Methods and systems are provided for dislodging a ferromagnetic disk removably installed in a wellbore. The disk can be installed in the wellbore during oil and gas well completion and production activities to maintain pressure within the wellbore. More specifically, the disclosure relates to using a strong magnet installed within a magnetic tool to dislodge and remove a ferromagnetic disk without breaking the disk. The strong magnet can be a neodymium magnet, electromagnet, or other types of strong magnets.

Bottom hole assemblies for drilling through a lost circulation zone of a wellbore includes a drill string, a drill bit and a cladding seat coupled to the drill string, an expandable cladding sheath engaged with the cladding seat, a release mechanism coupling an uphole end of the expandable cladding sheath to the drill string, and an expander translatable axially along the drill string. The expandable cladding sheath is a fiber reinforced polymer. The cladding seat releasably couples a downhole end of the expandable cladding sheath to the drill string, and the release mechanism operates to release the uphole end of the expandable cladding sheath from the drill string. The expander deforms the expandable cladding sheath outward into contact with a wall of a wellbore when translated axially through a central cavity of the expandable cladding sheath. The bottom hole assembly may enable drilling ahead through a lost circulation zone.

Bottom hole assemblies for drilling through a lost circulation zone of a wellbore includes a drill string, a drill bit and a cladding seat coupled to the drill string, an expandable cladding sheath engaged with the cladding seat, a release mechanism coupling an uphole end of the expandable cladding sheath to the drill string, and an expander translatable axially along the drill string. The expandable cladding sheath is a fiber reinforced polymer. The cladding seat releasably couples a downhole end of the expandable cladding sheath to the drill string, and the release mechanism operates to release the uphole end of the expandable cladding sheath from the drill string. The expander deforms the expandable cladding sheath outward into contact with a wall of a wellbore when translated axially through a central cavity of the expandable cladding sheath. The bottom hole assembly may enable drilling ahead through a lost circulation zone.

A stop collar includes an annular body and a gripping member. The body includes an outer surface and an inner surface. The body defines a window extending from the outer surface to the inner surface. A portion of the inner surface has a diameter that decreases proceeding toward an axial end of the body. The gripping member is positioned at least partially within the body and in contact with the inner surface. The gripping member is at least partially aligned with the window when the stop collar is in a first state. The gripping member moves toward the axial end of the body when the stop collar actuates into a second state. A diameter of the gripping member decreases as the gripping member moves toward the axial end of the body.

For a side pocket mandrel that has a primary flow bore and an offset side pocket, a method for installing a guide sleeve begins with the step of compressing the guide sleeve to reduce an outer diameter of the guide sleeve. The method continues with the step of inserting the guide sleeve into a section of the primary flow bore that has a first inner diameter (D1). The method continues with the steps of allowing the guide sleeve to radially expand such that the outer diameter of the guide sleeve matches the first diameter, pushing the guide sleeve further into the primary flow bore to a guide sleeve section that has a second inner diameter (D2) that is larger than the first inner diameter (D1), and allowing the guide sleeve to radially expand to capture the guide sleeve within the guide sleeve section of the primary flow bore.

For a side pocket mandrel that has a primary flow bore and an offset side pocket, a method for installing a guide sleeve begins with the step of compressing the guide sleeve to reduce an outer diameter of the guide sleeve. The method continues with the step of inserting the guide sleeve into a section of the primary flow bore that has a first inner diameter (D1). The method continues with the steps of allowing the guide sleeve to radially expand such that the outer diameter of the guide sleeve matches the first diameter, pushing the guide sleeve further into the primary flow bore to a guide sleeve section that has a second inner diameter (D2) that is larger than the first inner diameter (D1), and allowing the guide sleeve to radially expand to capture the guide sleeve within the guide sleeve section of the primary flow bore.

Provided is a gauge sensor, a sensing system, and a well system. The gauge sensor, in one aspect, includes a tubing encapsulated conductor (TEC) termination region, the TEC region including a TEC termination, and a seal region coupled to the TEC region, the seal region including a gauge sensor angled surface configured to couple with a gauge mandrel angled surface of a gauge cavity that the gauge sensor is configured to insert within. The gauge sensor, in this one aspect, further includes a sensor region coupled to the seal region, the sensor region including one or more temperature sensors, and a pressure nipple region coupled to the sensor region, the pressure nipple region including a pressure nipple having a length (L.sub.p).

Provided is a gauge sensor, a sensing system, and a well system. The gauge sensor, in one aspect, includes a tubing encapsulated conductor (TEC) termination region, the TEC region including a TEC termination, and a seal region coupled to the TEC region, the seal region including a gauge sensor angled surface configured to couple with a gauge mandrel angled surface of a gauge cavity that the gauge sensor is configured to insert within. The gauge sensor, in this one aspect, further includes a sensor region coupled to the seal region, the sensor region including one or more temperature sensors, and a pressure nipple region coupled to the sensor region, the pressure nipple region including a pressure nipple having a length (L.sub.p).

Provided is a gauge mandrel, a sensing system, and a well system. The gauge mandrel, in one aspect, includes a tubular having a length (L.sub.t), an internal diameter (D.sub.i) and a width (W), the internal diameter (D.sub.i) and the width (W) defining a sidewall thickness (t), the tubular defining a primary fluid passageway. The gauge mandrel, in accordance with this aspect, further includes a gauge cavity extending along at least a portion of the length (L.sub.t) of the tubular and located entirely within the sidewall thickness (t), the gauge cavity having an insertion end configured to accept a gauge sensor.

A side pocket mandrel is configured for use within a gas lift system deployed in a well that has an annular space surrounding the gas lift system. The side pocket mandrel includes a central body that includes a central bore, a gas lift valve pocket, and a gas lift valve installed within the gas lift valve pocket. The side pocket mandrel may also include a motorized choke valve assembly to selectively cover some or all of an internal tubing port extending between the central bore and the gas lift valve pocket. The side pocket mandrel may also include an automatic closing valve assembly configured to automatically close the gas lift valve port when the gas lift valve is removed from the side pocket mandrel.