Abstract: A wellbore assembly includes a wellbore string configured to be disposed within a wellbore. The wellbore assembly also includes a float collar coupled to a downhole end of the wellbore string. The float collar includes a housing, a check valve, and a sleeve. The housing includes a fluid outlet. The housing defines a fluid port that extends through a wall of the housing. The check valve is disposed within the housing between the fluid port and the fluid outlet. The sleeve is coupled to the wall of the housing uphole of the check valve. The sleeve moves, based on pressure changes of the fluid in the float collar, with respect to the wall of the housing thereby either exposing the fluid port and opening a fluid pathway from the bore to an annulus of the wellbore, or covering the fluid port and blocking the fluid pathway.

Abstract: A mechanically actuated tubing drain for service with oil wells, water wells, gas wells and/or thermal wells has a configuration in which the drain opens by operation of a bumper member which may be pulled upwardly to move a sleeve member which is initially positioned adjacent to a drain port, thereby sealing the drain port. Once the bumper member pushes the sleeve member upwardly, any fluid in the tubing above the drain port will drain from the tubing. The bumper member may be pulled upwardly either by upward movement of a rod string or by operation of a wireline or slickline tool. The mechanically actuated drain does not require a tubing anchor to operate.

Abstract: There is provided a flow control apparatus configured for optimizing use of available space within the wellbore for conducting of fluids between the surface and the subterranean formation. The flow control apparatus is useable for conducting all forms of fluid, such as, for example, liquids, gases, or mixtures of liquids and gases. As well, the flow control apparatus is useable for effecting injection of fluid (e.g. a fluid for stimulating hydrocarbon production via a drive process, such as, for example, waterflooding, or via a cyclic process, such as “huff and puff”) into the subterranean formation, and for receiving production of fluid (e.g. hydrocarbon material) from the subterranean formation (including production that is stimulated by gas lift).

Abstract: Utilizing a fluid flow rate within a tool to close and open a vent extending through a circumference of the tool. The vent may be positioned above a packer pair that is configured to extend across an annulus. The tool may include a vent, sliding sleeve, adjustable member, and plunger.

Abstract: A downhole sleeve tool is provided that includes a lower sub defining a bore and one or more sleeve ports therethrough. There is a piston valve movably positionable within the lower sub to selectively block communication between the bore and the one or more sleeve ports. There is an upper sub connectable to the lower sub and sharing another bore therewith. The upper sub has an inlet port, one or more communication ports, and an outlet port. There is an at least one cartridge assembly disposed in a cartridge bore formed in a wall of the upper sub.

Abstract: A tool activation device includes a pressure inlet port configured to be in communication with a wellbore pressure, and a housing that includes a counter mechanism with a first counter end and a second counter end, where the counter mechanism includes a closed chamber filled with a fluid having a pressure, and a ratchet system that includes a ratchet piston with a first ratchet end in pressure communication with the pressure inlet port and a second ratchet end in communication with the closed chamber, a valve mechanism interconnecting the pressure inlet port and the closed chamber arranged for equalizing the pressure a cross the ratchet piston.

Abstract: A downhole tool control apparatus includes a control assembly, a stroking assembly, and a pocket sleeve positioned in an outer sub. The control assembly and stroking assembly are independently slidable axially within the outer sub. The control assembly and stroking assembly slide depending on the flow rate of fluid through the downhole tool actuator. The stroking assembly includes a spline barrel having a spline projection positioned within a spline pocket formed in the pocket sleeve. The pocket sleeve and control assembly include one or more ratchet teeth positioned in the pocket sleeve such that as the flow rate is changed between a high and a low flow rate, the spline projection engages the ratchet teeth until an actuated cycle is completed, allowing the downhole tool actuator to move to an actuation position.

Abstract: A downhole sleeve tool is provided that includes a lower sub defining a central bore and one or more sleeve ports therethrough. There is a piston valve slidably positionable within the lower sub to selectively block communication between the central bore and the one or more sleeve ports. There is an upper sub connectable to the lower sub and sharing another central bore therewith. The upper sub has an inlet port, one or more communication ports, and an outlet port. There is an at least one cartridge assembly disposed in a cartridge bore formed in a wall of the upper sub.

