A system for emptying a gravity separated fluid including a flexible bag storing the fluid arranged within a protection structure, the protection structure including a bottom element forming the lower section of the protection structure, the flexible bag being connected to the protection structure, and includes at least one fluid conduit providing fluid communication between the flexible bag and outside the protection structure. A first outlet pipe is arranged inside the flexible bag near the bottom element and is connected to and in fluid communication with the at least one fluid conduit. A perforated tube surrounding the outlet pipe provides an annulus fluid passage, water is supplied to the structure volume, and the fluid is emptied through the at least one fluid conduit, through the perforations in the perforated tube, through the annulus fluid passage to the first outlet pipe.

A system includes a running tool having a tool body configured to couple to a hanger assembly, a first sleeve disposed around the tool body and configured to move in an axial direction with respect to the tool body, a torque sleeve disposed around the tool body and configured to move in the axial direction as a result of movement of the first sleeve in the axial direction, where the torque sleeve has a first torque transfer interface configured to interlock with a second torque transfer interface of the hanger assembly to enable torque transfer from the running tool to the hanger assembly, and a second sleeve configured to couple to the first sleeve, where the second sleeve is configured to move to engage a lock member of the hanger assembly and to move the lock member between a locked position and an unlocked position.

An outer casing string, including a surface casing head, and associated installation method. In some embodiments, the surface casing head includes an outer tubular member insertable through a diverter of an installed conductor system, an inner tubular member at least partially disposed within and moveable relative to the outer tubular member, and a sleeve ring rotatably coupled to the inner tubular. The outer tubular member has an annular recess. The sleeve ring includes a snap ring that is displaceable between an extended position and a retracted position. In the extended position, at least a portion of the snap ring is received within the annular recess, and the outer tubular member is axially immovable relative to the inner tubular member. In the retracted position, no portion of the snap ring is received within the annular recess, and the outer tubular member is axially moveable relative to the inner tubular member.

A system for emptying a gravity separated fluid including a flexible bag storing the fluid arranged within a protection structure, the protection structure including a bottom element forming the lower section of the protection structure, the flexible bag being connected to the protection structure, and includes at least one fluid conduit providing fluid communication between the flexible bag and outside the protection structure. A first outlet pipe is arranged inside the flexible bag near the bottom element and is connected to and in fluid communication with the at least one fluid conduit. A perforated tube surrounding the outlet pipe provides an annulus fluid passage, water is supplied to the structure volume, and the fluid is emptied through the at least one fluid conduit, through the perforations in the perforated tube, through the annulus fluid passage to the first outlet pipe.

A well construction method in which a drilled bore is lined with a plurality of successively smaller diameter sections of bore-lining tubing including casing sections a liner section is provided. A liner is provided with an inner string extending to a distal end of the liner. The liner and the inner string are run into a distal section of a drilled bore. Settable material is pumped from surface through the inner string and through the distal end of the liner to partially fill an outer annulus surrounding the liner. Fluid displaced from the outer annulus and a portion of the settable material is permitted to flow from the outer annulus through a port in the liner and into an inner annulus between the inner string and the liner.

A system for emptying a gravity separated crude oil including a flexible bag storing the crude oil arranged within a protection structure, the protection structure including a bottom element forming the lower section of the protection structure, the flexible bag being connected to a flange that is connected to the protection structure, and includes at least one fluid conduit providing fluid communication between the flexible bag and outside the protection structure. A first outlet pipe is arranged inside the flexible bag near the bottom element and is connected to and in fluid communication with the at least one fluid conduit. A perforated tube surrounding the outlet pipe provides an annulus fluid passage, water is supplied to the structure volume, and the crude oil is emptied through the at least one fluid conduit, through the perforations in the perforated tube, through the annulus fluid passage to the first outlet pipe.

A method of locating bore-lining tubing, such as a liner (120), in a drilled bore (106) comprises selecting a buoyant material, such as air (138), having a density lower than the density of an ambient fluid, such as well fluid (180, 182). The buoyant material (138) and an inner tubing (140) are located within the bore-lining tubing (120) with the inner tubing (140) extending from a distal end of the bore-lining tubing to a proximal end of the bore-lining tubing. The inner tubing (140) is sealed to the distal end of the bore-lining tubing (120) and to a portion of the bore-lining tubing (120) spaced from the distal end to define an inner annulus (152) between the inner tubing (140) and the bore-lining tubing (120). A volume of the buoyant material (138) is retained within the inner annulus (152). An assembly (168) comprising the inner tubing (140) and the bore-lining tubing (120) and containing the volume of buoyant material (138) is run into a drilled bore (106). Fluid (126a) may be flowed through the inner tubing (140) and into an outer annulus (124) surrounding the bore-lining tubing (120).

A device is for reducing the load on a wellhead casing from a bending moment generated by a horizontal load component from a well element arranged over a wellhead. A supporting frame is connected to an upper portion of the wellhead casing and projects outwards from the center axis of the wellhead casing and is provided with an abutment which rests supportingly against a base at a radial distance from the wellhead casing. The supporting frame is arranged to absorb a portion of said bending moment.

A wellbore lining system that puts liners into place immediately behind the drill head tool is used in drilling and for preparing natural gas hydrate (NGH) deposits for production of its natural gas. The system overcomes the requirement of setting casing from the wellhead, which controls well bore diameter with depth and allows for flexibility in well bore size at any depth. Wellbore liners stabilize the well walls by being very tightly fitting against bounding rocks and sediments, which overcomes the requirement for cementing, which commonly accompanies conventional well casing. In addition, liners can be emplaced with designed impermeability, permeability, and complex flow-through patterns so that production processes, such as sand flow, can be put in place as part of a liner section.

An apparatus includes a first flow line, a second flow line and a seabed-disposed pump station. The first and second flow lines extend to a sea surface platform. The pump station to, in response to a shut down of a production flow in the first flow line, operate a pump of the station to transfer liquid from the first flow line to the second flow line to reduce a liquid column in the first flow line and push liquid in the second flow line to the sea surface platform for removal; and open a bypass valve for the pump to allow a liquid column in the second flow line to decrease to reduce a pressure in the second flow line during a period in which the pump station is shut down. The pump station may also be operated to communicate a pig through flow lines, and during a time interval in which the production is shut down, the pump station may be operated in a bypass mode to prevent hydrate formation in a subsea flow line.