Abstract: An energizing ring can be used to energize a seal. In embodiments, the energizing ring has a recess, or divot, adjacent to a portion of the seal so that if the seal is deformed during a balloon-type failure, a portion of the deformed seal can occupy the recess. The seal, thus, engages surfaces of the recess to prevent axial movement of the energizing ring relative to the seal.

Abstract: The present invention relates to a casing module for being part of a downhole casing system, comprising a base pipe extending in a longitudinal direction and having a circumference, a functional assembly mounted over the base pipe to define a casing module flow path between the functional assembly and the base pipe, and a main flow path arranged substantially in a centre of the base pipe and extending in a longitudinal direction of the casing system, wherein at least a part of the casing module flow path is an annular flow path extending both in the longitudinal direction of the base pipe and continuously around the entire circumference of the base pipe, and the base pipe has end sections at which a plurality of supporting structures protrude from an outer surface to provide support for the functional assembly, the supporting structures defining a plurality of casing module flow paths extending in the longitudinal direction.

Abstract: Disclosed is a well configuration and method of forming the configuration and producing hydrocarbons from the configuration. In one embodiment, multiple fractures are formed from a wellbore in a subterranean hydrocarbon gas formation. One fracture is filled with material to create a flow barrier that modifies the flow pattern of at least one fluid within the subterranean hydrocarbon formation. Also disclosed is the process of injecting a Dew Point altering gas into the formation on one side of the barrier and producing a mixture of formation gas and injected gas from the fractures on the other side of the barrier.

Abstract: Apparatus and methods for completing, treating, and/or producing a wellbore are provided. The apparatus can include a tubular body defining an inner bore, one or more injection inflow control devices, and one or more production inflow control devices. The one or more injection inflow control devices can include one or more first check valves in fluid communication with the inner bore, with each first check valve being configured to allow fluid to flow therethrough from the inner bore to a region of the wellbore, and to substantially block a reverse fluid flow therethrough. The one or more production inflow control devices can include one or more second check valves coupled to the tubular body, each second check valve being configured to allow fluid to flow therethrough from the wellbore to the inner bore and to substantially block a reverse fluid flow therethrough.

Abstract: A flow control device comprises a fluid pathway configured to provide fluid communication between an exterior of a wellbore tubular and an interior of the wellbore tubular, a flow restriction disposed in a fluid pathway, a flow blockage disposed in the fluid pathway, and a retaining member configured to maintain the flow blockage within the fluid pathway and allow access to the flow blockage within the fluid pathway. The flow blockage substantially prevents a fluid flow through the fluid pathway.

Abstract: Apparatus and methods for controlling the flow of fluid, such as formation fluid, through an oilfield tubular positioned in a wellbore extending through a subterranean formation. Fluid flow is autonomously controlled in response to change in a fluid flow characteristic, such as density or viscosity. In one embodiment, a fluid diverter is movable between an open and closed position in response to fluid density change and operable to restrict fluid flow through a valve assembly inlet. The diverter can be pivotable, rotatable or otherwise movable in response to the fluid density change. In one embodiment, the diverter is operable to control a fluid flow ratio through two valve inlets. The fluid flow ratio is used to operate a valve member to restrict fluid flow through the valve.

Abstract: A flow control assembly can be disposed in a wellbore and can include a porous material. The porous material can be a temporary plug in a flow path. The porous material may respond to stimuli in a wellbore by creating a flow path, or otherwise allowing fluid to flow in a flow path. The porous material may be located in a port of tubing or proximate, such as adjacent, to an opening in the port.

Abstract: A method of servicing a subterranean formation comprising placing a wellbore servicing system within a wellbore penetrating the subterranean formation, wherein the wellbore servicing system comprises a first activatable stimulation assembly and a second activatable stimulation assembly incorporated within a tubular string, configuring the wellbore servicing system to provide a route of fluid communication from the first activatable stimulation assembly to a first zone of the subterranean formation, introducing a treatment fluid into the first zone of the subterranean formation via the first activatable stimulation assembly, and embedding a first portion of the wellbore servicing system within the wellbore.

Abstract: An apparatus usable with a well includes a gas lift valve having a check valve arrangement located between an annulus and a passageway of a tubing. The check valve arrangement is adapted to selectively allow fluid flow from the check valve arrangement from an inlet side of the check valve arrangement to an outlet side of the check valve arrangement, and is biased to prevent a leakage flow through the check valve arrangement from the outlet side to the inlet side. The check valve arrangement is defined by a valve element movable into and out of engagement with a valve seat wherein one of the valve element and the valve seat has a first sealing structure engageable with a second sealing structure on the other of the valve element and the valve seat. At least one of the first and second sealing surfaces include at least one pair of sealing members.

