using hydraulic force from the closed position to the open position.

Abstract: A tubular string is run into a wellbore with a remotely actuated valve near a lower end adjacent a cementing shoe. The valve is triggered to operate without intervention such as by mud pulses generated at the surface and recognized by a sensor linked to a processor adjacent the valve to trigger the valve to close. Alternative actuation systems are envisioned for the valve that is located near the cementing shoe.

Abstract: A ball seat valve employed in a downhole tool string includes a split-ring baffle that is configured to radially expand and to radially contract to catch a dropped ball.

Abstract: A system for use with a well having multiple zones can include multiple well screens which filter fluid flowing between a completion string and respective ones of the zones, at least one optical waveguide which senses at least one property of the fluid as it flows between the completion string and at least one of the zones, multiple flow control devices which variably restrict flow of the fluid through respective ones of the well screens, and multiple pressure sensors which sense pressure of the fluid which flows through respective ones of the well screens. A completion string for use in a subterranean well can include at least one well screen, at least one flow control device which selectively prevents and permits substantially unrestricted flow through the well screen, and at least one other flow control device which is remotely operable, and which variably restricts flow through the well screen.

Abstract: A method of drilling a wellbore includes drilling the wellbore by injecting drilling fluid through a drill string extending into the wellbore from surface and rotating a drill bit of the drill string. The drill string further includes a circulation sub having a port closed during drilling. The drilling fluid exits the drill bit and carries cuttings from the drill bit. The drilling fluid and cuttings (returns) flow to the surface via an annulus formed between an outer surface of the tubular string and an inner surface of the wellbore. The method further includes after drilling at least a portion of the wellbore: halting drilling; sending a wireless instruction signal from the surface to a downhole portion of the drill string by articulating the drill string, acoustic signal, or mud pulse, thereby opening the port; and injecting drilling fluid through the drill string and into the annulus via the open port.

Abstract: Disclosed herein is a valve. The valve includes a first member having a first port therethrough, a second member in operable communication with the first member having a sealing surface thereon on an inner radial surface of the second member and a second port therethrough that is movable relative to the first member. The valve also has a seal sealingly engaged with the first member and slidably sealingly engagable with the second member, and a support member movably disposed relative to the first member and the second member. The support member has a support surface dimensioned similarly to the sealing surface, and is movable with the second member relative to the first member so that upon such movement the seal is continuously supported by at least one of the sealing surface and the support surface.

Abstract: Actuation mechanisms for downhole assemblies in earth-boring applications may comprise a housing comprising an internal bore defining a flow path through the housing. An actuation member may be supported within the housing. A movable sleeve may be located within the internal bore and may be movable between a first position and a second position responsive to changes in flow rate of fluid flowing through the flow path. The movable sleeve may be biased toward the first position. The actuation member may be in an initial, pre-actuation position when the movable sleeve is initially located in the first position. The actuation member may be movable to a subsequent, pre-actuation position when the movable sleeve is located in the second position. The actuation member may be released from the actuation mechanism when the movable sleeve is returned to the first position.

Abstract: A hydraulic time delay system and method in a wellbore tool is disclosed. The system/method includes an actuation mechanism which allows pressure to act on a functional piston in the wellbore tool. The movement of the piston is restrained by a partially or filled reservoir which is allowed to exhaust through a flow restriction element. The restriction element comprises standard metal tubing with a known inner diameter and is cut to an exact length as predicted by fluid dynamic modeling. A time delay and rate of piston movement desired for the downhole tool, between a trigger event such as pressure and a functional event, can be tuned with parameters that include the length and diameter of the tubing, reservoir fluid viscosity and number of tubes in parallel. In another embodiment, a secondary plugging element added to the reservoir controls the rate of piston movement and time delay.

Abstract: A ported tubular is provided for use in casing a wellbore, to permit selective access to the adjacent formation during completion operations. A system and method for completing a wellbore using the ported tubular are also provided. Ports within the wellbore casing may be opened, isolated, or otherwise accessed to deliver treatment to the formation through the ports, using a tool assembly deployed on tubing or wireline.

