A setting tool for actuating a well tool within a wellbore includes a sleeve telescopically engaging a mandreland a floating piston disposed between the sleeve and the mandrel. The floating piston has a first face subjected to a downhole hydrostatic pressure. The setting tool also includes a pressure chamber formed between the floating piston and the valve, a working fluid in the pressure chamber, and a fluid-tight collapse chamber formed between the valve and a sealed end of the sleeve. The valve selectively the working fluid from the pressure chamber into the collapse chamber if the working fluid reaches a predetermined primary pressure setting of the valve. The setting tool is connected to and actuated a consumer.

A downhole tool for performing a wellbore operation includes a perforating gun, a detector module connected to the perforating gun, wherein the detector module transmits a command in response to a signal, a signal generator configured to transmit the signal to the detector module, and a plug dropping mechanism located adjacent to the detector module, the plug dropping mechanism releasing an object upon receiving the command from the detector module. The perforating gun is fired, and the downhole tool is activated. A plug-mate positioned adjacent to the plug dropping mechanism receives the object. The plug-mate has a profile complementary to the object, and the plug-mate and the object cooperating to block flow along the wellbore. In another mode of operation, an actuation member actuates the plug-mate. It is emphasized that this abstract is provided to comply with the rules requiring an abstract, which will allow a searcher or other reader to quickly ascertain the general subject matter of the technical disclosure.

A method of performing a completion operation at a wellbore includes flowing a plug downhole within fluid through a pipe disposed within the wellbore, landing the plug on a platform carried on the pipe to close the pipe to fluid flow, flowing fluid downhole through the pipe against the plug positioned on the platform, and rupturing a disk of the plug with a pressure of the fluid to open the pipe to fluid flow through a channel of the plug.

A dissolvable untethered object for use inside a well fluid includes an internal cavity and a fluid entry point. The internal cavity contains a gas. The fluid entry point is closed and selectively openable so that the internal cavity can be filled with the well fluid flowing through the fluid entry point. A dissolving rate of the dissolvable untethered object is modified after contact of the well fluid inside the internal cavity with the dissolvable untethered object.

A running tool for deploying a secondary string into a wellbore with a primary tubing string includes a latch for selectively engaging a secondary string latching pin within the tool and means for activating the tool to disengage the latching pin from the tool.

A wellbore completion system includes an expandable liner hanger with a post-setting fluid flow path. The system includes an expandable liner hanger that can be expanded by a running tool prior to a completion operation in a wellbore. The system also includes a circulating sleeve that can be manipulated by the running tool. The circulating sleeve can provide a return path for fluid internal to the expandable liner hanger for the completion operation that is performed subsequent to releasing the running tool from the expandable liner hanger.

A method of lifting liquids from a formation using a plunger lift assembly. The method includes dropping a multi-component plunger lift assembly from a wellhead and into a wellbore. This is done in response to a release signal or in response to a wellhead being shut in. The wellbore has a deviated section which may extend to horizontal. The multi-component plunger lift assembly includes a cylindrical plunger and a sphere. These components are released into the wellbore simultaneously. In response to reservoir formation gases passing into the wellbore, the method also includes allowing the plunger lift assembly to move up the wellbore and to the wellhead, thereby pushing liquids upwardly towards the wellhead.

Embodiments described herein provide systems and methods for minimizing deceleration of downhole tools when the downhole tools are pumped down into wellbores through drill pipe in an untethered manner. For example, embodiments described herein include a hydraulic downhole tool deceleration system that includes a hydraulic decelerator configured to be affixed to a downhole tool string pumped down through drill pipe during operation. The hydraulic decelerator is configured to contact a hard shoulder while traveling through the drill pipe, and to limit an initial magnitude of deceleration of the downhole tool string caused at the initial moment of contact of the hydraulic decelerator against the hard shoulder.

An apparatus for cleaning the area around a casing of a wellbore is described. The apparatus comprises a body configured to be located in a wellbore casing, the body defining an internal chamber for receipt of pressurised fluid. Pistons are mounted in the body and is arranged to move from an inwardly retracted condition to an outwardly deployed condition as a result of an increase in fluid pressure in the internal chamber. Pistons further comprise at least one first nozzle arranged to direct a jet of pressurised fluid from the apparatus.

A hydraulic fracking plug assembly comprises a mandrel, sealing element, upper and lower backup rings, upper and lower cones, upper and lower slips each having teeth configured to engage a well casing, and a shoe. At least one of these parts, and in a further example most or all of these parts, are soluble in a solvent such as a potassium chloride solution, an acid, or a base. In some such examples, the soluble parts comprise magnesium, a magnesium alloy, or a soluble polymer.