A system for stimulating a well with an annulus formed by a string and a wellbore. The system includes an injection assembly with at least two zone isolation packers configured to set upstream and downstream of a target zone at pressures above a predetermined activation pressure, and unset at pressures below the activation pressure.

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

A method of setting a tandem releasable bridge plug system in a casing includes assembling a tandem bridge plug string including a lower bridge plug and an upper bridge plug. Both the upper bridge plug and the upper connector are initially disabled by a lock and unlockable from topsides; running in the tandem plug string on a drill pipe string until the lower plug is at its setting target depth in the casing; setting and shutting the lower plug; disconnecting the upper plug from the lower plug; pulling up the upper plug to its upper setting target depth in the casing, enabling the upper plug by releasing the lock; venting annulus gas to a central bore of the upper plug through a radial aperture below a packer of the upper plug and below a ball valve; shutting said ball valve in said central bore the upper plug; and disconnecting the drill pipe string from the upper plug.

To perform an aligned operation downhole, a tubular disposed downhole has an internal bore with a first inner circumference and has a target at a first radial orientation. A locator profile is defined about the internal bore at a first location, and an internal nipple is defined about the internal bore at a second location. The internal nipple has a second inner circumference less than the first of the internal bore. An orientation slot is defined longitudinally across the internal nipple and is disposed at a second radial orientation configured relative to the first radial orientation of the target. A tool is deployable into the internal bore. The tool has a locator to engage in the locator profile and has an orientation key to engage in the slot and align an operational component for the aligned operation with the target.

A valve assembly including a tubular having a first end, a second end, and an intermediate portion extending therebetween. The second end includes one or more openings. A pin member extends radially outwardly of the intermediate portion of the tubular. A valve member is arranged about the tubular. The valve member includes a first end portion, a second end portion and an intermediate section extending therebetween. The second end portion includes a valve element that registers with the one or more openings. An actuator sleeve is mounted to the first end of the valve member and extends about the tubular. The actuator sleeve includes a first end section, a second end section, and an inner surface extending therebetween. The inner surface includes a plurality of J-slots that are selectively receptive of the pin member to establish a position of the valve element relative to the one or more openings.

A wellbore cleaning system provides a relockable shearing swivel tool that can be used in tandem with a lockable weight set circulation tool. Suspended from an upper drill string is an assembly consisting of a landing sub, the lockable weight set circulation tool and relockable shearing swivel tool are located immediately above a liner top and from which is suspended a lower drills string. The lower drill string and production liner are both significantly smaller in diameter than the upper drill string and production casing such than when fluid is pumped at high rates through the entire drill string and reduced cross sectional area of the lower drills string and production liner causes a large pressure drop characterized at surface by a high pump pressure. As part of the method, an operator makes up a drill string assembly that includes an upper drill string, a lower drill string, a landing sub or device, the lockable weight set circulation tool, and the relockable shearing swivel tool. This drill string assembly is lowered into a wellbore until the landing sub is close to a liner top or other shoulder in the wellbore. The drill string is rotated and reciprocated, pumping cleaning chemicals through the entire drill string and through the production liner. The liner top is engaged with the landing sub to open a circulation path from the upper drill string to an upper annulus. The drill string is rotated and reciprocated while pumping cleaning chemicals through the upper annulus to clean the production casing.

An apparatus for performing a milling operation includes a mill having an internal fluid conduit and a fluid port configured to connect the internal fluid conduit to an exterior of the mill. A moveable flow diversion component is configured to move axially in the internal conduit from a first axial position in which fluid is prevented from flowing between the internal fluid conduit and the fluid port, to a second axial position in which the internal fluid conduit is in fluid communication with the fluid port. The apparatus also includes one or more slots configured to engage one or more pins extending into the internal fluid conduit, the one or more slots defining a path that directs movement of the flow diversion component. The flow diversion component is configured to be moved from the first to the second axial position by changing fluid pressure in the internal fluid conduit.

An uphole end for a compression-set straddle packer has a multicomponent mandrel and a multicomponent sliding sleeve that reciprocates within a limited range on the multicomponent mandrel. A bias element constantly resists relative movement between the multicomponent mandrel and the multicomponent sliding sleeve.

An uphole end for a compression-set straddle packer has a multicomponent mandrel and a multicomponent sliding sleeve that reciprocates within a limited range on the multicomponent mandrel. A bias element constantly resists relative movement between the multicomponent mandrel and the multicomponent sliding sleeve.

A downhole, hydraulically actuated drilling stabilizer provides versatility in a bottom-hole assembly. The drilling stabilizer can be used in a directional drilling application to help control the inclination in an extended reach or horizontal well. The drilling stabilizer has stabilizer blade members with an angular design portion that provides versatility in a bottom-hole assembly. The stabilizer can also be used in a conventional rotary bottom-hole assembly or positioned below a steerable motor. A drilling stabilizer with adjustable extension diameters provides improved inclination control over currently existing options.