Systems and methods contain fluids discharged from a subsea well or at the surface by capping the well blowout with a pre-positioned capping device. The capping device includes at least one blind shear ram and is separate from a blowout preventer. The blowout preventer may operate to control well events up to a certain pressure, above which the capping device is employed since the capping device has a higher pressure rating than the blowout preventer.

A drilling package for an offshore wellbore having a wellhead, said drilling package comprising in a functional order a shear module situated above said wellhead and in fluid communication with said wellbore; a blowout preventer in fluid communication with the shear module; a lower marine riser package in fluid communication with the blowout preventer; and a bypass valve and port in a normal fluid path upstream of a well closure device that is actuated to divert flow from the normal path through the blowout preventer to an alternative flow path.

A subsea connection system has a subsea structure with a flow channel therein and a port at one end of the flow channel, a stab having a flowline connected thereto, and a frame affixed to the stab. The stab is adapted to engage the port of the subsea structure so as to allow a fluid to flow from the flowline into the flow channel. The frame has a hook portion that is engageable with a tool hanger of the subsea structure so as to support the stab in alignment with the port. The frame is pivotable about the tool hanger so as to move the stab toward the port. An actuator is cooperative with the stab so as to move the stab between a retracted position and an extended position.

A modular well containment cellar system having a bottom portion, two co-planar half-panels joined to the bottom portion and separated by a through-channel portion, and a one side wall joined to a bottom portion and to the half-panels, forming a closed container with an open top for mating to another cellar component at the half-panels, wherein a well pipe may be received into the through-channel. A plurality of drip diverters prevent downward-moving liquid from running between the mated half-panels and between the well pipe and the through-channel, to capture dripped and running liquids from above the containment cellar system.

A modular well containment cellar system having a bottom portion, two co-planar half-panels joined to the bottom portion and separated by a through-channel portion, and a one side wall joined to a bottom portion and to the half-panels, forming a closed container with an open top for mating to another cellar component at the half-panels, wherein a well pipe may be received into the through-channel. A plurality of drip diverters prevent downward-moving liquid from running between the mated half-panels and between the well pipe and the through-channel, to capture dripped and running liquids from above the containment cellar system.

A well system can include a generally tubular production string extending to a surface location. A production packer seals off an annulus external to the production string. A swellable packer is interconnected in the production string between the production packer and the surface location. A method of mitigating a leak in a generally tubular production string can include interconnecting a swellable packer in the production string, and the swellable packer swelling, and thereby increasingly restricting flow through an annulus surrounding the production string, in response to fluid leakage through a sidewall of the production string. Another method can include interconnecting a swellable packer in the production string, and the swellable packer swelling, and thereby increasingly restricting flow through an annulus surrounding the production string, in response to a flow of hydrocarbons into the annulus from an interior of the production string.

A system for emergency response to a well control incident is disclosed, which includes a capture device fitted to a subsea wellhead, a pipeline termination unit fluidly connected to the capture device, and a subsea module fluidly connected to the pipeline termination unit via a subsea flowline, wherein the subsea module comprises a subsea separator, and wherein the subsea module is anchored to a seabed. The system also includes a mini spar fluidly connected to the subsea module by a riser system.

This invention relates to a method and system for the three-dimensional reconstruction of material properties of a target using remotely located physical sensors using deep learning artificial intelligence. Utilizing the special technique disclosed here, the method provides an order of magnitude improvement in computational speed and memory requirements over current state-of-the-art artificial intelligence-based systems. The improvement in accuracy and resolution obtained enables high resolution imaging of buried infrastructure using above ground sensors mounted on drones and other devices. This makes it feasible to perform several first order inspection tasks related to pipeline health, corrosion, integrity, and others that are currently only possible using inline inspection tools such magnetic flux leakage (MFL) and ultrasonic (UT) sensors or via deployment of fiber optic sensors.

A sealable pipe adaptor is mounted directly on a hydrocarbon well head. A central branch is used for a drilling operation. The central branch has a first valve that is normally open and controllable during the drilling operation. The first valve contains a first sensor that is a shut-off sensor that shuts the first valve when a gush of oil or gas flow above a first preset safety threshold is detected. A first side branch has a second valve that is controllable during the drilling operation and during a production mode. The first side branch valve has a second sensor that opens the second valve when detecting a rogue hydrocarbon flow so that the rogue hydrocarbon flow is directed through the first side branch. The first side branch is connected to storage. A second side branch is connected to a production pipe. The first side branch has a third valve controllable from a production collection terminal. The third valve is normally closed during the drilling operation and is normally open during the production mode. The third valve contains a third sensor that is a shut-off sensor that shuts the third valve when a gush of oil or gas flow that is above a second preset safety threshold is detected.

An in-situ cultivation system of a deep-sea hydrothermal metallic sulfide deposits includes a hydrothermal metallic sulfide deposit mound body, a well casing, a well head control flow guide device, a fluid mixing control hood; the hydrothermal metallic sulfide deposit mound body includes a confining bed, a hydrothermal fluid enriching bed and mound body bedrock; perforations are formed at casing wall of the well casing; the well head flow control device is provided at top of the well casing; a lower opening is formed at bottom of the fluid mixing control hood and is sleeved on four sides of the top of the well casing; an upper opening is formed at top of the fluid mixing control hood; a plurality of fluid holes are formed at a lateral wall of the fluid mixing control hood; and a sulfide coating is applied to inner wall of the fluid mixing control hood.