Abstract: A mud motor stall protector including a housing, a piston translationally disposed in the housing, the piston defining a flow passage therein, and a pin positioned relative to the housing to occupy a portion of the flow passage of the piston or leave the flow passage of the piston open depending upon position of the piston relative to the pin.

Abstract: Systems and methods for drilling optimization of a subterranean well include securing a multifunction sub in line with a tubular string. A nozzle provides a fluid flow path from the central bore through a sidewall of the sub body, the nozzle oriented in a direction so that the fluid flow path directs a wellbore fluid from within the central bore in a direction uphole. A valve system can move between a closed position where the fluid flow path of the nozzle is closed, and at least one open position where the wellbore fluid can pass through the fluid flow path. A control system is operable to receive information and provide a signal to move the valve system. The tubular string is moved into a bore of the subterranean well and information is delivered to the control system to regulate the flow of wellbore fluid through the nozzle.

Abstract: There are described downhole devices, methods and other apparatus, which may be used to generate energy, monitor fluids and/or provide control signals or otherwise trigger for actuation. The devices, methods, etc. may provide improved autonomy and/or accuracy, while at the same time minimise any effect on the operation of a well. Such devices and methods may be particularly useful downhole and in remote locations. An example of a device comprises a generating material having a fluid contact surface, that contact surface being configured to be in contact with a fluid downhole. The generating material may be configured to generate an electric charge at the material in response a fluid at the contact surface. In some examples, the device further comprises a signal source configured to provide a signal in response to a generated electric charge at the generating material.

Abstract: A wellhead valve assembly feedthrough for a cable or conduit comprises a lower connector disposed within the wellhead valve assembly and being coupled to an upper end of a cable or conduit disposed in a wellbore, and a moveable upper connector disposed above the lower connector, the upper connector extensible to connect to the lower connector and retractable to disconnect from the lower connector. The wellhead valve assembly feedthrough further includes a sealed exit arrangement having a segment of conduit or cable passing therethrough to outside the wellhead valve assembly, wherein one end of the segment of conduit of cable is connected to the upper connector.

Abstract: A hydraulic arrangement for fail-safe and pump-through of a safety valve. The arrangement allows for compact actuation of a safety valve through accumulators. The arrangement supports automatic closure of the valve in the emergent circumstance of any loss of hydraulic control above the valve. Additionally, the arrangement also allows for a technique of re-opening the valve for long term killing of a well in direct response to the introduction of kill fluid without requiring any added complex interventional measures.

Abstract: A downhole cutting tool and method of operating the cutting tool. The cutting tool (10) has first and second flow pathways through the tool body (12) and a switching mechanism operated by axial force via weight-set or drop ball to control the opening of the flow pathways and direct fluid to the second flow path and operate the cutting mechanism (18). Fluid flow through the first pathway can be used to actuate a hydraulically operated tool mounted on the tool string below the cutting tool (10).

Abstract: A selective downhole actuator comprising at least a first actuator position, a second actuator position and a third actuator position. The selective downhole actuator is reconfigurable between the first actuator position and the second actuator position. The selective actuator is selectively reconfigurable to the third actuator position by varying an operating parameter during a transition of the selective downhole actuator between the first and second actuator positions.

Abstract: A splitflow valve comprises a tubular body, a valve element and a lock. The tubular body defines a through hole and has at least one lateral bypass port. The valve element defines a flow restriction and is moveable along the through hole along a first direction between a first position and a second position, wherein the bypass port is closed by the valve element in the first position. In the second position the bypass port is open. The lock maintains the valve element in the second position wherein a flow of fluid entering the through hole of the tubular body is split into a first flow portion passing the flow restriction and a second flow portion exiting the at least one bypass port. Further, the lock is deactivatable to allow the valve element to return to the first position.

Abstract: A method of controlling flow in a tubular including developing a pressure in the tubular with an electric submersible pump (ESP), directing a flow of fluid through a flow control device arranged on the tubular downhole of the ESP in response to the pressure, sensing a parameter of the flow of fluid, and adjusting, in real time, a flow parameter of the flow control device with a coil tubing in response to the parameter of the fluid.

