Abstract: An apparatus for use in a wellbore is disclosed that in one non-limiting embodiment includes a string for deployment into the wellbore, the string including at least one packer and an expansion tool downhole of the packer, wherein the expansion tool further includes: a release device and a lock device inside a movable housing; wherein the lock device prevents shifting of the release device until the lock device is moved to an unlock position by application of a first force to the lock device; and wherein the release device is movable to a release position by application of a second force after the lock device has been moved to the unlock position; and wherein the movable housing is capable of moving over the release device after the release device has been moved to the release position to absorb at least one of contraction and expansion of the expansion tool.

Abstract: In one aspect, an apparatus for use in a wellbore is disclosed that in one non-limiting embodiment contains an outer assembly that includes an isolation packer corresponding to each of a plurality of zones along the wellbore, wherein each isolation packer is configured to be set in the wellbore, a release module associated with each isolation packer to release its associated isolation packer after such isolation packer has been set in the wellbore, and a disconnect module below each isolation packer that is armed using a first force and activated using a second force.

Abstract: An apparatus for use in a wellbore for performing a treatment operation is disclosed that in one non-limiting embodiment may include an inner string that further includes a first tubular having a first communication link, and a service tool including a cross-over tool having a fluid flow passage therein for supplying a treatment fluid under pressure from an inside of the service tool to an outside of the service tool, and wherein the service tool includes a second communication link operatively coupled to the first communication link and wherein the second communication link runs across or through the fluid flow passage in the cross-over tool that is protected from direct flow of the fluid under pressure from the inside of the service tool to the outside of the service tool.

Abstract: A production string for use in a wellbore is disclosed that in a non-limiting embodiment includes an expansion joint having a first tubular that slides along a second tubular, a control line extending from a location above the expansion joint to a location below the expansion joint, wherein a control line placed around the first tubular in a helical fashion that includes a plurality of coils and wherein at least some of the coils in the plurality of coils are connected to each other by a flexible member to limit stretch between the connected coils when the control line is stretched.

Abstract: In one aspect, a method for completing a wellbore in a formation is disclosed, that in one non-limiting embodiment includes placing a casing in the wellbore, cementing an annulus between the casing and the wellbore, and forming an annular cavity of a selected length in the cement between the casing and the wellbore. In one aspect, the forming the annular space includes placing a dissolvable material on an outside of the casing before placing the casing in the wellbore, and dissolving the dissolvable material after cementing to form the annular space.

Abstract: An apparatus for use in a wellbore is disclosed that in one non-limiting embodiment includes a locating device having a locating collet configured to engage with a locating profile on a housing and disengage from the locating profile when a first pull load is applied to the locating collet, a delay device that prevents application of the first pull load on the locating collet when it is engaged with the locating profile until the delay device has been activated, and a locking device configured to prevent activation of the delay device until a second pull load less than the first is applied on the locking device for a selected period of time.

Abstract: An apparatus for use in a wellbore is disclosed that in one non-limiting embodiment includes a set down tool that includes a locating device configured to engage with an outer member at a selected location, a set down device configured to set down in a set down profile in the outer member when the set down device is activated, an alignment device for activating the set down device and a locking device that operates the alignment device to activate the set down device while maintaining the locating device engaged with the outer member.

Abstract: In one aspect, an apparatus for selectively treating a plurality of zones around wellbore is disclosed that in one non-limiting embodiment includes an outer string for placement in the wellbore, the outer string including a packer above a flow port corresponding to each zone, wherein each packer is configured to be set independently and the flow port is configured to supply a treatment fluid to its corresponding zone when such flow port is open, an activation device coupled to each packer, wherein each such activation device is configured to be independently activated to set its corresponding isolation packer, and an inner string for placement in the outer string, the inner string including a frac port for supplying a fluid under pressure to each flow port.

Abstract: In one aspect, a flow control device is disclosed that in one embodiment may include a sand screen that includes adjacent wraps of a longitudinal member, wherein the longitudinal member has a width, a first axial side and a second axial side, the longitudinal member further including spaced apart standoffs along the first axial side and spaced apart channels that provide fluid paths from the second axial side to the first axial side.

Abstract: In one aspect, a system includes a casing disposed in a wellbore in a formation, an installed tubular disposed within the casing and a treatment tubular disposed within the installed tubular, wherein no control line is provided in the treatment tubular, installed tubular or casing. The system also includes a communication line that is placed within the treatment tubular after the treatment tubular is positioned in the wellbore, wherein the communication line has a sensor to be placed proximate an area of interest within the treatment tubular.

Abstract: A lock system works in combination with a mandrel to allow selective operation and disabling of a downhole tool. In the specific situation of a Smart Collet® the tool is locked from being able to find support when engaged to a mating profile as the tool is moved between landing locations. A lower housing features an external dog that in response to rotation takes with it a collet ring with circumferentially oriented fingers. An outer housing cams the collet heads into a respective groove in the mandrel. Reversal of such relative rotation between the upper and lower housings allows the collet heads to spring out of the mandrel groove for the unlocked position. The lock is adapted for use in a variety of tools. The rotation to unlock and then lock is accomplished by dog interaction with shaped internal profiles in a surrounding tubular assembly at strategic locations where needed.

