Abstract: A subsea completion for a well is presented that includes a tubing spool, a tubing hanger, a fluid coupling, an electrical coupling, a control system, a valve, and a production tree. The tubing spool includes a central bore, a side wall, and a fluid supply passage extending through the tubing spool. An electrical supply passage can also extend through the side wall of the tubing spool. The tubing hanger includes a fluid control passage. The tubing hanger can also include an electrical control passage. The control system includes a fluid control conduit to provide fluid to the tubing spool fluid supply passage from outside the tubing spool. The valve is connectable to the outside of the tubing spool to control fluid flow between the control system fluid conduit and the tubing spool fluid supply passage.

Abstract: A flow stop valve positioned in a downhole tubular, particularly a flow stop valve which may be used with a dual density fluid in deep sea drilling or cementing application. The flow stop valve includes a housing and first and second receiving portions attached to first and second ends of the housing. A flow through the valve is selectively permitted between the housing and the first and second receiving portions. A valve element, such as a spindle, is slidably received in the first and second receiving portions. The valve element and housing together form a valve to selectively prevent flow through the flow stop valve. A first end face of the valve element and the first receiving portion define a first chamber and a second end face of the valve element and the second receiving portion define a second chamber.

Abstract: A selective sleeve system includes, a tubular, a sleeve movably disposed at the tubular, and a movable member having at least one dog radially biased and configured to be radially displaceable into a recess. The at least one dog is positionable perimetrically adjacent to at least one tab, subsequent displacement into the recess to radially overlap with the sleeve sufficiently to move the sleeve relative to the tubular upon movement of the movable member relative to the tubular.

Abstract: A system for selectively actuating multiple load devices, such as well tools, which are selectively actuated by applying a predetermined voltage across a predetermined pair of conductors. At least one lockout device is associated with each load device. The lockout device prevents current from flowing through the respective load device until voltage across the pair of the conductors exceeds a predetermined minimum. A method is provided for selecting well tools for actuation by applying a minimum voltage across a set of conductors and a lockout device. Leak paths are prevented from draining off current by the lockout devices. A system is provided for applying current to bidirectional load devices such as downhole pumps and motors.

Abstract: A bridge plug can be deployed downhole and retrieved using a retrieval tool disposed on jointed or coiled tubing or on another bridge plug. Internally, the bridge plug has a sleeve that is movable on a stem of the plug's tailpiece. When in a first position, the sleeve prevents fluid communication through ports in the stem so that circulated fluid from the retrieval tool can be used to clear debris from the plug during retrieval. When the retrieval tool engages the sleeve in the plug, pulling up on the tool moves the sleeve to an intermediate position in which fluid pressure is equalized across the plug. Further pulling up on the tool locks the sleeve in a further position on the stem so that circulated fluid from the retrieval tool will pass directly to the stem's ports. Movement of the sleeve by the retrieval tool also releases the engaged slips and packing element on the bridge plug's mandrel.

Abstract: A method can include closing a valve interconnected between sections of a washpipe of a service tool string by displacing the service tool string relative to a completion string, thereby preventing flow through the washpipe. A well system can include a service tool string reciprocably received in a completion string, the service tool string including a washpipe received in a well screen, and a valve which selectively permits and prevents flow through the washpipe. The completion string can include a structure which operates the valve in response to displacement of the service tool string relative to the completion string. Another method can include closing a valve by partially withdrawing a service tool string from a completion string, thereby preventing flow through a washpipe of the service tool string.

Abstract: A downhole fluid flow control system includes a fluidic module (150) having a main fluid pathway (152), a valve (162) and a bridge network. The valve (162) has a first position wherein fluid flow through the main fluid pathway (152) is allowed and a second position wherein fluid flow through the main fluid pathway (152) is restricted. The bridge network has first and second branch fluid pathways (163, 164) each having a common fluid inlet (166, 168) and a common fluid outlet (170, 172) with the main fluid pathway (152) and each including two fluid flow resistors (174, 176, 180, 182) with a pressure output terminal (178, 184) positioned therebetween. In operation, the pressure difference between the pressure output terminals (178, 184) of the first and second branch fluid pathways (163, 164) shifts the valve (162) between the first and second positions.

