Abstract: An autonomous inflow control device, including a first flow modifier and a second flow modifier disposed in series with one another, a third flow modifier and a fourth flow modifier disposed in series with one another, a first sensor, a second sensor, a valve responsive to a difference between a signal from the first sensor and a signal from the second sensor. A method for including flowing a fluid to a device, splitting the flow into a first flow path of the device and a second flow path of the device, generating a signal in a first sensor in the first flow path, generating a signal in a second sensor in the second flow path, and opening or closing a valve responsive to a differential in the signal from the first sensor and the signal from the second sensor. A borehole system including the autonomous inflow control device.

Abstract: An autonomous inflow control system includes an inlet conduit connecting production fluid to an input of a first flow modifier including one of a laminar flow device and a turbulent flow device. An intermediate conduit is connected to a first fluid output of the first flow modifier, and connects the first flow modifier to a second flow modifier configured to provide a second fluid output, the second flow modifier including another of the laminar flow device and the turbulent flow device. The system includes a signal path configured to provide a first signal and a second signal, and a valve responsive to a difference between the first signal and the second signal. The first signal corresponds to the first fluid output and the second signal corresponds to the second fluid output, or the first signal corresponds to the input and the second signal corresponds to the first fluid output.

Abstract: An energy extraction arrangement, includes a surface defining a flow pathway, and a flap hingedly secured to the surface, the flap exposed to a fluid flow, during use. A borehole energy extraction system, including a non-diverted primary flow pathway for borehole fluids, a surface defining the flow pathway, and a flap hingedly secured to the surface, the flap exposed to a fluid flow, during use. A method for extracting energy from a non-diverted primary fluid flow, the method including deflecting solely by the primary fluid flow a flap hingedly connected to a surface defining in part a flow pathway for the primary fluid flow, and generating an electrical potential by the deflecting. A borehole system, including a borehole in a subsurface formation, a string in the borehole, and an energy extraction arrangement disposed within or as a part of the string.

Abstract: An energy harvester, including a cyclical impulse device, and a piezoelectric generator deformably connected to the device. A method for harvesting energy from a flowing fluid including inducing a selected flow regime, causing a cyclical impulse device to cycle based upon the flow regime, and physically deforming a piezoelectric generator with the device. A wellbore system, including a borehole in a subsurface formation, a string in the borehole, and an energy harvester disposed within or as a part of the string.

Abstract: A packer setting tool for setting a packer device within a wellbore. The packer setting tool includes an outer housing defining a piston chamber within. A piston member is disposed within the piston chamber and is moveable therein in response to ignition of a non-hydrocarbon liquid fuel source.

Abstract: A plug releaser includes, a first tubular with at least one first port through a wall thereof, at least two plugs sealingly engaged with the first tubular defining a first chamber between the first tubular and the at least two plugs. The at least two plugs are rupturable or releasable from the first tubular at selected pressure differentials thereacross, and a second tubular is in operable communication with the first tubular at locations beyond the at least two plugs. The at least one first port provides fluidic communication between the first chamber and an outside of both the first tubular and the second tubular and the at least one first port is sized to prevent pressure differential across the at least two plugs from building to a selected pressure differential needed to rupture or release the plugs in either direction for at least a period of time.

Abstract: A liner hanger features a pressure balanced setting sleeve system that applies no net force to the slips when internal pressure is raised in access ports associated with opposed actuation sleeves such that applied pressure results in opposed forces that cancel each other out. When one of the sleeves is isolated from tubing pressure and the other port to the other sleeve is pressurized, the bi-directional slips are extended and their extended position is locked with a lock ring to hold the set of the liner hanger against release.

Abstract: A packer setting tool for setting a packer device within a wellbore. The packer setting tool includes an outer housing defining a piston chamber within. A piston member is disposed within the piston chamber and is moveable therein in response to ignition of a non-hydrocarbon liquid fuel source.

Abstract: A packer setting tool for setting a packer device within a wellbore. The packer setting tool includes an outer housing defining a piston chamber within. A piston member is disposed within the piston chamber and is moveable therein in response to ignition of a liquid hydrocarbon fuel source.

Abstract: A liner hanger and packer are set at different times in a single trip without intervention. The running tool has a ball seat that accepts a ball for pressuring up which results in movement of a mandrel with a magnet mounted to it past a valve triggered by the magnetic field. Potential energy is released to set the liner hanger. Further mandrel movement then releases the running tool once the liner is supported by the hanger. After a cement job that starts with confirmation of release of the running tool, the same magnet is moved past another valve adjacent the liner top packer. Another valve is triggered open to release potential energy and move parts that set the packer. The running tool is removed from the liner and brought to the surface.

