Abstract: A float equipment assembly includes an inner string that provides a fluid flow path through the float equipment assembly. The float equipment assembly also includes an opening through which a fluid flowing through the inner string exits the float equipment assembly. The float equipment assembly further includes a moveable member, which when repositioned, isolates the inner string. The float equipment assembly further includes a dissolvable material that initially prevents repositioning of the moveable member, where the moveable member is repositioned after a threshold portion of the dissolvable material has dissolved.

Abstract: The embodiments include methods and tools to activate downhole apparatuses. In one embodiment, a hydrostatic pressure intensifier includes a housing having at least two different internal cross-sectional surface areas. The housing includes a device mounted on the housing and operable to actuate in response to being subject to a threshold amount of pressure. The housing also includes a first piston housed in a first chamber of the housing, where the first piston has a first cross-sectional area and a first stroke length, and a second piston housed in a second chamber of the housing, where the second piston has a second cross-sectional area and a second stroke length, and where the first cross-sectional area is greater than the second cross-sectional area. The hydrostatic pressure intensifier also includes a fluid flow restrictor that restricts fluid flow through the valve to control an amount of pressure applied by the first piston.

Abstract: Provided is a packer plug. The packer plug, in this example, may include an engagement member having a no go feature configured to engage a no go shoulder of an associated packer assembly. The packer plug, in the example, further includes a nose cone having one or more nose cone openings coupled proximate a downhole end of the engagement member, and a check valve coupled proximate the engagement member. The check valve, engagement member, and nose cone, in this example, create a fluid path between a lower end and an upper end of the packer plug. Further to this example, the check valve is configured to allow downhole fluid to pass uphole through the fluid path as the packer plug is being pushed downhole, but substantially prevent uphole fluid from passing downhole through the fluid path as the packer plug is being pulled uphole.

Abstract: The embodiments include methods and tools to activate downhole apparatuses. In one embodiment, a hydrostatic pressure intensifier includes a housing having at least two different internal cross-sectional surface areas. The housing includes a device mounted on the housing and operable to actuate in response to being subject to a threshold amount of pressure. The housing also includes a first piston housed in a first chamber of the housing, where the first piston has a first cross-sectional area and a first stroke length, and a second piston housed in a second chamber of the housing, where the second piston has a second cross-sectional area and a second stroke length, and where the first cross-sectional area is greater than the second cross-sectional area. The hydrostatic pressure intensifier also includes a fluid flow restrictor that restricts fluid flow through the valve to control an amount of pressure applied by the first piston.

Abstract: The embodiments include float equipment assemblies and methods to isolate downhole strings. In one embodiment, a float equipment assembly includes an inner string that provides a fluid flow path through the float equipment assembly. The float equipment assembly also includes an opening through which a fluid flowing through the inner string exits the float equipment assembly. The float equipment assembly further includes a moveable member, which when repositioned, isolates the inner string. The float equipment assembly further includes a dissolvable material that initially prevents repositioning of the moveable member, where the moveable member is repositioned after a threshold portion of the dissolvable material has dissolved.

Abstract: Provided is a packer plug. The packer plug, in this example, may include an engagement member having a no go feature configured to engage a no go shoulder of an associated packer assembly. The packer plug, in the example, further includes a nose cone having one or more nose cone openings coupled proximate a downhole end of the engagement member, and a check valve coupled proximate the engagement member. The check valve, engagement member, and nose cone, in this example, create a fluid path between a lower end and an upper end of the packer plug. Further to this example, the check valve is configured to allow downhole fluid to pass uphole through the fluid path as the packer plug is being pushed downhole, but substantially prevent uphole fluid from passing downhole through the fluid path as the packer plug is being pulled uphole.

Abstract: A setting tool for setting a packer in a wellbore includes a housing defining a hydraulic chamber, a piston disposed in the chamber, a pump coupled to the chamber via a flowline, and a setting sleeve directly or indirectly coupled to the piston. The pump may be used to pump pressurized fluid into the hydraulic chamber for pushing the piston in a direction, and the setting sleeve may be used to apply a compressive force to a packer element of the packer in response to the piston being pushed in that direction. The setting tool may include a sensor used to collect a measurement relating to a force on the workstring, in addition to a controller designed to receive a signal from the sensor and to provide a control signal to the pump based on the sensor signal.

Abstract: Provided is an oil/gas service tool assembly. The oil/gas service tool assembly, in this example, may include a washpipe apparatus, the washpipe apparatus including an uphole washpipe portion, and a downhole washpipe portion having washpipe perforations therein, wherein the uphole washpipe portion and downhole washpipe portion are telescopingly coupled to one another. The oil/gas service tool assembly, in this example, includes a washpipe check valve coupled downhole of the downhole washpipe portion.