Abstract: A valve and method of use wherein the valve includes a housing having an axial flowbore defined along its length. A lateral fluid flow port is disposed through the housing. A piston sleeve is disposed within the flowbore and is selectively moveable to block flow through the lateral flow port. The valve can be moved between operating positions wherein flow through the lateral flow port is blocked or allowed and axial flow through the flowbore is blocked or permitted.

Abstract: An automatic vent valve and method for use is provided equalizing the pressure in at least two lines. A housing has a first piston that compresses a bias device when the second pressure source supplies sufficient pressure. Upon a sufficient reduction in pressure the first piston releases a second internally held coaxial piston to allow fluid to flow from a first pressure source towards a second pressure source, thereby equalizing the pressure between the two pressure sources.

Abstract: Systems and methods for improving functional access to subterranean formations that include a well, which includes a casing string having at least one casing conduit that extends and provides a hydraulic connection between a surface region and the subterranean formation. Performing a plurality of downhole operations utilizing a casing string that constitutes a plurality of hydraulic pathways between the surface region and the subterranean formation. In some embodiments, the plurality of downhole operations may be simultaneous operations and/or may be associated with at least one of a plurality of operational states including a drilling state, completing state, stimulating state, producing state, abandoning state, and/or killing state. In some embodiments, systems and methods may include a plurality of production control assemblies to control and/or monitor the downhole operations.

Abstract: A method for communicating a signal to an instrument in a wellbore includes axially accelerating the instrument in a preselected pattern of acceleration. The predetermined pattern corresponds to the signal to be communicated. The axial acceleration of the instrument is detected, and the signal is decoded from the detected axial acceleration. A signal detection system for an instrument in a wellbore includes an accelerometer oriented along a longitudinal axis of the instrument and means for comparing measurements made by the accelerometer to at least one predetermined pattern.

Abstract: A wellbore tubular set concentrically between an inner an and outer annulus has a pressure relief valve that opens when pressure in the outer annulus exceeds pressure in the inner annulus by an amount that can damage the tubular. The relief valve closes and reseats when the pressure differential is reduced to below the damaging threshold. The relief valve can include a spring for reseating the valve. A pressure gauge can be included within the outer annulus for monitoring whether or not the relief valve is operating properly.

Abstract: A valving system includes a tubular and a sleeve slidably engaged with the tubular having a seat thereon. The sleeve is configured to occlude flow from an inside of the tubular to an outside of the tubular when in a first position, allow flow between an inside of the tubular and an outside of the tubular at a first location upstream of the seat and a second location downstream of the seat when in a second position, and allow flow between an inside of the tubular and an outside at the tubular at the first location and not the second location when in a third position. The valving system also includes a disappearing member in operable communication with the tubular and the sleeve configured to prevent movement of the sleeve to the third position until disappearance thereof.

Abstract: A valve assembly (2) which is configured to be coupled to a tubing string comprises a housing (8) defining a housing flow path (9) for communicating with the tubing string, and a barrier member (14) located in the housing (8) and configurable between a normally-closed position in which the barrier member (14) restricts access through the housing flow path (9), and an open position in which access is permitted through the housing flow path (9). The valve assembly (2) also comprises a bypass arrangement reconfigurable between an open state in which the bypass arrangement defines a bypass flow path that communicates with the housing flow path (9) on opposite sides of the barrier member (14) to permit fluid to bypass the barrier member and thereby fill the tubing string, and a closed state in which fluid is prevented from bypassing the barrier member to thereby permit pressurization of the tubing string.

Abstract: A method of variably restricting flow in a subterranean well can include resisting the flow through a sidewall of a tubular string, and then selectively opening a device in response to a predetermined pressure signal being transmitted. The opening of the device can substantially reduce a resistance to the flow through the tubular string sidewall. A flow restrictor system for use with a subterranean well can include a flow restrictor which resists flow through system, a pressure sensor, and an initially closed device which opens and thereby permits the flow to bypass the flow restrictor, in response to a predetermined pressure signal being detected by the sensor.

Abstract: A downhole circulating valve includes a generally tubular outer housing having a generally axially extending internal passageway. At least one generally longitudinally extending circulating passageway is formed through at least a portion of the housing. At least one exterior port and at least one interior port are in fluid communication with the circulating passageway. At least one seal plug is disposed within the circulating passageway. The seal plug has a first position relative to the housing wherein the seal plug is remote from the exterior port and the interior port, thereby allowing fluid flow between the exterior port and the interior port through the circulating passageway. The seal plug has a second position relative to the housing wherein the seal plug is between the exterior port and the interior port and wherein the seal plug forms at least one metal-to-metal seal with the circulating passageway, thereby preventing fluid flow between the exterior port and the interior port.