Abstract: 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.

Abstract: A subterranean tool can drop multiple objects to landing locations in a tubular string. The tool can keep at least one ball out of the fluid stream until ready for release. A dart or wiper plug can be kept in the fluid stream with an open bypass until axial mandrel movement allows release of the plug or dart. The tool is rotationally locked at a lower location for run in and then can rotationally lock at an upper location upon release of the dart or ball shifting relative rotation capabilities to different members. Axial movement that releases the dart also aligns a ball with a decreasing depth groove so that relative part rotation can cam the ball against a leaf spring detent and into the mandrel flow path.

Abstract: A top down cementing tool operates with either mechanical manipulation or hydraulically. Rotation of the liner during cementing is enabled. A first bore is open for circulation during running in of the liner. In the hydraulic version, pressuring up on a dropped ball in the first bore opens cement packer setting ports and aligns crossover ports from the first bore to the annulus below the cementing packer and displaced fluid return ports to the annulus above the cementing packer. Pressuring up on a trailing wiper plug in the first bore opens the second bore so that pressuring on a seated ball in the second bore opens access to unsetting the cementing packer and launching the ball in the second bore for liner hanger setting and release of the running tool. The alternative embodiment gets the same result but with string manipulation for some of the realignments.

Abstract: A plug releaser includes, a first tubular with at least one first port through a wall thereof, at least two plugs sealingly engaged with the first tubular defining a first chamber between the first tubular and the at least two plugs. The at least two plugs are rupturable or releasable from the first tubular at selected pressure differentials thereacross, and a second tubular is in operable communication with the first tubular at locations beyond the at least two plugs. The at least one first port provides fluidic communication between the first chamber and an outside of both the first tubular and the second tubular and the at least one first port is sized to prevent pressure differential across the at least two plugs from building to a selected pressure differential needed to rupture or release the plugs in either direction for at least a period of time.

Abstract: A liner hanger and packer are set at different times in a single trip without intervention. The running tool has a ball seat that accepts a ball for pressuring; up which results in movement of a mandrel with a magnet mounted to it past a valve triggered by the magnetic field. Potential energy is released to set the liner hanger. Further mandrel movement then releases the running tool once the liner is supported by the hanger. After a cement job that starts with confirmation of release of the running tool, the same magnet is moved past another valve adjacent the liner top packer. Another valve is triggered open to release potential energy and move parts that set the packer. The running tool is removed from the liner and brought to the surface.

Abstract: A tubular occlusion and pressure damping system includes, a tubular, an occlusion configured to block flow through the tubular, the occlusion having, a first chamber in pressure communication with an inside of the tubular, a second chamber in fluidic communication with the first chamber, and a flow restrictor in operable communication with the first chamber and the second chamber. The flow restrictor configured to throttle flow between the first chamber and the second chamber such that pressure increases within the second chamber lag behind pressure increases in the inside of the tubular at least until the second chamber has reached a selected volume after which pressure within the second chamber increases toward the pressure in the inside of the tubular.

Abstract: A subterranean tool can drop multiple objects to landing locations in a tubular string. The tool can keep at least one ball out of the fluid stream until ready for release. A dart or wiper plug can be kept in the fluid stream with an open bypass until axial mandrel movement allows release of the plug or dart. The tool is rotationally locked at a lower location for run in and then can rotationally lock at an upper location upon release of the dart or ball. Axial movement that releases the dart can continue until the ball aligns with a decreasing depth groove so that relative part rotation cams the ball against a leaf spring detent and into the mandrel flow path.

Abstract: A tubular occlusion and pressure damping system includes, a tubular, an occlusion configured to block flow through the tubular, the occlusion having, a first chamber in pressure communication with an inside of the tubular, a second chamber in fluidic communication with the first chamber, and a flow restrictor in operable communication with the first chamber and the second chamber. The flow restrictor configured to throttle flow between the first chamber and the second chamber such that pressure increases within the second chamber lag behind pressure increases in the inside of the tubular at least until the second chamber has reached a selected volume after which pressure within the second chamber increases toward the pressure in the inside of the tubular.

Abstract: A setting tool for actuating a well tool within a wellbore includes a mandrel, a sleeve telescopically engaging the mandrel, 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 is configured to flow 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 a consumer and is actuated to set the consumer. 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.

Abstract: A liner hanger features a pressure balanced setting sleeve system that applies no net force to the slips when internal pressure is raised in access ports associated with opposed actuation sleeves such that applied pressure results in opposed forces that cancel each other out. When one of the sleeves is isolated from tubing pressure and the other port to the other sleeve is pressurized, the bi-directional slips are extended and their extended position is locked with a lock ring to hold the set of the liner hanger against release.