The disclosed device provides a high-accuracy plunger arrival detection system comprising a low-power magnetometer with high sensitivity and which is capable of sampling low or high intensity magnetic fields. The device processes gathered data from sensors, stores at least some processed data in memory, executes a trending algorithm which compares the magnetic field of the plunger to the ambient magnetic field or a predetermined set of initialization values, and generates an output which is relayed to a well controller. An output signal may be via hard wire, RF, wireless or other known means. In addition, the implementation of two sensing devices mounted in series and in spaced relation to each other, can provide for an actual plunger average velocity. An actual plunger average velocity, as opposed to approximate average velocity, can be used to better optimize well control and improve safety of the overall well production system.

Certain aspects are directed to self-assembling packers that seal an annulus in a downhole wellbore. In one aspect, the packer is formed from a magnetorheological fluid, which may be a carrier fluid formed from a polymer precursor and magnetically responsive particles. The fluid is allowed to be shaped by a magnetic field provided by one or more magnets exerting a radially extending magnetic field from a tubing section used to place the packer.

A method of using a wellbore isolation device comprises: introducing the wellbore isolation device into the wellbore, wherein the isolation device comprises: (A) a matrix, wherein the matrix has a phase transition temperature less than or equal to the bottomhole temperature of the wellbore; and (B) at least one reinforcement area, wherein the reinforcement area: (i) comprises at least a first material, wherein the first material undergoes galvanic corrosion; and (ii) has a greater tensile strength and/or shear strength than the matrix.

A method of using a wellbore isolation device comprises: introducing the wellbore isolation device into the wellbore, wherein the isolation device comprises: (A) a matrix, wherein the matrix has a phase transition temperature less than or equal to the bottomhole temperature of the wellbore; and (B) at least one reinforcement area, wherein the reinforcement area: (i) comprises at least a first material, wherein the first material undergoes galvanic corrosion; and (ii) has a greater tensile strength and/or shear strength than the matrix.

A downhole tool that has a plurality of arm assemblies. Each of the arm assemblies has an arm configured to expand and retract and an actuator. A hydraulic bus in fluid communication with the plurality of arm assemblies. A plurality of flow control devices. The flow control devices are configured to selectively isolate one or more arm assemblies of the plurality of arm assemblies from the hydraulic bus while maintaining the other arm assemblies of the plurality of arm assemblies in communication with the hydraulic bus.

A downhole tool that has a plurality of arm assemblies. Each of the arm assemblies has an arm configured to expand and retract and an actuator. A hydraulic bus in fluid communication with the plurality of arm assemblies. A plurality of flow control devices. The flow control devices are configured to selectively isolate one or more arm assemblies of the plurality of arm assemblies from the hydraulic bus while maintaining the other arm assemblies of the plurality of arm assemblies in communication with the hydraulic bus.

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.

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.

Systems and methods for instructing a device within a wellbore of a subterranean well includes a drill string with an actuator assembly extending into the subterranean. The actuator assembly has a first pipe member with a segment formed of a first material. A second pipe member is coaxially aligned with the first pipe member. A plurality of bearings are positioned between the first pipe member and the second pipe member. Each of the plurality of bearings includes a second material. The first material is reactive to the second material. Certain of the plurality of bearings are changeable bearings that include a dissolvable material. The actuator assembly is operable to instruct an operation of the device by generating an instruction signal by rotating the first pipe member relative to the second pipe member and interpreting a pattern of a reaction of the segment as a bearing rotates past the segment.

A bottom hole assembly has a tubular component with an axis, a first axial end, a second axial end and a poppet valve assembly mounted in the second axial end. An orifice retainer is mounted inside the tubular component adjacent the first axial end. The orifice retainer has a retainer first axial end, a retainer second axial end opposite the retainer first axial end and an orifice pocket adjacent the retainer second axial end. The orifice retainer is installed in and can be removed from the first axial end of the tubular component, opposite the poppet valve assembly. In addition, an orifice is mounted in the orifice pocket of the orifice retainer. The orifice operates in conjunction with the poppet valve assembly.