Abstract: Wellbore flow control devices can be used in various subterranean operations to regulate access of formation fluids to the interior of a wellbore pipe and/or to limit the access of unwanted fluids thereto. Coupling of flow regulating assemblies to one another in the wellbore flow control devices can result in improved operational performance in regulating formation fluid flow to the interior of the wellbore pipe compared to using the flow regulating assemblies in an uncoupled state. Wellbore flow control devices can comprise a gate valve assembly that is in fluid flow communication with a flow restricting assembly, where each assembly is located on the exterior of a wellbore pipe and the flow restricting assembly is in fluid flow communication with the interior of the wellbore pipe.

Abstract: A wellbore servicing apparatus comprising a housing defining an axial flowbore and comprising one or more ports providing a route of fluid communication between the axial flowbore and an exterior of the housing, a sliding sleeve disposed within the housing and comprising a seat and an orifice, the sliding sleeve being movable from a first position in which the ports are obstructed by the sliding sleeve to a second position in which the ports are unobstructed by the sliding sleeve, and the seat being configured to engage and retain an obturating member, and a fluid delay system comprising a fluid chamber containing a fluid, wherein the fluid delay system is operable to allow the sliding sleeve to transition from the first position to the second position at a delayed rate.

Abstract: Well operating elements are described, one embodiment comprising a first component that is substantially non-dissolvable when exposed to a selected wellbore environment and a second component that is soluble in the selected wellbore environment and whose rate and/or location of dissolution is at least partially controlled by structure of the first component. A second embodiment includes the component that is soluble in the selected wellbore environment, and one or more exposure holes or passages in the soluble component to control its solubility. The second embodiment may or may not include a substantially non-dissolvable component. Methods of using the well operating elements in oilfield operations are also described. This abstract allows a searcher or other reader to quickly ascertain the subject matter of the disclosure. It will not be used to interpret or limit the scope or meaning of the claims.

Abstract: When injecting liquids into the ground, imposing pulses on the injected liquid is effective to increase penetration and saturation of the ground. Imposing suckback onto the pulses is effective to make the liquid in the ground behave as a coherent unitary body, surging out and back each pulse, and to super-saturate the ground. The tool includes a suckback-chamber, which is timed to open to the ground formation just as the pulse-valve closes. A biasser (e.g a spring) drives the chamber open and sucks in some of the liquid from the ground. The chamber is then emptied, back to the ground, by the rising pressure as the pulsing tool is recharged. The suckback-chamber can be added to any type of pulsing tool.

Abstract: A downhole tool and method for performing to provide a flow path from an inner bore thereof to a wellbore annulus, wherein the flow path is provided upon the application of pressure.

Abstract: A bypass assembly for use in a downhole tool comprises a chamber, a first fluid port in fluid communication with the chamber, a second fluid port in fluid communication with the chamber, a flow restrictor disposed in a first flow path between the first fluid port and the second fluid port, a piston moveable in a first direction by the application of a first fluid pressure, a biasing member, and a restraining member disposed adjacent to the piston. The biasing member biases the piston to move in a second direction opposite the first direction, and the restraining member is actuated by movement of the piston in the first direction in response to a predetermined fluid pressure. Movement of the piston in the second direction to a predetermined position configures the bypass assembly to divert fluid flow around the flow restrictor along a second flow path.

Abstract: A method of propagating pressure pulses in a well can include flowing a fluid composition through a variable flow resistance system which includes a vortex chamber having at least one inlet and an outlet, a vortex being created when the fluid composition spirals about the outlet, and a resistance to flow of the fluid composition alternately increasing and decreasing. The vortex can be alternately created and dissipated in response to flowing the fluid composition through the system. A well system can include a variable flow resistance system which propagates pressure pulses into a formation in response to flow of a fluid composition from the formation.

Abstract: A method and apparatus is disclosed for remotely and selectively controlling fluid flow through tubular string disposed within a wellbore and further control fluid flow between the tubular string inner flow passage and the annular flow passage. The present invention further discloses a method of selectively and remotely receiving and interpreting a form of command or information at a desired apparatus within the wellbore caused by the operator on earth surface.