Abstract: A flow control valve for use with a downhole motor includes a housing with at least one port and a sleeve with at least one opening. The sleeve is movable within the housing to align and offset the ports and openings. A first biasing member associated with a first portion of the sleeve and a second biasing member associated with a second portion of the sleeve bias the sleeve in a first direction, while pressure applied to the sleeve due to fluid flow moves the sleeve in an opposing second direction. Movement of the sleeve in the second direction compresses the first and second biasing members, disengages the first portion of the sleeve from the first biasing member, and aligns the openings with the ports to permit transmission of the pressure through the openings and ports.

Abstract: Hybrid-tieback seal assemblies, interventionless setting assemblies, and associated methods of setting downhole components of the hybrid-tieback seal assemblies using such interventionless setting assemblies are disclosed. A hybrid-tieback seal assembly comprises one or more anchoring bodies, one or more packer seal assemblies, and one or more interventionless hydraulic setting systems. A method of setting downhole equipment comprises applying a pressure to a compensating volume and providing a working volume, wherein the working volume is separated from the compensating volume by one or more hydraulic control devices. A pressure is applied to the working volume in response to the pressure applied to the compensating volume. The pressure applied to the compensating volume is then reduced and the pressure applied to the working volume is captured by the hydraulic control devices. The captured pressure in the working volume is applied to set one or more of the anchoring bodies and packer seal assemblies.

Abstract: A flow control device for control of fluid flow through a tubular member comprises a control chamber having a piston disposed therein, where the piston is moveable from an open piston position to a closed piston position by the application of a first fluid pressure, and a valve chamber having a valve therein, where the valve is moveable from a closed valve position to an open valve position by the application of a second fluid pressure. A seal preventing fluid flow through the control chamber into the tubular member is formed in the closed piston position, and a flow path through the valve chamber and into the tubular member is formed in the open valve position.

Abstract: A method of operating an isolation valve can include continuously transmitting a signal to a detector section, and a control system operating an actuator in response to the detector section detecting cessation of the signal transmission. A well system can include an isolation valve which selectively permits and prevents fluid communication between sections of a wellbore, a remotely positioned signal transmitter, and the isolation valve including a control system which operates an actuator in response to detection of a signal by a detector section. Another well system can include an isolation valve interconnected in a tubular string, and the tubular string being cemented in a wellbore, with cement being disposed in an annulus formed radially between the isolation valve and the wellbore.

Abstract: A stage tool for wellbore annular cementing may be opened for cementing by hydraulic actuation of a sliding sleeve valve from over a fluid port. After sufficient cement has been introduced, the stage tool fluid port can be closed by compressing two telescopically arranged parts of its tubular body to further overlap each other and overlie the fluid port. This permits the stage tool to be closed without employing a plug.

Abstract: An injection apparatus for use in a wellbore is disclosed wherein the apparatus includes a tubular housing and a shield housing disposed outside the tubular housing, the shield housing including a chamber in fluid communication with the tubular housing. The apparatus further includes a piston disposed within the shield housing, the piston coupled to a biasing member, wherein movement of the piston controls fluid communication between the chamber and the wellbore, and wherein the movement of the piston is caused by a pressure change of a fluid within the tubular housing.

Abstract: An apparatus and method for the actuation of down-hole tools are provided. The down-hole tool that may be actuated and controlled using the apparatus and method may include a reamer, an adjustable gauge stabilizer, vertical steerable tools, rotary steerable tools, by-pass valves, packers, whipstocks, down hole valves, latch or release mechanisms and/or anchor mechanisms.

Abstract: Interventionless setting assemblies and associated methods are disclosed. A method of setting downhole equipment comprises applying a pressure to a compensating volume and providing a working volume, wherein the working volume is separated from the compensating volume by one or more hydraulic control devices. A pressure is applied to the working volume in response to the pressure applied to the compensating volume. The pressure applied to the compensating volume is then reduced and the pressure applied to the working volume is captured by maintaining the pressure applied to the working volume when the pressure applied to the compensating volume is reduced. The captured pressure in the working volume is applied to set downhole equipment.

Abstract: Pressure cycle independent indexer devices and methods include an indexing logic having a trigger sequence path defining a pressure event (e.g., one or more pressure events) between a starting slot and an actuation slot and each pressure event being located between a sequence transition point from an incoming sequence leg into an outgoing sequence leg of the trigger sequence path and a return transition point from the trigger sequence path into a return path. The indexing logic may permit cycling hydraulic pressures in a well without inadvertently cycling through the trigger sequence path.