A tubing hanger running tool assembly includes a ring extending around a tubing hanger in a wellhead, and having a contracted configuration and an expanded configuration. The ring in the expanded configuration is received into a groove in the wellhead. The assembly includes a sleeve to actuate the ring between the contracted and expanded configurations. The sleeve includes a tubing hanger running tool received through the sleeve and having a lower end that is configured to be received into a first bore of the tubing hanger and to form a connection therewith. The tubing hanger running tool is configured to transmit an axial force to the sleeve in response to the tubing hanger running tool being received into the tubing hanger. The axial force moves the sleeve axially with respect to the ring, which actuates the ring between the contracted and expanded configurations.

A system for controlling surge pressure and deployed into a wellbore drilled using a managed pressure drilling technique includes auto-fill float equipment allowing flow into a liner casing string, a drillpipe diverter providing a flow path between a drillpipe landing string and an annulus, and a drillpipe flow restrictor selectively blocking the flow path from the top of the drillpipe landing string while allowing fluid to be displaced up the liner casing string and into the annulus. The drillpipe flow restrictor and the drillpipe diverter are convertible to provide a flow path from the wellbore through the auto-fill float equipment to a top surface while blocking flow through the diverter into the annulus. The auto-fill float equipment is convertible to block the flow path from the wellbore into the liner casing string, while allowing fluid to flow from the liner casing string into the wellbore.

A system to provide at least two circumferential metal to metal seals between coaxial tubulars. Where a first tubular includes a circumferential shoulder having a circumferential first metal seal and a circumferential second metal seal. A second tubular has a circumferential shoulder that matches and abuts the first tubular circumferential shoulder. Each metal seal is of a material having a higher yield strength than the second tubular shoulder such that the first metal seal and the second metal seal will penetrate the material of the second tubular shoulder thereby providing a seal. Additionally a test port is provided from the exterior of the exterior tubular to a point on either the first or second tubular between the first and second metal seals.

A system to provide at least two circumferential metal to metal seals between coaxial tubulars. Where a first tubular includes a circumferential shoulder having a circumferential first metal seal and a circumferential second metal seal. A second tubular has a circumferential shoulder that matches and abuts the first tubular circumferential shoulder. Each metal seal is of a material having a higher yield strength than the second tubular shoulder such that the first metal seal and the second metal seal will penetrate the material of the second tubular shoulder thereby providing a seal. Additionally a test port is provided from the exterior of the exterior tubular to a point on either the first or second tubular between the first and second metal seals.

A tubing hanger includes: a mandrel for connection to a tubing string; an outer hanger body for supporting the mandrel in the well, the mandrel supported in a main bore of the outer hanger body by J-lock mechanisms. The outer hanger body can be supported in the tubing head or in bowl of a tubing rotator.

A single-tube double-wellhead drilling and production apparatus is provided, which includes a suction pile, two first wellhead heads, two second wellhead heads, two second guiding pipes, two tubings, two tubing hangers, and two plugs located inside and connected with a corresponding second wellhead head. Each second wellhead head is connected to a corresponding first wellhead head and is connected through a connecting pipeline which is provided with a control valve and a check valve. One end of each first wellhead head is connected with a corresponding first guiding pipe connected with the suction pile. Each second guiding pipe is located inside a corresponding first guiding pipe and is connected to an end of a corresponding second wellhead head. Each tubing hanger is located in and connected with a corresponding second wellhead head, is located below and communicates with a corresponding plug, end of which is provided with a corresponding tubing.

A single-tube double-wellhead drilling and production apparatus is provided, which includes a suction pile, two first wellhead heads, two second wellhead heads, two second guiding pipes, two tubings, two tubing hangers, and two plugs located inside and connected with a corresponding second wellhead head. Each second wellhead head is connected to a corresponding first wellhead head and is connected through a connecting pipeline which is provided with a control valve and a check valve. One end of each first wellhead head is connected with a corresponding first guiding pipe connected with the suction pile. Each second guiding pipe is located inside a corresponding first guiding pipe and is connected to an end of a corresponding second wellhead head. Each tubing hanger is located in and connected with a corresponding second wellhead head, is located below and communicates with a corresponding plug, end of which is provided with a corresponding tubing.

A sleeve for protecting a lockdown screw of a wellhead assembly can include a body having an inner surface and an outer surface, wherein the body has a concave curvature, where the body is configured to be disposed within an upper portion of a recess of a component of the wellhead assembly inside of which the lockdown screw is disposed, where the concave curvature of the body is configured to match that of an inner wall of the component, and where the outer surface is configured to isolate the lockdown screw from an environment in a cavity partially formed by the inner surface when the body is disposed in the upper portion of the recess.

A sleeve for protecting a lockdown screw of a wellhead assembly can include a body having an inner surface and an outer surface, wherein the body has a concave curvature, where the body is configured to be disposed within an upper portion of a recess of a component of the wellhead assembly inside of which the lockdown screw is disposed, where the concave curvature of the body is configured to match that of an inner wall of the component, and where the outer surface is configured to isolate the lockdown screw from an environment in a cavity partially formed by the inner surface when the body is disposed in the upper portion of the recess.

A wellhead hanger assembly is provided. In one embodiment, a system includes a wellhead hanger, an inner sleeve coupled to the wellhead hanger, a running tool coupled to the inner sleeve, and an outer sleeve coupled to the running tool. The outer sleeve may be positioned to transmit torque from the running tool to the wellhead hanger, and the wellhead hanger may be in castellated engagement with the outer sleeve via a set of castellations and mating slots. Additional systems, devices, and methods are also disclosed.