Injection of CO.sub.2 may be controlled and optimized, and CO.sub.2 plume leaks monitored in real time, using a controlled sleeve system deployed into a well, where the controlled sleeve system comprises a predetermined set of ports extending from an outer surface of a substantially tubular housing through to an inner annulus of the housing and one or more selectively actuated sliding sleeves configured to selectively open, occlude, and close the predetermined set of ports. One or more sensors configured to be deployed in the well may be present. A wireless remotely actuated flow controller disposed at least partially within the housing and operatively in communication with the sensor comprises a sleeve actuator controller operatively connected to the selectively actuated sliding sleeve and a sensor data acquisition module operatively in communication with the sensor. A communications module is operatively in communication with the wireless remote actuated flow controller. Power may be supplied via a power supply operatively in communication with the wireless remote actuated flow controller, the communications module, and the sensor. The controlled sleeve system is placed into communication with a surface control system disposed proximate a surface location of the well and CO.sub.2 injected into a geological formation of the well, at least partially through the controlled sleeve system. The surface system is used to selectively actuate the selectively actuated sleeve to selectively choke, occlude, and permit the flow of CO.sub.2.

A circulating sub having an elongate outer member and an elongate inner member positioned within the outer member. Locking members releasably maintain the inner and outer members in a longitudinally fixed relationship. The sub may be activated by a single ball. The ball engages with the locking members and unlocks the inner member from the outer member. The increase of fluid pressure within the sub causes the inner member to move downward within the outer member. Downward movement of the inner member opens exit ports on the outer member to allow fluid to flow into a wellbore surrounding the sub. The decrease of fluid pressure within the sub causes the inner member to move upward within the outer member. Upward movement of the inner member seals the exit ports and deactivates the sub. Once the sub is deactivated, the ball may be expelled from the sub.

A valve assembly for integration within a wellbore string disposed within a hydrocarbon-containing reservoir is provided. The valve assembly includes a valve housing having a plurality of frac ports for establishing fluid communication between a central passage and the reservoir. The valve assembly includes a bottom sleeve operatively mounted within the valve housing configured to selectively open the frac ports, and a top sleeve operatively mounted within the valve housing slidable between (i) a first position defining a first fluid pathway whereby fluid is flowable down into the central passage and into the reservoir via the frac ports, and (ii) a tracing position defining a second fluid pathway whereby fluid is flowable from the reservoir into an annulus defined between the top sleeve and the housing. The valve assembly also has a tracer compartment defined within the annulus forming part of the second fluid pathway and accommodating a tracer material.

Disclosed is a gravel pack service tool that utilizes an internal closure device to set a packer. One disclosed system includes a completion string including at least one packer, a service tool configured to be arranged within the completion string and having an interior that provides a flow path for fluids and a crossover tool, and a closure device arranged within the flow path and being actuatable between an open position and a closed position in response to a signature pressure pulse detected by the closure device, wherein, when the closure device is in the open position, the fluids are able to bypass the closure device and flow to lower portions of the service tool, and wherein, when the closure device is in the closed position, the fluids are prevented from bypassing the closure device and a pressure within the service tool is increased to set the at least one packer.

A downhole well tool assembly can include a perforator and a selectively openable and closable perforation plug discharge port. A method of perforating and treating multiple formation zones of a well in a single trip of a downhole well tool assembly into the well can include positioning the downhole well tool assembly at a zone, closing a perforation plug discharge port of the downhole well tool assembly, perforating the zone, treating the zone, opening the perforation plug discharge port, deploying perforation plugs into the well via the perforation plug discharge port, plugging perforations in the zone with the perforation plugs, positioning the downhole well tool assembly at a subsequent zone, closing the perforation plug discharge port, perforating the subsequent zone, and treating the subsequent zone.

An indexing valve system includes a first tubular having an outer surface portion, an inner surface portion defining a passage portion, and a plurality of indexing components. A second tubular is axially aligned with the first tubular. The second tubular includes an outer surface section, an inner surface section defining a passage section, and a plurality of indexing members that selectively inter-engage with the plurality of indexing components. The inner surface section including a plurality of indexing elements. An insert extends into, and is axially shiftable relative to, the passage portion and the passage section. The insert includes an outer surface supporting an indexer that selectively engages with the plurality of indexing elements to rotate the second tubular relative to the first tubular.

The present description relates to processes and systems for asynchronous frac-to-frac operations for recovering hydro-carbons. The processes can include the use of injection-only and production-only valves that include a housing and at least one sleeve as well as flow restriction components, check valves, or other features. The flow restriction component can be a tortuous path provided in the sleeve. The check valves can be integrated into the sleeve or into the housing of the valve. Various different types of valve assemblies can be used and integrated with flow restriction components and/or check valves.

A mechanically actuated tubing drain for service with oil wells, water wells, gas wells and/or thermal wells has a configuration in which the drain opens by operation of a bumper member which may be pulled upwardly to move a sleeve member which is initially positioned adjacent to a drain port, thereby sealing the drain port. Once the bumper member pushes the sleeve member upwardly, any fluid in the tubing above the drain port will drain from the tubing. The bumper member may be pulled upwardly either by upward movement of a rod string or by operation of a wireline or slickline tool. The mechanically actuated drain does not require a tubing anchor to operate.

A downhole tool comprises a mechanical energy storage component that retains energy supplied by a first pressure increase and transfers such energy to actuate another component of the tool. In one aspect, the tool is a toe valve that is activated for opening ports thereon upon application of a first pressure and actuated to open the ports upon application of a second pressure lower than the first pressure.

A system includes an outer completion string, an inner service string configured to connect within the outer completion string, and an upper completion. The outer completion string includes at least one isolation packer, a sand control assembly and a gravel pack extension disposed uphole of a washdown shoe in a bottom-most well zone. In a top well zone, the outer completion string includes a latch profile, a female inductive coupler, a gravel pack packer, and a sand control assembly and a gravel pack extension disposed downhole of the gravel pack packer. The inner service string includes, among other components, an inner concentric string that is concentrically arranged within a workstring creating an inner-annulus between the workstring and the inner concentric string. The upper completion includes a male inductive coupler that is configured to connect with the female inductive coupler of the outer completion string.