A casing head support system (CHSS) for a casing head includes a casing head support unit (CHSU) having a tubular body with a support unit top end (SUTE) and a support unit bottom end (SUBE); a first conductor string extension joint coaxially fastened to the SUBE; and an internal load profile machined into an inner circumferential surface of the CHSU. The SUTE forms a coaxial connection with the casing head. The internal load profile supports a corresponding load shoulder on a conductor hanger. The CHSU contains a CHSU top preparation machined into the inner circumferential surface of the support unit. The CHSU top preparation is located at the SUTE. The CHSU top preparation mates with a corresponding casing head support unit running tool (CHRT) bottom preparation.

A casing head support system (CHSS) for a casing head includes a casing head support unit (CHSU) having a tubular body with a support unit top end (SUTE) and a support unit bottom end (SUBE); a first conductor string extension joint coaxially fastened to the SUBE; and an internal load profile machined into an inner circumferential surface of the CHSU. The SUTE forms a coaxial connection with the casing head. The internal load profile supports a corresponding load shoulder on a conductor hanger. The CHSU contains a CHSU top preparation machined into the inner circumferential surface of the support unit. The CHSU top preparation is located at the SUTE. The CHSU top preparation mates with a corresponding casing head support unit running tool (CHRT) bottom preparation.

A system includes a hanger running tool that has a first lock ring configured to secure the hanger running tool to a hanger when a first axial force is applied to the hanger running tool and a tool body configured to direct a push ring of the hanger in an axial direction when a second axial force is applied to the hanger running tool, where the push ring is configured to direct a second lock ring of the hanger radially outward toward a tubular, and where the hanger running tool is configured to secure the hanger to the tubular without rotating the hanger running tool.

A system includes a hanger running tool that has a first lock ring configured to secure the hanger running tool to a hanger when a first axial force is applied to the hanger running tool and a tool body configured to direct a push ring of the hanger in an axial direction when a second axial force is applied to the hanger running tool, where the push ring is configured to direct a second lock ring of the hanger radially outward toward a tubular, and where the hanger running tool is configured to secure the hanger to the tubular without rotating the hanger running tool.

An annular seal system for sealing between a casing hanger and a wellhead housing, the system including an actuator ring having a rigid portion and a flexible portion, and a lockdown ring positioned adjacent the actuator ring. The annular seal system further includes a seal assembly capable of moving from a de-energized position to an energized position, wherein when the seal assembly is in the de-energized position there is defined a space between the seal assembly and the rigid portion of the actuator ring, and when the seal assembly is in the energized position the space is closed, the rigid portion of the actuator ring contacts a surface of the casing hanger, and the flexible portion of the actuator ring pushes the lockdown ring into engagement with the wellhead, the flexible portion of the actuator ring adapted to axially compress to allow positional variation between the lockdown ring and the wellhead housing.

An annular seal system for sealing between a casing hanger and a wellhead housing, the system including an actuator ring having a rigid portion and a flexible portion, and a lockdown ring positioned adjacent the actuator ring. The annular seal system further includes a seal assembly capable of moving from a de-energized position to an energized position, wherein when the seal assembly is in the de-energized position there is defined a space between the seal assembly and the rigid portion of the actuator ring, and when the seal assembly is in the energized position the space is closed, the rigid portion of the actuator ring contacts a surface of the casing hanger, and the flexible portion of the actuator ring pushes the lockdown ring into engagement with the wellhead, the flexible portion of the actuator ring adapted to axially compress to allow positional variation between the lockdown ring and the wellhead housing.

A liner hanger having one: or more enhanced Socking assemblies is provided. The liner hanger includes a liner hanger body, lower slips, upper slips, a packer cone, and a seal that seals an annulus between the liner hanger and an outer casing, The one or more enhanced locking assemblies may include: a packer cone locking assembly that prevents all components of the liner hanger from actuating until it is unlocked; a slips locking assembly that prevents the lower slips from being actuated until it is unlocked; guide rails that prevent. the lower slips and/or the upper slips from being wedged in a radially outward direction during run in; and a floating cone locking assembly that releases the packer cone from being coupled to a spacer of the liner hanger when it is unlocked.

An assembly for supporting one or more cables in coiled tubing deployed in a well is described. The assembly includes a receptacle connected to an upper opening of the coiled tubing. A receptacle clamp is connected to the receptacle to provide a circumferential lateral extension surface. A separate extension column having a base portion is supported on the lateral extension surface. The extension column has an upper platform surface separated vertically from the base portion. A cable clamp is supported on the upper platform surface and configured to reversibly grip the one or more cables. The assembly is useful for any process requiring support of cables in coiled tubing deployed in a well, such as a process for assembling a heater for providing underground heat.

A managed pressure drilling (MPD) system including a work string including tubulars having an internal flow path. The work string supports a liner float. A liner hanger running tool is coupled to the work string uphole of the liner float. An MPD sub is coupled to the work string and is operable to close off the internal flow path to fluid pressure passing uphole from the liner float in a first position and opens the internal flow path to fluid pressure after the liner string reaches a target depth. The MPD sub includes a housing having a rotatable ball valve including a ball. A ball seat is arranged between the rotatable ball valve and the downhole end, and a ball engagement member arranged between the rotatable ball valve and the uphole end. The ball engagement member includes a seal component that engages the ball portion.

A managed pressure drilling (MPD) system including a work string including tubulars having an internal flow path. The work string supports a liner float. A liner hanger running tool is coupled to the work string uphole of the liner float. An MPD sub is coupled to the work string and is operable to close off the internal flow path to fluid pressure passing uphole from the liner float in a first position and opens the internal flow path to fluid pressure after the liner string reaches a target depth. The MPD sub includes a housing having a rotatable ball valve including a ball. A ball seat is arranged between the rotatable ball valve and the downhole end, and a ball engagement member arranged between the rotatable ball valve and the uphole end. The ball engagement member includes a seal component that engages the ball portion.