Abstract: A tube wave reduction system for a borehole includes a tubular member; one or more openings in the tubular member, the one or more openings having a through-passage and a deformation region surrounding the through-passage; and an absorber in fluid communication with the one or more openings. Also included is a method for reducing an effect of a tube wave.

Abstract: An apparatus for engaging and moving a ram block. In some embodiments, the apparatus, or ram block changer, includes a support bracket coupled to a blowout preventer and an articulated arm releasably coupled to the ram block. The ram block changer may further include a pivot coupling assembly having a first axis of rotation. The pivot coupling assembly extends through the support bracket and the articulated arm, wherein the articulated arm is rotatable about the first axis of rotation relative to the support bracket. The articulated arm may include a first member receiving the pivot coupling assembly therethrough, a second member coupled to the ram block, and a second pivot coupling assembly having a second axis of rotation spaced apart from the first axis of rotation and extending through the first and second members. The second member is rotatable about the second axis of rotation relative to the first member.

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: A selective downhole tool including a tubular having a longitudinal bore enabling passage of fluids there through. Having a valve opening in a wall of the tubular. An expandable ball seat selectively movable between a first size sized to trap a ball to block flow through the tubular. A larger second size sized to release the ball through the tubular. A valve cover longitudinally movable within the tubular, the valve cover including a dissolvable insert. Also included is a method of operating a downhole tool.

Abstract: A system, including a plug, including one or more fluid pathways extending between upstream and downstream sides of the plug, and an internal lock positionable in an unlocked position and a locked position, wherein the internal lock is resiliently biased to the locked position upon release from the unlocked position, wherein the locked position is configured to internally secure the plug within a wellhead component.

Abstract: An electronic control system for a downhole tool controls an operational state of the downhole tool. The electronic control system receives a signal from uphole, and drives a motor to operate a valve, alternately fluidly connecting a chamber in the valve to drilling fluid in a bore of the downhole tool, causing an activation mechanism to configure the downhole tool into a first state, and fluidly connecting the chamber to an annulus surrounding the downhole tool, venting mud into the annulus.

Abstract: A hydraulically balanced multiple drop well completion has a plurality of hydraulic control lines each of which communicates hydraulic inputs and a plurality of hydraulically operated tools numbering greater than or equal to the number of hydraulic control lines. Each of the hydraulic control lines is connected to at least one of the hydraulically operated tools to communicate hydraulic inputs to actuate the hydraulically operated tools. Each of the hydraulically operated tools discharges hydraulic fluid to one of the hydraulic control lines other than the hydraulic control line from which it receives the controlling hydraulic input.

Abstract: A hydraulic connection mechanism for use in a wellbore comprises an upper connection tool, a lower connection tool configured to engage the upper connection tool and form a fluid communication pathway through the hydraulic connection mechanism, and a debris barrier disposed in the fluid communication pathway. The debris barrier comprises a body element, and a spring element configured to maintain the body element in a closed position when the upper connection tool is disengaged from the lower connection tool.

Abstract: A tubular actuating system includes a plurality of series of actuators disposed within a tubular with at least one of the series having a plurality of actuators. Each of the plurality of actuators in the at least one of the series is alterable from a first position allowing passage of plugs below a selected size to a second position allowing actuation by plugs of selected sizes. The plurality of actuators of the series are distributed within the tubular such that the more upstream of any two of the plurality of actuators is actuatingly engagable with a larger one of the plugs than the more downstream of the two of the plurality of actuators when in the second position, and the plurality of series is distributed such that for any two of the series the more upstream of the two series requires a larger plug to alter the actuators therewithin.

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

Abstract: A 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: An sleeve valve for a well assembly includes at least one set of passages extending through a tubular body between the central passage and an exterior of the tubular body and a sleeve slidably located within the central passage of the valve body adapted to selectably sealably cover or uncover the at least one sets of passages. A shifting tool for actuating the sleeve valve is connectable to a tool string and includes a shifting bore with an actuating piston extending from a central bore through the shifting tool and first and second key bores extending radially inwards from the outer surface each having a piston keys located therein. Each of the first and second piston keys is operably connected to the actuating piston so as to be extended from the outer surface when the central bore is supplied with a pressurized fluid.