Abstract: A method of simultaneously stimulating at least a first zone and a second zone of a subterranean formation comprises: flowing a fluid through at least a first flow rate restrictor and a second flow rate restrictor, wherein: (A) the first flow rate restrictor is located adjacent to the first zone, (B) the second flow rate restrictor is located adjacent to the second zone, (C) the first and second flow rate restrictors are connected in parallel, and (D) as at least one of the properties of the fluid changes, the flow rates of the fluid exiting the first and second flow rate restrictors are similar within a flow rate range; and allowing the fluid to stimulate at least the first zone and the second zone.

Abstract: According to an embodiment, an exit assembly comprises: a first fluid inlet; a first fluid outlet; and at least one fluid director, wherein the fluid enters the exit assembly in one direction, in another direction, or combinations thereof, and wherein the at least one fluid director induces flow of the fluid rotationally about the assembly when the fluid enters in the one direction and impedes flow of the fluid rotationally about the assembly when the fluid enters in the another direction. In another embodiment, the exit assembly includes two or more fluid inlets. According to another embodiment, a flow rate restrictor comprises: a fluid switch; and the exit assembly. According to another embodiment, the flow rate restrictor is for use in a subterranean formation.

Abstract: A control mechanism for a downhole tool including a mandrel having a throughbore, at least one activation port, and at least one bypass port, a first sleeve detachably mounted within the throughbore at a first position and moveable to a second position, the first sleeve having a first seat, and a second sleeve detachably mounted within the throughbore at a third position located axially above the first position and moveable to a fourth position, the second sleeve having a second seat. A method of hydraulically actuating and deactuating a downhole tool, the method including disposing the downhole tool and a control mechanism in a well.

Abstract: Presented are apparatus and methods for pump-through fluid loss control. In one embodiment, the fluid loss control device is positioned in a wellbore having a first and a second one-way valve therein. The first one-way valve is openable in response to a first, selected differential pressure acting upward across the first one-way valve. For example, fluid pumped from an ESP from below the device acts to open the first one-way valve. Fluid is flowed upward through the device through the first one-way valve while the second one-way valve is closed. The first one-way valve is closed by reducing the first differential pressure across the first one-way valve, for example, by turning off the ESP. The second one-way valve is opened in response to a second, selected differential pressure acting downward across the valve. Fluid is flowed downward through the second one-way valve while the first one-way valve is closed.

Abstract: A method and apparatus for conducting a reverse flow operation. The apparatus may be lowered into a wellbore on a work string, and includes an opening device, a closing device, and a locking device disposed in a housing. Pressurized fluid supplied through the work string may actuate the opening device to open fluid flow through ports in the housing. Pressurized fluid from the annulus may be supplied through the port in the reverse flow direction to actuate the locking device to enable fluid flow up through the work string back to the surface, and to release the closing device. Pressurized fluid supplied through the work string may actuate the closing device to close fluid flow through the ports in the housing.

Abstract: Methods and related systems are described for controlling inflow of fluid into a production string. In aspects, the invention provides an inflow control device with a shut-off feature that is operated automatically utilizing swellable materials.

Abstract: Devices, systems and related methods control a flow of a fluid between a wellbore tubular and a formation using a flow control device having a flow space formed therein; and a flow control element positioned in flow space. The flow control element may be configured to flex between a first radial position and a second radial position to in response to a pressure differential along the flow space.

Abstract: An apparatus is described for controlling fluid flow in a downhole tubular. Fluid is flowed through a flow control system having a flow ratio control system and a pathway dependent resistance system. The flow ratio control system has a first and second passageway, where the ratio of fluid flowing through the passageways dependent on a characteristic of the fluid flow. The pathway dependent resistance system includes a vortex chamber with a first inlet directing flow primarily tangentially into the vortex chamber and the second inlet directing flow primarily radially into the vortex chamber. Undesired fluids, such as gas or water, in an oil well, are directed, based on their relative fluid flow characteristics, into the vortex primarily tangentially, thereby restricting flow when the undesired fluid is present.

Abstract: A completion system, including a lower completion initially fluidly open. A production string is included having a removable plug configured to impede fluid flow through the production string. The removable plug is run in with the production string. An intermediate completion assembly is included that couples the lower completion to the production string. The intermediate completion assembly has a packer device and a barrier valve. The packer device is operatively arranged to be set by pressurizing fluid in the production string against the removable plug. The barrier valve is operatively arranged for selectively impeding fluid flow between the production string and the lower completion after the removable plug is removed. A method of completing a borehole is also included.