Abstract: A tubular includes an outer surface, an inner surface defining a passage, and a plurality of openings extending through the outer surface and the inner surface. A sleeve is positioned within the passage. The sleeve includes an outer surface portion having at least one recess. At least one release member extends from the inner surface into the at least one recess. The at least one release member maintains the sleeve in a first configuration relative to the plurality of openings. At least one of the inner surface and the outer surface portion includes a self-holding connection that establishes one of a reduced diameter portion of the passage and an increased diameter portion of the sleeve. The self-holding connection is configured to maintain the sleeve in a second configuration axially shifted relative to the first configuration.

Abstract: A bypass diverter sub including a housing defining a flow passage, a control line bypass piston arranged within a control line bypass bore defined in a wall of the housing, and a balance line bypass piston arranged within a balance line bypass bore defined in the wall. An outer magnet is disposed within a magnet chamber and is operatively coupled to the control and balance line bypass. A flow tube profile is positioned within the flow passage and provides an inner magnet magnetically coupled to the outer. The flow tube profile is movable between a first position, where control line and balance line pressures circulate through the bypass diverter sub to a subsurface safety valve, and a second position, where the control line pressure is diverted into the flow passage and the balance line pressure is diverted into a balance line jumper conduit.

Abstract: An actuator assembly for effective interventionless activation of a valve in wells of multilateral architecture. The assembly may be pressure actuated from an oilfield surface even in certain circumstances where another valve in another leg of the well has been opened in a manner compromising pressure control of the well. Due to the multi-stage nature of the actuator, pressure based activation remains viable as a result of supplemental and/or fail-safe modes of actuation, for example, where such pressure control becomes compromised.

Abstract: A valve arrangement including a housing having a port, a closure member defining a bore, the bore being of a smaller flow area than an adjoining flow area to produce a lower pressure in flowing fluid therein than pressure in fluid flowing in the adjoining flow area, the closure member being disposed within the housing and movable between a closed position and an open position, a volume defined between the closure member and the housing, an opening in the closure member extending from the volume to the bore of the closure member to convey fluid pressure generated in the bore of the closure member to the volume thereby creating a lower pressure in the volume thereby biasing the closure member into a closed position.

Abstract: A system for control using a hydraulic fluid includes a hydraulic control line for flowing the hydraulic fluid, a fluid line in fluid communication with the hydraulic control line, a flow controller configured to regulate a flow of the hydraulic fluid in the fluid line, and a piezoelectric device in fluid communication with the hydraulic control line and configured to actuate the flow controller upon receiving a selected flow of the hydraulic fluid.

Abstract: A casing having an inner diameter and an outer diameter, a packer positioned on a tool configured to expand across an annulus, and a pressure port positioned within a between the inner diameter and the outer diameter of the casing. The pressure port includes a first end being positioned on a lower annulus on a first side of the packer and second end being positioned on an upper annulus on a second side of the packer, wherein the pressure port is configured to create a pressure differential between the upper annulus and the lower annulus.

Abstract: A technique provides a simplified and cost-effective approach for deployment and operation of completion systems. The construction of the overall completion system and the deployment methodology provide an efficient approach for placement and operation of completion systems in a variety of wellbores. In many applications, the system and methodology may be used for sand control applications in which the completion equipment comprises sand control features, such as sand screens deployed along well zones.

Abstract: A system and method for vent gas combustion in storage tank for heavy oil production is provided. Auxiliary burners located are provided for combusting the well casing gas. A burner management system for controlling the auxiliary burners is provided which receives a gas pressure value and initiates the auxiliary burners based upon one or more threshold values when the gas pressure exceeds the one or more pressure values. An auxiliary exhaust stack may be collocated with a main exhaust stack of a tank heater for the storage tank.

Abstract: A downhole tool and method, of which the downhole tool includes a first sub defining a port extending radially therethrough, a second sub spaced apart from the first sub, and a housing connected with the first and second subs. A valve element is disposed at least partially within the housing, and is movable from a closed position to an open position. In the closed position, the valve element blocks fluid communication between a bore and an opening in the housing. When the valve element is in the open position, fluid communication between the bore and the opening is permitted. An actuation chamber is defined between the first sub, the housing, and the valve element, and is in fluid communication with the bore via a flow path that includes the port. A flow restrictor in the flow path is configured to slow fluid flow from the bore to the actuation chamber.

