Abstract: A method for remotely evaluating fatigue damage of a subsea wellhead may include obtaining a plurality of values associated with measurements of a parameter associated with the fatigue damage of the subsea wellhead during field operations, wherein the measurements are measured by a sensor device positioned separately from and adjacent to the subsea wellhead; executing an algorithm using the measurements to generate a result; comparing the result of the algorithm with a range of acceptable values; and determining that the subsea wellhead has a potential failure when the result falls outside the range of acceptable values.

Abstract: A wellhead bracing system for a subsea well includes a base plate assembly and a wellhead brace assembly. The base plate assembly comprises a top surface, a bottom surface, a base plate aperture, and a plurality of anchor holes. The wellhead brace assembly comprises a vertical plate assembly having a cylindrical shape, a horizontal plate assembly to which the vertical plate assembly is attached, and a vertical support assembly attached to an outer surface of the vertical plate assembly and attached to the top surface of the horizontal plate assembly. Horizontal plate holes of the horizontal plate assembly are configured to attach to studs on the top surface of the base plate to secure the wellhead brace assembly to the base plate assembly. The wellhead bracing system slides onto a wellhead of the subsea well and braces an exterior of the wellhead.

Abstract: The wave characteristics of the water (e.g., ocean) above a wellhead may be used to determine a wave-induced wellhead fatigue damage rate for the wellhead, and the current profile of water around a riser connected to the wellhead may be used to determine a riser vortex-induced vibration caused fatigue damage rate for the wellhead. The wave-induced wellhead fatigue damage rate and the riser vortex-induced vibration caused fatigue damage rate for the wellhead may be combined to obtain the total wellhead fatigue damage rate for the wellhead, which may be used to make operational decisions, such as connections or disconnections, for the well.

Abstract: A wellhead bracing system for a subsea well includes a base plate assembly and a wellhead brace assembly. The base plate assembly comprises a top surface, a bottom surface, a base plate aperture, and a plurality of anchor holes. The wellhead brace assembly comprises a vertical plate assembly having a cylindrical shape, a horizontal plate assembly to which the vertical plate assembly is attached, and a vertical support assembly attached to an outer surface of the vertical plate assembly and attached to the top surface of the horizontal plate assembly. Horizontal plate holes of the horizontal plate assembly are configured to attach to studs on the top surface of the base plate to secure the wellhead brace assembly to the base plate assembly. The wellhead bracing system slides onto a wellhead of the subsea well and braces an exterior of the wellhead.

Abstract: An annular blowout preventer includes a body, a piston disposed within the body, and a packing unit disposed adjacent the piston. The packing unit includes an packer body surrounding an opening. The packer body is fabricated from a first material. The packing unit further includes a second material disposed between the packer body and the opening, the second material being less rigid than the first material. The packer body and the second material constrict the opening when the annular blowout preventer is actuated. The second material creates a seal around a tool disposed within the opening. The second material fills in one or more crevices or recesses on an outer perimeter of the tool.

Abstract: An annular blowout preventer includes a body, a piston disposed within the body, and a packing unit disposed adjacent the piston. The packing unit includes an packer body surrounding an opening. The packer body is fabricated from a first material. The packing unit further includes a second material disposed between the packer body and the opening, the second material being less rigid than the first material. The packer body and the second material constrict the opening when the annular blowout preventer is actuated. The second material creates a seal around a tool disposed within the opening. The second material fills in one or more crevices or recesses on an outer perimeter of the tool.