Abstract: A seal assembly including a first tubular having a sealing surface and a seal element run with the first tubular and displaced from the surface. The seal element initially has a radial dimension that forms a radially innermost or outermost sealing dimension of the first tubular for enabling the first tubular to be sealed with a second tubular radially disposed with the first tubular. A mechanism is included that is triggerable for reconfiguring the radial dimension of the seal element. The sealing surface of the first tubular operative forms the radially innermost or outermost sealing dimension of the first tubular when the radial dimension of the seal element has been reconfigured for enabling the sealing surface of the first tubular to receive a second seal element. A method of sealing tubulars is also disclosed.

Abstract: A valve is mounted to a tubular string and has an actuation assembly that is isolated from well fluids. The valve member can be a ball that rotates on a pivot and is actuated by relative rotation of string components that straddle the ball. Rotation of one string component is linked to the closure ball by an external slanted slot with an operating ball that rides in it and connects the rotating string component to the closure ball. Travel stops limit the desired rotation of the closure ball in opposed directions. The closure ball can alternatively be rotated by relative longitudinal string component movement that is converted to relative rotation such as through the use of a j-slot mechanism. Internal seals isolate the slanted slot and operating ball from well fluids.

Abstract: Disclosed herein is a method of installing an elastomeric element onto a tubular. The method includes, positioning the elastomeric element onto a radially expandable member, radially expanding the radially expandable member and the elastomeric element installed thereon, positioning a tubular coaxially with the radially expandable member, and axially urging the elastomeric element off the radially expandable member thereby allowing the elastomeric element to be positioned coaxially about an outer perimetrical surface of the tubular.

Abstract: A completion tubular is placed in position adjacent the zone or zones to be fractured and produced. It features preferably sliding sleeve valves that can assume at least two configurations: wide open and open with a screen material juxtaposed in the flow passage. In a preferred embodiment the valve assembly has three positions, adding a fully closed position to the other two mentioned. After run in, the valves can be put in the wide open position in any order desired to fracture. After fracturing, the valves can be closed or selectively be put in filtration position for production from the fractured zones in any desired order. Various ways are described to actuate the valves. The tubular can have telescoping pistons through which the fracturing can take place if the application calls for a cemented tubular.

Abstract: A wellbore tool which includes a housing having an axial flowbore and a piston sleeve movably disposed within the flowbore. The tool is moveable between first and second operating positions by an actuation mechanism having a piston with a seat having a plurality of separate arcuate segments. The tool can be moved between first and second operating positions with the use of actuating plugs of different sizes that can be landed upon the seat.

Abstract: A system including a plurality of differential pressure actuated tools; a seat receptive to a plug; a first conduit fluidly communicating tubing pressure upstream of the seat to one end of each of the plurality of tools; and a second conduit fluidly communicating tubing pressure downstream of the seat to an opposite end of each of the plurality of tools and method.

Abstract: A positioning tool engages a profile with retaining members such as dogs so that a pulling force can be applied for a predetermined time as a signal that the tool is at the proper location. The time delay is a fluid system that drives fluid through a narrow restriction. The restriction is variable to allow unloading of the resistance from the fluid system while the dogs are still adequately supported. As a result the dogs are released from the profile without regional overstressing. A lock can prevent the tool from resetting to limit its use to locating at a single location. The lock holds the hydraulic system in a defeated position so that even if the dogs engage another profile when locked they will immediately exit that profile.

Abstract: An apparatus to protect the mounting area of casing and a locating profile and optionally a sliding sleeve valve and a flow path from the outside of the valve to the annulus when subsequent attachment of an expanded liner is intended and the expanded liner is to be cemented in place. A barrier sleeve, nose, and outer sleeve define a sealed cavity having a loose incompressible material inside that covers the mounting location on the casing. A locating profile and an optional sliding sleeve valve and a flow path from the outside of the valve to the annulus can be provided. The cementing of the casing takes place through the barrier sleeve. After the cementing, the sleeve and nose are drilled out and the incompressible material is removed to the surface with the drill cuttings. A liner is inserted in the casing and is preferably expanded into sealing contact.

Abstract: A completion tubular is placed in position adjacent the zone or zones to be fractured and produced. It features preferably sliding sleeve valves that can assume at least two configurations: wide open and open with a screen material juxtaposed in the flow passage. In a preferred embodiment the valve assembly has three positions, adding a fully closed position to the other two mentioned. After run in, the valves can be put in the wide open position in any order desired to fracture. After fracturing, the valves can be closed or selectively be put in filtration position for production from the fractured zones in any desired order. Various ways are described to actuate the valves. The tubular can have telescoping pistons through which the fracturing can take place if the application calls for a cemented tubular.