Abstract: A method for controlling flow of fluid from an annular space in a wellbore includes changing a flow restriction in a fluid flow discharge line from the wellbore annular space. The flow restriction is changed at a rate related to a difference between at least one of a selected fluid flow rate out of the wellbore and an actual fluid flow rate out of the wellbore, and a selected fluid pressure in the annular space and an actual pressure in the annular space.

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: 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. 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. The diverter can 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. The fluid diverter can move in response to density change in the fluid to affect fluid flow patterns in a tubular, the change in flow pattern operating a valve assembly.

Abstract: A well tool actuator can include a series of chambers which, when opened in succession, cause the well tool to be alternately actuated. A method of operating a well tool actuator can include manipulating an object in a wellbore; a sensor of the actuator detecting the object manipulation; and the actuator actuating in response to the sensor detecting the object manipulation. A drilling isolation valve can comprise an actuator including a series of chambers which, when opened in succession, cause the isolation valve to be alternately opened and closed. A method of operating a drilling isolation valve can include manipulating an object in a wellbore, a sensor of the drilling isolation valve detecting the object manipulation, and the drilling isolation valve operating between open and closed configurations in response to the sensor detecting the object manipulation.

Abstract: Sneak path elimination in diode multiplexed control of downhole well tools. A system for selectively actuating multiple well tools includes a control device for each tool, a well tool being operable by selecting a respective control device; conductors connected to the control devices, which are selectable by applying a predetermined voltage across a respective predetermined pair of the conductors; and at least one lockout device for each control device, the lockout devices preventing current from flowing through the respective control devices when voltage across the respective predetermined pair of the conductors is less than a predetermined minimum. A method includes selecting a well tools for actuation by applying a predetermined minimum voltage to a set of conductors; and preventing actuation of another well tool when the predetermined minimum voltage is not applied across another set of conductors, at least one conductor being common to the two sets of conductors.

Abstract: A method for opening a port through the wall of a ported sub including providing a sub with a port through its tubular side wall and providing a hydraulically actuatable valve to cover the port, the valve being actuatable to move away from a position covering the port to thereby open the port. The method further includes increasing pressure within the sub to create a pressure differential across the valve to move the valve toward the low pressure side, while the port remains closed by the valve, thereafter reducing pressure within the sub to reduce the pressure differential and driving the valve to move it away from a position covering the port.

Abstract: A pressure-actuated valve fit to a tubing string for alternately closing to communicate fluids from a wellbore to the tubing string and opening to communicate fluids from a wellbore annulus to the tubing string. The valve is particularly useful for lifting liquids which accumulate in the tubing string when the reservoir has a diminished pressure. In this case, gas is accumulated in the wellbore annulus and when the valve is opened the gas enters the valve and is directed to the tubing string for lifting the liquids. The valve is closed by a spring and has a closing-assist which applies an additional force to the spring to ensure the valve is fully closed.

Abstract: Systems and methods for completing a wellbore. The system may include a first outer tubular member having an inflow control device configured to allow fluid to pass radially through the first outer tubular member. A second outer tubular member may be coupled to the first outer tubular member via an axial coupling. The second outer tubular member may have an inflow control device configured to allow fluid to pass radially through the second outer tubular member. An inner tubular defining an inner bore may be disposed at least partially within the first outer tubular member, the second outer tubular member, or a combination thereof such that an annulus is formed radially therebetween. The inner tubular member may include a flow control device configured to allow fluid to pass radially between the inner bore and the annulus.

Abstract: A valve assembly for regulating fluid flow in a horizontal wellbore. A housing can be coupled to a production tubular. A chamber is defined within the housing and can be in fluid communication through a flow channel with an inner annulus formed adjacent the wellbore. A piston and a biasing member can be disposed within the chamber, where the biasing member biases the piston into a first position. A flowpath is defined within the housing and communicable with both the production tubular and the inner annulus. The flowpath can include one or more nozzles disposed therein, and the piston can be configured to move between the first position allowing fluid flow through the flowpath to the production tubular and a second position preventing fluid flow to the production tubular.

Abstract: Valves comprise a chamber having a piston disposed therein. One side of the piston defines a hydrostatic chamber in fluid communication with an outside environment, such as wellbore annulus, through a port. Operatively associated with the piston on the other side is a sleeve in sliding engagement with an inner mandrel. The inner mandrel comprises a port that is initially blocked by the sleeve. Upon an increase in pressure within the annulus, the piston is moved causing the port in the sleeve to align with the port in the inner mandrel thereby allowing fluid to flow from the annulus into the bore of the inner mandrel. As a result, fluid can be circulated through the valve, or pressure within the annulus can be reduced. A return member is operatively associated with the piston to urge the piston toward the closed position after pressure within the wellbore annulus is reduced.