Abstract: A retrofit assembly for functionally replacing a fluid isolation valve disposed in a borehole above a lower completion, including a barrier valve operatively arranged to selectively isolate the lower completion when the fluid isolation valve is open. The barrier valve is transitionable between an open position and a closed position due to engagement with an upper completion string. A packer device is included and operatively arranged to isolate a formation in which the borehole is formed. A method of retrofitting a completion system is also included.

Abstract: A completion system for arrangement in a borehole including a lower completion, an upper completion string, and an intermediate assembly engaged between the lower completion and the upper completion string. The intermediate assembly includes a single barrier valve only. The barrier valve is operatively arranged to be transitionable to an open position when engaged with the upper completion string and transitions to a closed position via the upper completion string when the upper completion string is pulled out of the borehole. A method of completing a borehole is also included.

Abstract: A technique that is usable with a well includes deploying a plurality of location markers in a passageway of the well and deploying an untethered object in the passageway such that the object travels downhole via the passageway. The technique includes using the untethered object to sense proximity of at least some of the location markers as the object travels downhole, and based on the sensing, selectively expand its size to cause the object to become lodged in the passageway near a predetermined location.

Abstract: A downhole circulating valve includes a generally tubular outer housing having an axially extending internal passageway including an internal seat and at least one generally radially extending opening formed through the housing intersecting the internal seat. A valve element is rotatably disposed within the internal passageway. The valve element has an axially extending internal bore and a head portion disposed at least partially within the internal seat. The head portion includes at least one generally radially extending seal element. The valve element has a first position relative to the housing, wherein the seal element is not aligned with the opening, thereby allowing fluid communication between the opening and the internal passageway.

Abstract: For injecting e.g. water into ground formation around a borehole, and for superimposing pulses onto the outflow of the injected water, it is important that the pulses have a rapid rise-time. A piston is connected to a pulse-valve of the tool. A bias spring urges the piston towards its closed position. The piston is urged towards the open position by a differential PDAF between the supplied accumulator-pressure and the in-ground formation-pressure. When the pulse-valve is open, the PDAF is falling, until the force of the spring closes the pulse-valve. Then the PDAF rises, but now the PDAF acts over only a small area of the piston. When the PDAF is high enough to ease the pulse-valve open, suddenly the whole area of the piston is exposed to the PDAF, whereby the pulse-valve opens violently.

Abstract: A method of producing liquid hydrocarbons from a subterranean formation can include flowing the liquid hydrocarbons from the formation through at least one valve, and increasingly restricting flow through the valve in response to pressure and temperature in the formation approaching a bubble point curve from a liquid phase side thereof. A method of producing gaseous hydrocarbons from a subterranean formation can include flowing the gaseous hydrocarbons from the formation through at least one valve, and increasingly restricting flow through the valve in response to pressure and temperature in the formation approaching a hydrocarbon gas condensate saturation curve from a gaseous phase side thereof.

Abstract: Methods and apparatus enable reliable and improved isolation between two portions of a bore extending through a casing string disposed in a borehole. A downhole deployment valve (DDV) may provide the isolation utilizing a valve member such as a flapper that is disposed in a housing of the DDV and is designed to close against a seat within the housing. The DDV includes an operating mechanism for opening/closing the DDV. In use, pressure in one portion of a well that is in fluid communication with a well surface may be bled off and open at well surface while maintaining pressure in another portion of the casing string beyond the DDV.

Abstract: Apparatuses and methods used for actuating downhole tools in which a ball is dropped from a surface of a wellbore until it contacts a ball seat of a downhole tool. The ball seat moves axially downward within the downhole tool and an expandable ball seating surface of the ball seat radially expands to pass the ball. The ball seat then moves axially upward within the downhole tool.

Abstract: A control mechanism for use with a safety valve adapted to seal a wellbore is described. The control mechanism comprises at least one valve actuator for engaging with the safety valve, the at least one actuator being moveable, in use, between a valve open position in which the safety valve is open and a valve closed position, in which the safety valve is closed. The control mechanism further comprises biasing apparatus adapted to bias the at least one valve actuator to the valve closed position, wherein, in use, the at least one valve actuator extends from the safety valve up to a wellbore wellhead. In one described embodiment, the safety valve is moved between the open and closed positions by movement of the at least one valve actuator with respect to the wellbore.