Abstract: A fluid flow control device disposable in a bore can include channels that can direct fluid flow based on one or more properties of the fluid more robustly. The channels may include a side channel between two other channels. The side channel can allow fluid flow to affect fluid flowing in one of the channels. Devices according to some aspects can differentiate between fluids having close, but different, properties and direct the fluid accordingly. Examples of fluid properties based on which the device can direct fluid include fluid density, fluid velocity, fluid viscosity, and Reynolds number of the fluid flow.

Abstract: The device is based on the principle of downhole shut-in of oil producing wells that do not flow to surface self-powered but require the injection of gas to lighten the fluid column and thus enable the well to produce. This downhole shut-in device comprises a check valve, an anchoring system, a seal system; an untethering system, a shock absorber and a sleeve for the protection of pressure and temperature memory probes. The objective of the downhole shut-in device is to obtain characteristic information of the fluid-rock system from variations in the pressures recorded in order to obtain the dynamic characterization of the reservoir.

Abstract: A safety valve can be disposed in a wellbore that is through a fluid-producing formation. The safety valve can include a flow tube that is allowed to move at least partially independent, or free, from a piston assembly to avoid negative effects from forces on the flow tube from a closing assembly, such as one including a flapper. For example, the flow tube may not be required to be rigidly connected to a piston assembly such that the flow tube can move more than the piston assembly moves.

Abstract: Linear pressure reducer apparatus for regulating injection pressure of a water-soluble polymer solution in injection wellheads, in an enhanced oil recovery system, including modules connected in series to the main injection pipe and each consisting of tubes of identical diameter but variable length, the apparatus allows variations to be made to pressure drop by adjusting the length of the tube through which the solution flows by closing or opening modules, without substantial degradation to the viscosity of the solution during its passage through the module. Installation for enhanced oil recovery implementing the apparatus.

Abstract: The present invention comprises fire arrestor device a triggering mechanism operatively connected to a well head and a plunger with a plug at one end being connected to the triggering mechanism. A guide and a valve are mounted to an inner surface of oil piping positioned below the well head align the plunger. A plug is formed at the distal end of the plunger, and is seated on a spring below the valve seat. The spring is held in compressed mode during normal operation. In the event of destruction of the well head, the triggering mechanism will melt or break. The spring then urges the plug upward engaging the valve seat and shutting off the fuel flow.

Abstract: A tool that is usable with a well includes a valve element, a mechanical operator, a pressure chamber and a regulator. The valve element has a first state and a second state. The mechanical operator responds to a predetermined signature in an annulus pressure relative to a baseline level of the annulus pressure to transition the valve element from the first state to the second state. The pressure chamber exerts a chamber pressure to bias the mechanical operator to transition from the second state to the first state. The baseline level is capable of varying over time, and the regulator regulates the chamber pressure based on the baseline level.

Abstract: A valve assembly for use in aquifer liquid flow control in accordance with one embodiment can be used to deliver liquid to and/or from at least one selected aquifer in a plural aquifer system. In accordance with an embodiment, the valve can be used to route liquid to or from a first aquifer without delivering liquid to or from a second aquifer, or to or from the second aquifer without delivering liquid to or from the first aquifer. As an aspect of an embodiment, the valve assembly can be used to shut off the flow of liquid to both the first and second aquifers.

Abstract: Techniques and equipment to facilitate controlling flow of a fluid along a flow passage. A flow control assembly is placed along a flow passage, and a bypass is routed past the flow control assembly. Flow along the bypass is controlled by a flow bypass mechanism which may be operated via pressure increase within the flow control assembly. A shear device restricts the opening of the bypass, and a dampening device acts to limit the shear device to exposure of forces from the pressure increase.

Abstract: A bi-stable valve includes a first chamber having a first aperture and a second aperture, and a second chamber having a first aperture and a second aperture. The bi-stable valve also includes a shaft having a first valve member adjacent a first end of the shaft and a second valve member adjacent an opposite second end of the shaft. The shaft is movable between a first position, in which the first valve member closes off the second aperture of the first chamber and the second valve member closes off the second aperture of the second chamber to prevent fluid from passing through the second apertures of the first and second chambers, and a second position, in which the first valve member and the second valve member allow fluid to pass through the second aperture of the first chamber and the second aperture of the second chamber.