Abstract: An automatic drilling apparatus having a tool body, a motive device connected to the tool body, and a drill bit connected to the tool body. The apparatus also includes a setting tool connected to the body, at least one sensor disposed on the tool body, and a computer disposed in the tool body, wherein the computer is configured to actuate the motive device, the drill bit, the setting tool, and the at least one sensor.

Abstract: A downhole arrangement (32) comprises first (34) and second (41) members, a lock profile (4) fixed relative to one of the first and second members, and a lock member (10) for engaging the at least one lock profile. A release member (40) is provided which is moveable to selectively lock the lock member in engagement with the lock profile so as to selectively secure the second member relative to the first member. Such a downhole arrangement may permit a releasable connection between the first and second members.

Abstract: A closure device is provided to close a surge pressure reduction tool disposed in a deviated wellbore. The closure device may include a tubular body, a fin, and a rupture disk disposed in the tubular body. The closure device may be pumped downhole to close the tool.

Abstract: A check valve has a valve member flexibly attached to a seat with resilient members that fold in response to flow above a predetermined value to shut the valve. The flexibly extending members store potential energy that is released to separate the valve member from the seat when the pressure applied against the seated valve member declines to the point that the potential energy stored in the flexible members is able to move the valve member off the seat. The valve assembly including the valve member, the seat and the flexible members can be a common material, or can be all one or more nonmetallic materials or involve composites or other easily drilled materials that are compatible with the operating conditions of pressure differential, temperature and composition of the well fluid. The check valve assembly can be pushed with pressure when closed to operate a subterranean tool.

Abstract: A re-fracturing method involves placement and centralization of a liner string that has shaped charges at predetermined locations that are externally isolated with packers. The shaped charges can be set off in a desired order and re-fracturing can then take place in new locations. In a bottom up order for perforating sequentially larger balls can be landed on seats and developed pressure or component movement generated by applying pressure can be used to set a shaped charge and isolate portions of the borehole below. The balls and even the seats can be later milled out or just allowed to disintegrate or dissolve with well fluids that are present or later added to clear the liner for subsequent production. Alternatively, the liner could be removed by release of the packers before production or injection begins.

Abstract: A downhole tool includes a housing and a mandrel glidingly arranged within the housing, wherein the mandrel is formed as a piston. The flange is acting on a spring arranged around the mandrel. In a first position of the mandrel, a fluid flow can run 100% through the tool via a first nozzle at a first end of the housing, the inside of the mandrel and a second nozzle at a second end of the housing. At a predetermined flow rate and with the help of a passage arranged in the housing wall and connecting the first side of the tool with the space or ring room on the non-spring side of the mandrel and a side port in the mandrel on its spring side, the mandrel will be moved towards the second nozzle due to sufficient force acting on a flange of the mandrel thus overcoming the spring resistance.

Abstract: A drill stem test string may include a tubular body having an axial bore formed at least partially therethrough. An axial flow valve may be coupled to the first tubular body and allow fluid to flow axially through the first tubular body when in an open state and prevent fluid from flowing axially through the first tubular body when in a closed state. A radial flow valve may be coupled to the first tubular body and allow fluid to flow radially through the first tubular body when in an open state and prevent fluid from flowing radially through the first tubular body when in a closed state. A seal assembly may be coupled to an outer surface of the first tubular body and positioned between a lower end of the first tubular member and the first radial flow valve.

Abstract: A circulation mechanism in a subsea assembly is selectively actuated to allow fluid communication between the riser annulus and tubing string to immediately kill the well using heavy-weight fluid in the riser annulus; perform well control operations by adjusting the weight or other properties of fluid in the tubing string or riser annulus; and/or to circulate the riser of a deep-water well undergoing well testing or intervention.