Abstract: This disclosure relates to system and method for delaying actuation using a destructible impedance device. In one embodiment, a delayed actuating system can comprise a base pipe comprising a first portion of an orifice, a sliding sleeve around the base pipe, the sliding sleeve comprising a second portion of said orifice, further said sliding sleeve maneuverable into a first position, wherein said first portion of said orifice rests at least partially over said second portion of said orifice, a second position, a distance away from said second position. Further, the delayed actuating system can comprise a biasing device biasing the sliding sleeve toward the second position, and a destructible impedance device at least partially in side said orifice, the destructible impedance device preventing the sliding sleeve from leaving the first position.

Abstract: Surface controlled subsurface control valves for use in wells and methods of controlling the same. In one embodiment, a valve includes a valve body, a bore closure assembly, a mechanical linkage, a drive assembly, and a control assembly. The valve body defines a bore for fluid to flow through when the bore closure assembly is in an open position. When the bore closure assembly is in its closed position, the bore closure assembly prevents fluid from flowing through the bore. The mechanical linkage is operatively connected to the bore closure assembly and to the drive assembly. The primary control assembly determines a force to apply to the mechanical linkage based on a present operating condition of the valve and causes the drive assembly to apply the determined force to the mechanical linkage. As a result, the mechanical linkage drives the bore closure assembly.

Abstract: This disclosure relates to an improved system and method for fracturing a well. In one embodiment, the system can comprise a base pipe comprising an insert port capable of housing a stop ball partially within the chamber of it, and a sliding sleeve. The sliding sleeve can comprise a first sleeve with an in inner surface. That inner surface can comprise a void. The first sleeve can be maneuverable into two positions. In the first position, the void can rest on a surface of the base pipe not comprising an insert port. Such positioning can prevent a stop ball from exiting the chamber of the base pipe. In the second position, the void can rest over an insert port. Such positioning can allow the stop ball to the chamber of said base pipe and to enter the void.

Abstract: Methods and apparatus enable reliable and improved isolation between two portions of a bore extending through a casing string disposed in a borehole. A downhole deployment valve (DDV) may provide the isolation utilizing a valve member such as a flapper that is disposed in a housing of the DDV and is designed to close against a seat within the housing. The DDV includes an operating mechanism for opening/closing the DDV. In use, pressure in one portion of a well that is in fluid communication with a well surface may be bled off and open at well surface while maintaining pressure in another portion of the casing string beyond the DDV.

Abstract: An isolation and control system including a valve; a stroker operative to shift the valve between open and closed positions; and at least one control line operative to pressurize the stroker responsive to tubing pressure. Also included is a method for isolation and control in a borehole including running a plug having a pathway defined therein that leads to tubing pressure at one end and to the at least one control line at the other end to a system including a valve.

Abstract: A method for preventing undesired cement flow in a well containing a tubing string, comprises: determining a desired pressure drop for a desired flow rate at a desired location in the tubing string, determining a flow area that will cause the desired pressure drop, and installing in the tubing string a choke having at least one port, wherein the total area of the port or ports equals the desired flow area. The choke may include at least two ports, one of which may include a least one rupture disk disposed selected to rupture when the pressure drop across the choke exceeds a predetermined value. The choke may be below a float collar in the well. The invention allows the use of foamed cement and in particular foamed cement having a density that is less than the lowest density that could have been used if the choke were not in place.

Abstract: Disclosed herein is a segmented seat for use in wellbore servicing systems, comprising an annular-shaped seat with an upward facing surface for receiving an obturator, the seat defining a central passageway. The seat comprises one or more slots or passageways and, wherein at least one slot or passageway extends continuously between seat segments. The at least one slot or passageway contains a nonmetallic material suitable for retaining the segments together yet frangible or flexible enough to allow the segments to separate when forced to do so. The segments have gripping surfaces which prevent or inhibit rotation of the seat during removal.

Abstract: An actuation system, including a first member having a first profile engagable with a tool operatively arranged for actuating the member from an initial configuration to an actuated configuration. A second member is included that is movable relative to the first member. The second member has a lockout feature configured to prevent engagement of the first member with the tool while the second member is located proximate to the first member. A method of selectively actuating a system is also included.