Abstract: Devices, systems and methods are disclosed for re-directing fluid flow from the interior of tubing placed in a well to the exterior of the tubing by use of selectively actuatable valves operable by engagement of a plug on a plug seat. The devices, systems, and methods disclosed may provide a flowback bypass for the flow of fluids around obstructions in the tubing when those obstructions occur at a predicted location within the tubing. The systems, devices and methods may also include a locking system operable by, among other things, plug and plug seat valves, and such locking system may be used to prevent opening of the flowback bypass until after a predetermined event has occurred.

Abstract: An apparatus for flowing a tool string along a wellbore tubular includes a flow restrictor having a diametrically expanded position and a diametrically retracted position. The flow restrictor sealingly engages the wellbore tubular when in the diametrically expanded position. The apparatus also includes a joint connected to the flow restrictor. The joint actuates the flow restrictor between the expanded position to the retracted position while moving between an open and a closed position.

Abstract: A downhole hydraulic tool employing multiple nozzles in a selectable fashion from an oilfield surface. At least one of the nozzles of the tool is equipped with a burst disk such that fluid pressure directed from the surface may be utilized in activating the nozzle. The pressure may be driven to exceed a predetermined level for sake of the activating by way of sealing off access to other nozzle(s) therebelow, for example, by way of standard ball drop techniques. Thus, nozzle selectivity may be taken advantage of when a first nozzle wears out without requiring time consuming removal of the tool from the well for sake of remedial repairs or replacement.

Abstract: A wellbore servicing system, comprising a sleeve system comprising a ported case, a sliding sleeve within the case and movable between a first sleeve position in which the sleeve restricts fluid communication via the case and a second sleeve position in which the sleeve does not, a radially divided segmented seat movable between a first seat position in which the seat restricts movement of the sleeve and a second seat position in which the seat does not, and a sheath covering a portion of the seat, the sleeve system being transitionable from a first, to a second, to a third mode, in the first mode, the sleeve is in its first position and the seat in its first position, in the second mode, the sleeve is in its first position and the seat in its second position, and, in the third mode, the sleeve is in its second position.

Abstract: A subsea wellhead assembly includes a wellhead body which disposed to support an isolation sleeve for a production tree and to support below the isolation sleeve a production casing hanger for a production casing string. The body also supports a second casing string outside the production casing string whereby to form an annulus between the casing strings. The body includes a passageway which is in communication with the annulus near a lower end of the body and extends upwardly within the wall of the body towards the upper end of the body. A valve is accommodated in the upper part of the body and provides controlled communication between the passageway and a port which can be coupled to the isolation sleeve. The valve is controllable from a production tree in particular is moveable between an open position and a closed position in response to fluid pressure applied to the valve from a production tree by way of the isolation sleeve.

Abstract: A tubing string assembly is disclosed for fluid treatment of a wellbore. The tubing string can be used for staged wellbore fluid treatment where a selected segment of the wellbore is treated, while other segments are sealed off. The tubing string can also be used where a ported tubing string is required to be run in a pressure tight condition and later is needed to be in an open-port condition.

Abstract: An electrical and hydraulic configuration on a subsea tree that facilitates the use of an ROV control system to operate the tree during well installations, interventions, and workovers. An SCM at the tree is in communication with a fixed junction plate that receives a production umbilical during normal operation. The ROV can be deployed to disconnect and park the production umbilical during well installations, interventions, and workovers to prevent accidental operation of the SCM or tree. The junction plate is configured to connect with the ROV and thereby establish communication with the hydraulic lines of the SCM. The ROV may carry an umbilical from a vessel to provide electrical and hydraulic service to the SCM during well operations. In addition, the ROV has facilities to repressurize spent control fluid to thereby allow reuse of the control fluid by the SCM.

Abstract: Systems and methods for performing operations on a well include first and second flow control devices positioned between upper and lower sections of a conduit. An upper connector assembly engaged with the upper section includes connectors adapted for connection to a chemical stimulation device, a blowout preventer, or other well intervention apparatuses. A lower connector assembly engaged with the lower section includes connectors adapted for connection to a chemical stimulation device, a running tool, wellbore conduits, or other well intervention apparatuses. The two connector assemblies, above and below the flow control devices, enable sequential or simultaneous operations to be performed, and can enable operations to be performed independent of the state of the flow control devices.