Abstract: A downhole fluid flow control system (100). The flow control system (100) includes a flow control component (122) having direction dependent flow resistance created by a vortex chamber (144). Production fluids (140) that travel through the flow control component (122) in a first direction enter the vortex chamber (144) traveling primarily in a tangential direction (148) to experience a first pressure drop. Injection fluids (150) that travel through the flow control component (122) in a second direction enter the vortex chamber (144) traveling primarily in a radial direction (152) to experience a second pressure drop. The pressure drop created by the tangential flow (148) of the production fluids (140) is greater than the pressure drop created by the radial flow (152) of the injection fluids (150).

Abstract: An internal completion string is anchored within a closed casing valve of a production liner in a wellbore. The internal completion string comprises a packer and a shifting tool. The production liner comprises a casing valve having a port and a moveable member. The annulus defined between the production liner and the internal completion string is sealed, and the shifting tool is remotely operated to move the moveable member away from the port, thereby opening the casing valve.

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: Systems and methods for managing pressures present in an annular space defined between casing strings contained within a subterranean well. These systems and methods may include providing a pressure distribution casing that includes a plurality of pressure distribution passages and distributing fluids present within the annular space along a length of the pressure distribution casing and/or between the annular space and the subterranean formation using a portion of the plurality of pressure distribution passages. Pressure distribution passages may be present on an inner surface of the pressure distribution casing, on an outer surface of the pressure distribution casing, and/or within a wall of the pressure distribution casing and may distribute the fluids along the length of the pressure distribution casing without distributing the fluids across and/or through a wall of the pressure distribution casing, such as between the inner surface and the outer surface of the pressure distribution casing.

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 flow control device includes, a body defining at least a portion of a flow passageway, at least one movable member in operable communication with the body, movable between at least a first position that provides a first restriction to flow through the flow passageway and a second position that provides a second restriction to flow through the flow passageway, and a circuit in operable communication with the at least one movable member that is configured to sense conductivity of fluid flowing through the flow passageway and to promote movement of the at least one movable member to move from the first position to the second position in response to a change in conductivity of fluid flowing through the flow passageway.

Abstract: An apparatus usable with a well includes a gas lift valve having a check valve arrangement located between an annulus and a passageway of a tubing. The check valve arrangement is adapted to selectively allow fluid flow from the check valve arrangement from an inlet side of the check valve arrangement to an outlet side of the check valve arrangement, and is biased to prevent a leakage flow through the check valve arrangement from the outlet side to the inlet side. The check valve arrangement is defined by a valve element movable into and out of engagement with a valve seat wherein one of the valve element and the valve seat has a first sealing structure engageable with a second sealing structure on the other of the valve element and the valve seat. At least one of the first and second sealing surfaces include at least one pair of sealing members.

Abstract: A well system can include a flow control device which regulates flow of a fluid from an interior of the device outwardly through an exit port, and a deflector which outwardly overlies the exit port and provides fluid communication between the exit port and an annulus formed radially between the deflector and a wellbore lining. The deflector can diffuse the flow of the fluid prior to impingement on the wellbore lining. A flow control assembly can include a flow control device which regulates flow of a fluid from an interior of the device outwardly through an exit port, and a deflector which outwardly overlies the exit port, the deflector including at least one opening, and the opening being circumferentially offset relative to the exit port. A form of an interior surface of the deflector and/or an exterior surface of the flow control device can diffuse the flow of the fluid.

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 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: 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 method and apparatus for commingling sweet gas and sour gas production in a gas well having an upper sweet zone and a lower sour zone. The apparatus comprises a commingling valve which prevents cross flow of sour fluids into the sweet zone or casing annulus.

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: 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: Apparatus (10) for restricting a flow of fluid through a bore (14) comprises a bore sealing member (12a) and an actuation assembly for moving the bore sealing member (12a) between first and second configurations. The actuation assembly is configured to isolate first and second end portions (46, 48) of the activation member (12a) from a bore fluid (50). The apparatus (10) provides for moving the bore sealing member (12a) between the first and second configurations without a bore fluid (50) pressure acting on an end portion (46, 48) of the activation member (12a).

