A blowout preventer and method of operating a wellbore. The blowout preventer has a main body containing a wellbore, a passage transverse to the wellbore, a shearing device located in the passage; and a charge that, when activated, propels the shearing device along the passage and across the wellbore to close the wellbore and prevent a blowout.

A well pressure control device includes a housing having a through bore. A pressure chamber has a piston movably disposed therein. The pressure chamber is coupled at one end to the housing transversely to the through bore. The actuating piston defines a pressure source side and a through bore side of the pressure chamber. A fluid pressure source is coupled to the other end of the pressure chamber. A closure element is disposed in the pressure chamber on the through bore side. At least one locking element is coupled to the pressure chamber at an axial position along the pressure chamber on the through bore side

A multi-intervention blowout preventer includes a body having a bore therethrough. A first pair of ram blocks may be coupled to the body and include a ram, a catcher, and a blade operationally connected to the bore via a first pair of openings in the body. The ram, the catcher, and the blade may cut a flexible line extending through the bore while holding the flexible line. A second pair of ram blocks may be coupled to the body and include a second pair of rams operationally connected to the bore via a second pair of openings in the body to seal around a tubular. A third pair of ram blocks may be coupled to the body and include a third pair of rams operationally connected to the bore via a third pair of openings in the body to seal the bore.

A blowout preventer includes a main body having a through bore. A pressure chamber is located adjacent to and transverse to the through bore. A gate is disposed in the pressure chamber. An insert is disposed in the main body and defines an opening therethrough parallel to the through bore. The insert also defines a passage therethrough transverse to the through bore for passage of the gate.

The method of preventing pressures higher than a predetermined pressure in the front ram seals of blowout preventer rams comprising providing blowout preventer rams suitable for sealing across the bore of a blowout preventer stack, providing seals on the blowout preventer rams which sealingly isolate the bore area below or upstream of the blowout preventer rams from the area above or downstream of the blowout preventer rams, providing a passageway from the front to the rear of the blowout preventer rams to vent the upstream or higher pressures to the rear of the blowout preventer rams, and communicating the resilient seal material in the front ram seals with a pressure release piston which will relieve the pressure at the predetermined pressure.

A closing unit system for a blowout preventer (BOP) stack includes a first fluid reservoir, a first power source, a first pump system fluidly coupled to the first fluid reservoir and electrically coupled to the first power source, and a valve manifold fluidly coupled to the first pump system via a closing unit hose assembly and configured to couple to the BOP stack. The closing unit system also includes one or more processors that are configured to receive an input indicative of an instruction to adjust an actuator associated with the BOP stack, and instruct the first power source to provide power to the first pump system to cause the first pump system to pump a fluid from the first fluid reservoir to the valve manifold in response to the input.

A safety valve for wells for the extraction of hydrocarbons is described which allows the cutting of the tubular drilling material possibly present in the safety valve and the closure of the well with a hydraulic seal, allowing the subsequent application of appropriate intervention plans to control the well in case the BOPs are not effective. A safety valve for wells for the extraction of hydrocarbons is described which is able to perform the action of cutting the tubular material with a higher capacity than conventional BOPs, considering the worst conditions of compound stresses at the wellhead, which are not contemplated by such BOPs today. In particular, the safety valve is capable of cutting/shearing a wide range of tubular elements in its inside.

The present disclosure relates to a ram system for a blowout preventer. The ram system includes a first ram having an interlocking arm, where the interlocking arm includes a first anti-deflection feature. The ram system includes a second ram having a second anti-deflection feature. The first ram and the second ram are configured to move toward one another along a longitudinal axis to reach an engaged configuration. The second ram is configured to receive the interlocking arm of the first ram to enable the first anti-deflection feature to engage with the second anti-deflection feature while the first ram and the second ram are in the engaged configuration to thereby enable the first and second anti-deflection features to block deflection of the interlocking arm relative to a lateral axis, an axial axis, or both.

A leak detection and collection system includes a cap configured to couple to a wellbore component. The system also includes an alert system removably coupled to the cap and a packer coupled to the cap. The packer extends into a bore of the wellbore component and the packer is actuated to seal against the wellbore component and to block flow through the bore. The system further includes a release mechanism coupled to the alert system, a first flow path, an accumulator, and a second flow path. The release mechanism is activated at a first pressure above a first threshold to release the alert system and the second flow path directs flow to the accumulator at a second pressure above a second threshold.

In some embodiments, a method for executing an emergency disconnect sequence in shallow water depth includes unlatching a lower marine riser package (LMRP) of a blowout preventer (BOP) from a lower stack of the BOP. The BOP defines a wellbore fluidically coupled to the subsea wellhead. A tubular is disposed within the wellbore. The method further includes shearing the tubular and sealing the wellbore. In response to an indication that a vessel operably coupled to the BOP has failed to keep station, an unlatch sequence and a shear and seal sequence are initiated, such that each sequence occurs at least partially simultaneously. The unlatch sequence includes disconnecting the LMRP from the lower stack, and the shear and seal sequence includes activating the lower stack to shear the tubular in less than about one second and seal the wellbore.