Abstract: A wellbore servicing system disposed at a wellbore, the wellbore servicing system comprising at least one wellbore servicing equipment component, wherein a flow path extends from the wellbore servicing system component into the wellbore, and a flow-back control system, wherein the flow-back control system is disposed along the flow path, and wherein the flow-back control system is configured to allow fluid communication via the flow path in a first direction at not less than a first rate and to allow fluid communication via the flow path in a second direction at not more than a second rate, wherein the first rate is greater than the second rate.

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

Abstract: A kobe sub includes a kobe installed in a port of the sub, the kobe includes a cap portion accessible in the inner bore, a base mounted in the port and connected to the cap portion, a channel extending through the base and closed by the cap portion; and an inflow controller positioned to control fluid flowing through the channel toward the inner bore when the cap portion is opened; and a port opening tool for opening the cap portion. The kobe may be employed with a frac port.

Abstract: A series of sliding sleeves is actuated by a single ball that lands on a first ball seat and shifts the ball seat. The shifting of the ball seat also allows tubing pressure to communicate to a formerly atmospheric chamber on one side of a piston integrated into the back side of the sliding sleeve. The other side of the piston remains at atmospheric pressure so that the shifting of the ball seat not only releases the ball to go to the next ball seat but also puts a net force on the sliding sleeve to shift it against a travel stop to open a port to allow fracturing, even if there is cement in the annulus around the opened port.

Abstract: A stroker device for use in a borehole in the ground includes an actuator arranged for displacing a tool in a longitudinal direction of the borehole, and grippers arranged to anchor the stroker to the wall of the borehole, alternatively to a pipe wall, wherein the stroker is provided with driving wheels or driving belts for propulsion.

Abstract: A downhole fluid flow control system includes a fluidic module (150) having a bridge network. The bridge network has first and second branch fluid pathways (163, 164) each including at least one fluid flow resistors (174, 180) and a pressure output terminal (178, 184). In operation, the pressure difference between the pressure output terminals (178, 184) of the first and second branch fluid pathways (163, 164) is operable to control fluid flow through the fluidic module (150).

Abstract: A multi-barrier system includes a first valve in fluid communication with a lower completion that is electrically actuatable and inductively coupled to an upper completion. Also included is a second valve in fluid communication with the lower completion, both the first valve and the second valve, positioned proximate an uphole extent of the lower completion, are closable in response to retrieving the upper completion and openable subsequent reengagement of an upper completion.

Abstract: A hydraulic connection mechanism for use in a wellbore comprises an upper connection running tool, a lower connection tool configured to engage the upper connection running tool and form a fluid communication pathway through the hydraulic connection mechanism, and a debris barrier disposed in the fluid communication pathway. The debris barrier comprises a body element, and a spring element configured to maintain the body element in a closed position when the upper connection running tool is disengaged from the lower connection tool.

Abstract: A subsurface safety valve system for a wellbore within a subterranean formation is described. The system can include a power source that generates power, and a delivery system disposed within the wellbore and electrically coupled to the power source. The system can also include at least one safety valve disposed within the wellbore and electrically coupled to the delivery system, where the at least one safety valve remains open while the at least one safety valve receives the power from the delivery system, and where the at least one safety valve closes when the at least one safety valve stops receiving power from the delivery system. The system can further include production tubing mechanically coupled to a distal end of the at least one safety valve, where the at least one safety valve shuts in a cavity within production tubing when the at least one safety valve closes.

Abstract: A wellbore servicing system including a work string and a valve tool defining an flowbore, wherein the valve tool is transitionable from a first mode to a second mode, from the second mode to a third mode, and from the third mode to a fourth mode, wherein the valve tool transitions from the first mode to the second mode upon an application of pressure to the flowbore of at least a threshold pressure, wherein the valve tool transitions from the second mode to the third mode upon a dissipation of pressure from the flowbore to not more than the threshold pressure, wherein, in the first mode, the valve tool allows fluid communication via the flowbore in a first direction and disallows fluid communication in a second direction, and wherein, in the second, and third modes, the valve tool allows fluid communication in both the first and second directions.