Abstract: A well screen assembly includes a tubular base pipe. The base pipe has a sidewall aperture that communicates fluid between an interior central bore of the base pipe and an exterior of the base pipe. A filtration screen is around the base pipe. The filtration screen defines a lateral fluid passage along a axial length of the well screen assembly. A flow control device is coupled to the base pipe and the filtration screen. The flow control devices includes a ring sealing the lateral fluid passage from the central bore. An elongate restrictor passage is in the ring, oriented longitudinally. The elongate restrictor passage is configured to communicate fluid between the lateral fluid passage and the central bore. The restrictor passage includes an internal, square edged orifice defined by a fixed, annular protrusion. The annular protrusion extends inwardly from an interior surface of the restrictor passage.

Abstract: A valve device for use in a side pocket and/or sub in a well, having a housing (1) with a first port (2) and a second port (3), a first valve body (11) movably mounted internally in the housing(1), a second valve body (20) mounted internally in the housing (1) and movable relative to both the housing (1) and the first valve body (11), where a first locking device (A) is configured between the first valve body (11) and the second valve body (20) in order to lock the movement of the first valve body (11) relative to the second valve body (20) in one direction and in such a manner that when the first locking device (A) is activated, the first valve body (11) is held in an open position as long as the second valve body (20) is in an open position.

Abstract: A velocity string deploys in production tubing of a gas well (or a gassy oil well) to help lift fluid toward the surface. The velocity string reduces flow area in the production tubing so that a critical flow velocity can be reached to lift liquid. Overtime, the reservoir pressure and resulting gas flow may decrease such that less liquid is produced toward the surface. At such a stage, operators then expand the velocity string to further decrease the flow area in the production tubing, which can produce the needed critical flow velocity to allow produced liquid to be lifted toward the surface.

Abstract: An apparatus for use in controlling first and second downhole tools includes a first cyclical indexing mechanism associated with a first downhole tool, and a second cyclical indexing mechanism associated with a second downhole tool, wherein the first indexing mechanism defines at least three sequential indexing positions within a cycle and the second indexing mechanism defines at least two sequential indexing positions within a cycle. The apparatus includes at least one actuator for actuating the first and second indexing mechanisms in response to a common stimulus to cause said first and second indexing mechanisms to advance between respective indexing positions so as to permit co-ordination of the operational states of the associated first and second downhole tools. The apparatus may be used for controlling first and second under reamers or for controlling an under reamer and a corresponding stabilizer.

Abstract: A completions assembly that includes an extendable and retractable shifting tool at a lower end of an upper completion. Outfitted with this type of tool, the upper completion may be sealably landed out at an installed lower completion without prematurely opening an isolation valve that ensures well control thereat. Rather, the full completions assembly may be finished out and the valve later opened by extending of the shifting tool from the upper completion toward the isolation valve at the lower completion. Once more, this type of well control is achieved through use of hydraulic lines that are dedicated to the upper completion even though the isolation valve is located therebelow. As a result, the extended use of hydraulic couplings and other complex or wear-prone well control architecture may be largely avoided.

Abstract: A service tool and methods for performing subterranean hydrocarbon services in a wellbore. The service tool can include a body that having an aperture formed therethrough. A valve system can be connected to the body. The valve system can selectively form a flow path between a first portion of the aperture and a second portion of the aperture; a flow path between a first flow port formed through a first portion of the body, the aperture, and the outer diameter of the body; and/or a flow path between a channel formed in a portion of the body, a second flow port formed through a second portion of the body, and the second portion of the aperture.

Abstract: A method of variably restricting flow in a subterranean well can include resisting flow through a flow path, and then selectively opening a pressure barrier which previously prevented flow through another flow path. The flow paths are configured for parallel flow. A flow restrictor system for use with a subterranean well can include at least two flow paths configured for parallel flow, a flow restrictor which resists flow through one flow path, and a pressure barrier which prevents flow through another flow path. The pressure barrier is selectively openable to permit flow through the second flow path.

Abstract: Apparatus and methods for controlling the flow of fluid, such as formation fluid, through an oilfield tubular positioned in a wellbore extending through a subterranean formation. Fluid flow is autonomously controlled in response to change in a fluid flow characteristic, such as density or viscosity. In one embodiment, a fluid diverter is movable between an open and closed position in response to fluid density change and operable to restrict fluid flow through a valve assembly inlet. The diverter can be pivotable, rotatable or otherwise movable in response to the fluid density change. In one embodiment, the diverter is operable to control a fluid flow ratio through two valve inlets. The fluid flow ratio is used to operate a valve member to restrict fluid flow through the valve.