Abstract: The embodiments described herein generally relate a downhole probe assembly incorporating a Bluetooth device for wirelessly transmitting electrical information between the downhole probe assembly and a surface electronic interface such as a computer when the probe assembly is above ground. The downhole probe assembly includes sensors for sensing downhole conditions; a controller in electrical communication with the sensors and configured to receive and process information from the sensors; a housing enclosing the one or more than one sensor and the controller; the Bluetooth device in electrical communication with the controller; and an end cap assembly fitted at one end of the housing. The end cap assembly partially surrounds the Bluetooth device and is configured for transmission of the electrical information therethrough. Also described is an end cap assembly for fitting to one end of a downhole probe assembly including a transmission module mated with and electrically connected to the Bluetooth device.

Abstract: A pressure test and actuation tool includes a housing; an insert disposed in operable communication with the housing. A metering head initially in sealed relation to both the housing and insert. A damper relief shoulder operably positioned relative to the metering head to initially support the metering head in sealed relationship with the housing and the insert and movable to unsupport the metering head defeating the sealed relationship with the housing and the insert. A method actuating a tool.

Abstract: A steam injection mandrel comprises a housing generally defining an axial flow bore and comprising one or more ports, an inner mandrel disposed within the housing, and a slot formed in the inner mandrel. The slot transitions at least three hundred sixty degrees about the longitudinal axis of the housing, and the steam injection mandrel is configured to provide fluid communication between the axial flow bore and the one or more ports through the slot.

Abstract: Disclosed is reclosable sleeve assembly including a housing defining one or more flow ports that provide fluid communication between a wellbore annulus and an interior of the housing, an outer sleeve arranged within the housing and movable between a closed position, where the outer sleeve occludes the one or more flow ports, and an open position, where the one or more flow ports are exposed, and an inner sleeve concentrically arranged within the outer sleeve and defining a plurality of flow slots, the inner sleeve being movable between an open position and a closed position where, when in the open position, the plurality of flow slots are axially aligned with the one or more flow ports.

Abstract: The annular space surrounding a flow tube in a subsurface safety valve is sealingly isolated at opposed ends of the flow tube and pressure compensated to the tubing pressure. The subsurface safety valve is inserted and aligned in an outer housing so that hydraulic operating connections are sealingly aligned with opposite hand split ring seals that are properly compressed when the safety valve is secured in its surrounding housing. The assembly is then able to meet high pressure, heavy debris, and marine environment service requirements for subsea conditions with minimal reconfiguration for what would otherwise serve as a borehole subsurface safety valve.

Abstract: A gas lift valve assembly includes a housing and a check valve. The housing defines an inlet port and an outlet port, and includes an inner casing having a radial outer surface and a radial inner surface at least partially defining a main flow passage. The check valve includes a sealing mechanism disposed around the radial outer surface of the inner casing, and a valve member including an outwardly extending sealing segment. The valve member is moveable between an open position and a closed position in which the sealing segment sealingly engages the sealing mechanism.

Abstract: A setting tool for actuating a well tool within a wellbore includes a sleeve telescopically engaging a mandreland a floating piston disposed between the sleeve and the mandrel. The floating piston has a first face subjected to a downhole hydrostatic pressure. The setting tool also includes a pressure chamber formed between the floating piston and the valve, a working fluid in the pressure chamber, and a fluid-tight collapse chamber formed between the valve and a sealed end of the sleeve. The valve selectively the working fluid from the pressure chamber into the collapse chamber if the working fluid reaches a predetermined primary pressure setting of the valve. The setting tool is connected to and actuated a consumer.

Abstract: A completion assembly for use in a wellbore is disclosed that in one non-limiting embodiment includes a tubular member having at least one packer to isolate a zone between the completion assembly and the wellbore, and a flow control device for closing flow of fluid through the tubular member, the flow control device including a valve that includes a fluid flow path and a seal member configured to close the fluid flow path, and a fluid-activated device that cycles each time a pressure differential is created across the flow path and moves the seal member to close the valve after completion of a selected number of cycles.

Abstract: A safety system for a well having a cable deployed electronic submersible pump includes a barrier valve having a control line for opening and closing the valve, a first flapper safety valve assembly, and a second flapper safety valve assembly. The second flapper safety valve allows the cable for the pump to pass through the second flapper safety valve when the valve is in a closed position. An integral flapper safety valve assembly incorporates the first and second flapper safety valves.