Abstract: A tubular seating system includes a seat disposed at a deformable first tubular which is sealable with a plug such that pressure is buildable thereagainst. A second tubular in operable communication with the deformable first tubular defining a support cavity therebetween is configured such that pressure within the support cavity provides support to the seat.

Abstract: An apparatus comprising a tubular body defining a flowbore, a first valve that, when activated, restricts fluid communication via the flowbore in a first direction and allows fluid communication in a second direction, and, when deactivated, allows fluid communication in the first and second directions, a first sleeve slidable from a first to a second position that, when in the first position, the first valve is activated, and, when in the second position, the first valve is deactivated, a second valve, that, when activated, restricts fluid communication in the first direction and allows fluid communication in the second direction, and, when deactivated, allows fluid communication in the first and second directions, and a second sleeve slidable from a first to a second position, that, when in the first position, the second valve is deactivated, and, when in the second position, the second valve is activated.

Abstract: A method of operating an isolation valve can include transmitting a signal to a detector section of the isolation valve, and a control system of the isolation valve operating an actuator of the isolation valve in response to detection of the signal by the detector section. An isolation valve can include a detector section which detects a presence of an object in the isolation valve, and a control system which operates an actuator of the isolation valve in response to an object presence indication received from the detector section. A well system can include an isolation valve which selectively permits and prevents fluid communication between sections of a wellbore, the isolation valve including a detector section which detects a signal, and the isolation valve further including a control system which operates an actuator of the isolation valve in response to detection of the signal by the detector section.

Abstract: A downhole fracturing system including a seat assembly having a plurality of like-sized openings therein. Each of the like-sized openings has a cross sectional area complementary to a corresponding plurality of objects such that each of the objects is matable therewith to substantially inhibit fluid flow through each like-sized opening. The objects have dimensions insufficient to mate with an opening in a next adjacent upstream seat assembly. A method of hydraulic fracturing is also included.

Abstract: In an exemplary embodiment, an apparatus includes a valve assembly, the valve assembly including a tubular member and a valve connected thereto, wherein the valve permits fluid flow through the tubular member in a first direction and prevents fluid flow through the tubular member in a second direction that is opposite the first direction. A plug is adapted to be secured to the valve assembly so that the plug is prevented from moving, relative to the valve assembly, in the first and second directions. In an exemplary embodiment, the apparatus is a cementing plug apparatus, which can plug a tubular string or casing so that fluid flow therethrough is prevented. In an exemplary embodiment, the tubular string or casing may be positioned within a preexisting structure such as, for example, a wellbore.

Abstract: A gas lift valve can include a degradable component; a valve; and a longitudinally extending tubular body that defines a flow path therein that includes the valve disposed between the degradable component and an opening of the tubular body.

Abstract: A ball valve includes a first ball clamping assembly that defines a first seat surface in contact with an exterior of the ball. A second ball clamping assembly defines a second, sealing seat surface in contact with and adapted to seal with the exterior of the ball. The second ball clamping assembly is coupled to the first ball clamping assembly to clamp the ball between the first and second seat surfaces. The second ball clamping assembly includes a seat ring holder and a seat ring carried by the seat ring holder. The seat ring of the second ball clamping assembly has a sealing seat surface. A springing member is provided between the seat ring and the seat ring holder and springingly biases the seat ring toward the ball. The seat ring holder has a shoulder that supports the seat ring against fully compressing the springing member.

Abstract: A tool for selectively treating a wellbore with fluid that includes a tubing string having a sidewall defining an inner bore, the sidewall comprising a flow area having at least one fluid flow port that permits fluid flow through the sidewall. Fluid is prevented from flowing through the flow area when a closure is in a closed position. When in the open position, fluid flows through the flow area. An axial seal is connected to the closure to selectively close the inner bore against fluid pressure to apply the predetermined opening force to move the closure to the open position. A releasable connector connects the axial seal to the closure and a retrieval tool attachment releases the axial seal from the closure upon application of a predetermined release force by a retrieval 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: The present disclosure relates to a sleeve fracturing assembly including a composite sleeve and an opening tool. The composite sleeve and the opening tool can automatically engage with each other via teeth-shaped members arranged thereon so as to open the composite sleeve. The present disclosure further relates to a sleeve fracturing device, which includes a plurality of composite sleeves and opening tools, wherein each composite sleeve and opening tool can achieve unique engagement. The present disclosure still further relates to a method of using the sleeve fracturing device.