Abstract: An inflow control device laterally insertable in a wall of a tubular, the inflow control device includes a plug shaped body having a first section and a second section, the first section having an orifice accessible to an interior of the tubular and the second section having an opening accessible to an exterior of the tubular, the orifice in fluid communication with the opening; and a selectable insert insertable into the orifice, the insert having an inner periphery providing a flow path between the exterior and interior of the tubular. Also, included is a production string and adjustable orifice inflow control device combination.

Abstract: An electronic module for use as a subsea electronic module for an underwater fluid extraction well, wherein a local area network enables communication within the module, the local area network including a plurality of interfaces with components of the network, and wherein the interfaces comprise capacitive coupling interfaces.

Abstract: A method of installing a wellbore junction assembly in a well can include connecting at least two tubular strings to one opposite end of a tubular string connector with similarly dimensioned oriented connections, whereby the tubular strings are interchangeably connectable to the connector by the oriented connections. A wellbore junction assembly can include at least two tubular strings and a tubular string connector having opposite ends. Each of the tubular strings may be secured to one opposite end of the connector by oriented connections, whereby each of the tubular strings has a fixed rotational orientation relative to the connector. A well system can include a tubular string connector, each of first and second tubular strings being secured to the connector, and a support which reduces bending of the second tubular string which results from deflection of the second tubular string from one wellbore section into another wellbore section.

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 downhole actuation system comprises an actuation mechanism comprising an indicator; a wellbore tubular; and a collet coupled to the wellbore tubular. The collet comprises a collet protrusion disposed on one or more collet springs, and the collet protrusion has a position on the one or more collet springs that is configured to provide a first longitudinal force to the indicator in a first direction and a second longitudinal force to the indicator in a second direction. The first longitudinal force is different than the second longitudinal force.

Abstract: A downhole fluid flow control system (100). The downhole fluid flow control system (100) includes a flow control component (122) having an internal flow path (134) and a temporary sealing substance (136) disposed within the internal flow path (134). During installation of the downhole fluid flow control system (100) in a well, the temporary sealing substance (136) prevents fluid flow through the flow control component (122), which prevents plugging or clogging of the internal flow path (134). After installation, the temporary sealing substance (136) degrades when exposed to a water source in the well, which enables fluid flow through the flow control component (122) and thus proper operation of the fluid flow control system (100).

Abstract: A variable flow resistance system can include a vortex device, with resistance to flow of a fluid composition through the vortex device being dependent on a rotation of the fluid composition at an inlet to the vortex device. Another system can include a second vortex device which receives a fluid composition from an outlet of a first vortex device, a resistance to flow of the fluid composition through the second vortex device being dependent on a rotation of the fluid composition at the outlet. Another system can include a first vortex device which causes increased rotation of a fluid composition at an outlet thereof in response to an increase the fluid composition velocity, and a second vortex device which receives the fluid composition from the outlet, a flow resistance through the second vortex device being dependent on the rotation of the fluid composition at the outlet.

Abstract: A modulator is disclosed for creating a pressure pulse in a fluid-filled well. The modulator comprises a tool body on which a plurality of extendable arms are mounted. The arms may be retracted into a stowed position substantially adjacent the tool body, or may be extended to meet the wall of the borehole. The arms are preferably resilient bowsprings that may be flexed outwards from the tool by means of an actuator pushing on at least one end of the springs. A flexible valve sleeve or bag is suspended between the arms and cooperates with a valve mounted adjacent the sleeve on the tool body. The valve sleeve creates a fluid-flow path through the valve, and in operation, the valve closes one end of the valve sleeve to create the pressure pulse. Sealing of the valve sleeve against the wall of the well is a result of the fluid pressure inflating the sleeve against the well wall. As a result, sealing takes place over an extended area of the bag and is dynamically responsive to changes in fluid flow or pressure.

Abstract: An equalization valve that allows for continuous equalization of pressure above and below a sealing element is disclosed. The equalization valve includes a housing having a fluid passageway therethrough. The fluid passageway is fluidically continuous across a sealing element disposed on a mandrel. The mandrel is part of a sealing assembly that contains the sealing element. The equalization valve includes a valve plug moveable from an open position in which the valve plug is not engaged with the sealing mandrel to a seated position in which the valve plug is seated against the sealing mandrel. The valve plug defines a conduit, the conduit that provides for a minimal fluid flow across the sealing element, when the valve plug is seated against the sealing mandrel. The sealing element remains sealingly engaged against the wellbore while the plug is in the seated position and while minimal fluid flow is occurring.