Abstract: A downhole tool comprising an inner sleeve with a plurality of sleeve ports and a housing positioned radially outwardly of the inner sleeve and having a plurality of housing ports, with the housing and inner sleeve partially defining a space radially therebetween. The space is occupied by a shifting sleeve. A fluid path extends between the interior flowpath of the tool and the space. A fluid control device, such as a burst disk, occupies at least portion of the fluid path. In one state, the shifting sleeve is in a first position between the housing ports and the sleeve ports to prevent fluid flow between the interior flowpath and exterior of the tool. The fluid control device may selectively permit fluid flow, and thus pressure communication, into the annular space to cause a differential pressure across the shifting sleeve.

Abstract: The present disclosure relates to downhole tools, including downhole valves, which actuate via a pressure differential created across a shifting element having one or more pressure surfaces isolated from fluid, and fluid pressure, flowing through the interior flowpath. Embodiment downhole tools of the present disclosure may actuate in response to, among other signals, fluid pressure in the interior flowpath of the tool and fluid pressure communicated to a pressure surface of the shifting sleeve from the exterior of the tool. Certain embodiments may also have an outlet connector whereby fluid pressure from the downhole tool may be communicated to its exterior, including to additional tools in the tubing strings via flowlines connecting the two tools.

Abstract: A setting tool for an expandable liner hanger. A method includes the steps of: releasably securing the setting tool to the hanger, the setting tool including an expansion cone for displacing through the hanger; and conveying the setting tool and hanger into the well on a generally tubular work string while no portion of the hanger extends longitudinally between the expansion cone and the work string. A setting tool includes an expansion cone, which is displaceable through the liner hanger to expand the hanger; at least one piston positioned on one side of the expansion cone; and an anchoring device for releasably securing the setting tool to the liner hanger, the anchoring device being positioned on an opposite side of the expansion cone. The expansion cone is pressure balanced between its two sides when the expansion cone is displaced through the liner hanger.

Abstract: According to one aspect of the disclosure, a hydraulic cycle opening sleeve includes a valve assembly and an opening assembly. The valve assembly includes at least one valve chamber and valve piston positioned to move in response to fluid pressure. The opening assembly includes a sliding piston to selectively open or close the hydraulic cycle opening sleeve.

Abstract: A well tool apparatus comprises a control arrangement configured to control response of the downhole tool by varying a bore-annulus pressure difference. The control arrangement includes a valve piston longitudinally slidable in a generally tubular controller housing that is in operation substantially co-axial with the wellbore, to open or close a valve port to a fluid flow connection between the drill string's interior and the tool. A latch mechanism is configured to latch the valve piston against movement in one axial direction, keeping the valve piston in an open or a closed condition. Unlatching of the valve piston requires displacement thereof in the other axial direction to a mode change position. A stay member is automatically displaceable under hydraulic actuation responsive to bore-annulus pressure differences above a trigger threshold value, to obstruct movement of the latched valve piston under hydraulic actuation to the mode change position.

Abstract: A subsurface safety valve is operable to close a fluid flow path by virtue of an axially movable flow sleeve. The valve includes a recockable actuator and a latch mechanism so that the valve can be moved to a closed position without overcoming the pressure head and frictional forces currently encountered in conventional safety valves. The latch mechanism includes one or more micro pistons.

Abstract: A downhole tool comprising a nested sleeve moveable from a closed position to an open position following actuation of a fluid control device. The fluid control device may selectively permit fluid flow, and thus pressure communication, into the annular space to cause a differential pressure across the shifting sleeve, and thereby moving the shifting sleeve to an open position. A static plug seat is positioned in the tubing or casing upwell of the downhole tool. When the shifting sleeve is opened, fluid flow is established through the static plug seat, allowing a dissolvable or disintegrable ball or other plug to engage the plug seat, preventing fluid flow past the plug seat to the opened downhole tool, thereby permitting pressurization of the tubing or casing, such as for a pressure test. Disintegration of the ball allows fluid communication to be re-established with the downhole tool, permitting fluid to flow through the tubing for subsequent operations.