A pump down intervention tool may be pumped downhole through a work string after an installation of the work string. The pump down intervention tool may include a downhole tool that includes but is not limited to an agitator tool, including but not limited to a fluidic pulsation device, or a check valve. The pump down intervention tool may be pumped downhole in the work string, for example but not limited to in a coiled tubing or jointed pipes. The pump down intervention tool may be landed at a desired location along a length of the work string. The pump down intervention tool can allow for the addition of a downhole tool after the work string's initial deployment, providing a desired functionality downhole at time after the initial deployment of the work string downhole.

A pump down intervention tool may be pumped downhole through a work string after an installation of the work string. The pump down intervention tool may include a downhole tool that includes but is not limited to an agitator tool, including but not limited to a fluidic pulsation device, or a check valve. The pump down intervention tool may be pumped downhole in the work string, for example but not limited to in a coiled tubing or jointed pipes. The pump down intervention tool may be landed at a desired location along a length of the work string. The pump down intervention tool can allow for the addition of a downhole tool after the work string's initial deployment, providing a desired functionality downhole at time after the initial deployment of the work string downhole.

A rotating control device includes a bowl housing with an inner aperture to receive a seal and bearing assembly. A plurality of hydraulically-actuated fail-last-position latching assemblies are disposed about an outer surface of the bowl housing to controllably extend a plurality of piston-driven dogs radially into a groove of the seal and bearing assembly. The seal and bearing assembly includes a housing, a mandrel disposed within an inner aperture of the housing, a first interference-fit sealing element attached to a bottom distal end of the mandrel, a plurality of tapered-thrust bearings indirectly mounted to the housing, a preload spacer disposed between top and bottom tapered-thrust bearings, a plurality of jam nuts to adjust a preload of the tapered-thrust bearings, and a lower seal carrier attached to the seal and bearing housing comprising a plurality of dynamic sealing elements that contact the mandrel.

A rotating control device includes a bowl housing with an inner aperture to receive a seal and bearing assembly. A plurality of hydraulically-actuated fail-last-position latching assemblies are disposed about an outer surface of the bowl housing to controllably extend a plurality of piston-driven dogs radially into a groove of the seal and bearing assembly. The seal and bearing assembly includes a housing, a mandrel disposed within an inner aperture of the housing, a first interference-fit sealing element attached to a bottom distal end of the mandrel, a plurality of tapered-thrust bearings indirectly mounted to the housing, a preload spacer disposed between top and bottom tapered-thrust bearings, a plurality of jam nuts to adjust a preload of the tapered-thrust bearings, and a lower seal carrier attached to the seal and bearing housing comprising a plurality of dynamic sealing elements that contact the mandrel.

A plugging tool includes an elongated inner housing allowing a first fluid to flow through a hollow interior of the inner housing, a retractable plunger positioned within the inner housing and operable to obstruct the flow of the first fluid into a discharge chamber and resume the flow of the first fluid into the discharge chamber based on a pressure exerted by the first fluid on the retractable plunger, and at least one pressure release valve (PRV) operable to open and release at least a portion of the first fluid from the inner housing based on a pressure exerted by the first fluid on the at least one PRV, wherein operation of the retractable plunger and the at least one PRV generates pulses of the first fluid used to deposit a sealing plug at a target interval of a wellbore.

A plugging tool includes an elongated inner housing allowing a first fluid to flow through a hollow interior of the inner housing, a retractable plunger positioned within the inner housing and operable to obstruct the flow of the first fluid into a discharge chamber and resume the flow of the first fluid into the discharge chamber based on a pressure exerted by the first fluid on the retractable plunger, and at least one pressure release valve (PRV) operable to open and release at least a portion of the first fluid from the inner housing based on a pressure exerted by the first fluid on the at least one PRV, wherein operation of the retractable plunger and the at least one PRV generates pulses of the first fluid used to deposit a sealing plug at a target interval of a wellbore.

A head for a well tubular. The well tubular head includes features that may be applied to a casing head or a tubing head. The well tubular head includes a bowl tubular reversibly connected with a casing connector. The bowl tubular is adapted for connecting with an uphole component of an equipment stack or other system. The bowl tubular includes a hanger profile for receiving a casing hanger or tubing hanger. The casing connector is adapted for connecting with the casing. The bowl tubular and the casing connector may be replaced independently of each oth-er. Removable connection points for flow lines may be includ-ed on the well tubular head to facilitate changing flow lines or flow line connection points. The bowl tubular may include a dri-ve system for rotating tubing.

A head for a well tubular. The well tubular head includes features that may be applied to a casing head or a tubing head. The well tubular head includes a bowl tubular reversibly connected with a casing connector. The bowl tubular is adapted for connecting with an uphole component of an equipment stack or other system. The bowl tubular includes a hanger profile for receiving a casing hanger or tubing hanger. The casing connector is adapted for connecting with the casing. The bowl tubular and the casing connector may be replaced independently of each oth-er. Removable connection points for flow lines may be includ-ed on the well tubular head to facilitate changing flow lines or flow line connection points. The bowl tubular may include a dri-ve system for rotating tubing.

A frac system including a frac tree. The frac tree includes a frac head. The frac head defines a first inlet, a second inlet, and an outlet. The frac head receives frac fluid through the first inlet and directs the frac fluid to the outlet fluidly coupled to a wellhead. A valve couples to the second inlet of the frac head. A flapper valve is within the frac head. The flapper valve moves between an open position and a closed position to control fluid flow to the valve through the second inlet. The flapper valve aligns with a first axis of the outlet and the second inlet in the closed position and aligns with a second axis of the first inlet in the open position.

A frac system including a frac tree. The frac tree includes a frac head. The frac head defines a first inlet, a second inlet, and an outlet. The frac head receives frac fluid through the first inlet and directs the frac fluid to the outlet fluidly coupled to a wellhead. A valve couples to the second inlet of the frac head. A flapper valve is within the frac head. The flapper valve moves between an open position and a closed position to control fluid flow to the valve through the second inlet. The flapper valve aligns with a first axis of the outlet and the second inlet in the closed position and aligns with a second axis of the first inlet in the open position.