Abstract: A system and method for downhole switching of wellbore logging tools is disclosed. The method includes lowering a logging tool in a wellbore tubular, and actuating a mechanical interference device based on interaction with a first mechanical intrusion associated with a screen assembly located downhole in a wellbore. The mechanical interference device is included in an activator module associated with the logging tool. Based on actuating the mechanical interference device, the method includes communicating a first trigger indication to a switching system included with the activator module. In response to the first trigger indication, the method further includes switching the logging tool between an inactive state and an active state. In the active state, an electrical load associated with the logging tool is energized by a power supply.

Abstract: A system and method for downhole switching of wellbore logging tools is disclosed. The method includes lowering a logging tool in a wellbore tubular, and actuating a mechanical interference device based on interaction with a first mechanical intrusion associated with a screen assembly located downhole in a wellbore. The mechanical interference device is included in an activator module associated with the logging tool. Based on actuating the mechanical interference device, the method includes communicating a first trigger indication to a switching system included with the activator module. In response to the first trigger indication, the method further includes switching the logging tool between an inactive state and an active state. In the active state, an electrical load associated with the logging tool is energized by a power supply.

Abstract: In accordance with embodiments of the present disclosure, a setting tool for setting a packer in a wellbore includes a housing defining a hydraulic chamber, a piston disposed in the chamber, a pump coupled to the chamber via a flowline, and a setting sleeve directly or indirectly coupled to the piston. The pump may be used to pump pressurized fluid into the hydraulic chamber for pushing the piston in a direction, and the setting sleeve may be used to apply a compressive force to a packer element of the packer in response to the piston being pushed in that direction. In some embodiments, the setting tool may include a sensor used to collect a measurement relating to a force on the workstring, in addition to a controller designed to receive a signal from the sensor and to provide a control signal to the pump based on the sensor signal.

Abstract: A telescoping joint is provided with one or more control lines and is usable for landing a subsea tubing hanger. The telescoping joint can include an outer mandrel, an inner mandrel, and a control line. The inner mandrel can be releasably coupled to the outer mandrel when run in a wellbore of a subterranean formation. At least part of the inner mandrel can be in an area defined by the outer mandrel and can seal an inner area defined by the inner mandrel from an environment exterior to the outer mandrel. The control line can be exterior to an outer surface of the outer mandrel and coiled around at least part of the inner mandrel.

Abstract: A telescoping joint is provided with one or more control lines and is usable for landing a subsea tubing hanger. The telescoping joint can include an outer mandrel, an inner mandrel, and a control line. The inner mandrel can be releasably coupled to the outer mandrel when run in a wellbore of a subterranean formation. At least part of the inner mandrel can be in an area defined by the outer mandrel and can seal an inner area defined by the inner mandrel from an environment exterior to the outer mandrel. The control line can be exterior to an outer surface of the outer mandrel and coiled around at least part of the inner mandrel.

Abstract: A method of controlling a blowout comprises: releasing at least a first tubing string into a portion of a well system, wherein the step of releasing comprises activating a release table; and causing or allowing a blowout preventer to close. The methods further comprise: compressing at least a portion of a second tubing string and a third tubing string together, wherein the step of compressing comprises activating a crimping device; cutting through the wall of at least a third tubing string, wherein the step of cutting comprises activating a cutting device, and wherein the step of cutting is performed after the step of compressing; and releasing at least the second tubing string and the third tubing string into a portion of a well system, wherein the step of releasing comprises activating a release table.

Abstract: A system for opening a window in a casing string (42) positioned in a wellbore (32). The system includes a hydraulic pressure intensifier (116) having a housing and a piston assembly with a differential piston area. The piston assembly is longitudinally shiftable relative to the housing and is initially secured relative thereto to prevent longitudinal movement therebetween. An anchor assembly (114) is operable to longitudinally secure the hydraulic pressure intensifier (116) within the casing string (42). A window opening tool (118) operably associated with the hydraulic pressure intensifier (116) is operably engagable with the casing string (42) such that when the anchor assembly (114) is longitudinally secured within the casing string (42) and the piston assembly is unsecured relative to the housing under hydrostatic pressure, longitudinal movement of the piston assembly transmits a force to the window opening tool (118), thereby opening the window in the casing string (42).

Abstract: A system for opening a window in a casing string (42) positioned in a wellbore (32). The system includes a hydraulic pressure intensifier (116) having a housing and a piston assembly with a differential piston area. The piston assembly is longitudinally shiftable relative to the housing and is initially secured relative thereto to prevent longitudinal movement therebetween. An anchor assembly (114) is operable to longitudinally secure the hydraulic pressure intensifier (116) within the casing string (42). A window opening tool (118) operably associated with the hydraulic pressure intensifier (116) is operably engagable with the casing string (42) such that when the anchor assembly (114) is longitudinally secured within the casing string (42) and the piston assembly is unsecured relative to the housing under hydrostatic pressure, longitudinal movement of the piston assembly transmits a force to the window opening tool (118), thereby opening the window in the casing string (42).