A ram type blowout preventer is designed to provide substantial hang off capability. Improved hang off capacity is provided by the ram bodies having shaped upper centralizing lobes and/or semi-circular or U-shaped central openings. In particular, the interface between the upper centralizer lobe and central opening is tapered such that the hang off load is spread over a larger area of each ram body.

A blow out preventer bonnet removal method is provided for removing a bonnet from the body of a blow out preventer. The method includes attaching a rail system to the body that extends laterally away from the body. A carriage apparatus is mounted on the rail system. A saddle is connected to the bonnet. The bonnet is then detached from the body. The bonnet is then moved on the rail system from a first position next to the body to a second position spaced away from the body. The carriage apparatus transports the bonnet upon the rail system when moving from the first to the second position.

Image sensors are positioned around a rig floor. An on-site edge or fog computing gateway is communicably coupled to the image sensors. The on-site edge or fog computing gateway includes one or more processors and a non-transitory computer-readable storage medium coupled to the one or more processors and storing programming instructions for execution by the one or more processors. The programming instructions instruct the one or more processors to do the following: receive an image stream form at least one of the plurality of image sensors; generate, from the image stream, an operating condition; determine that an automation rule includes the operating condition generated from the image stream; in response to determining that an automation rule includes the operating condition, send an instruction to drive a controllable device; and, in response to sending an instruction to drive the controllable device, drive the controllable device.

A monitoring system includes an image sensor positioned about a rig, the image sensor directed at a drill string component positioned on the rig, and an onsite gateway communicably coupled to the image sensor and disposed proximate to the rig. The onsite gateway includes one or more processors, and a non-transitory computer-readable storage medium coupled to the one or more processors and storing programming instructions for execution by the one or more processors. The programming instructions instruct the one or more processors to receive an image stream of the drill string component from the image sensor, identify an operating parameter of the drill string component, generate an operating condition of the drill string component, determine that the generated operating condition meets a failure threshold of the drill string component, and send an instruction to drive a controllable device.

One or more images of a tubular being run into a well are captured. The one or more images can be captured by an image sensor. The tubular includes a first tubular section and a second tubular section connected together by a connection. An onsite edge gateway local to the image sensor is configured to perform various operations. Based on the captured one or more images, an elevation of the connection relative to a reference elevation of the well is determined. Based on the determined elevation, an operating condition is determined. It is determined whether the operating condition is included in an automation rule. In response to determining that the automation rule includes the operating condition, a signal is transmitted to drive a controllable device.

An assembly for a valve includes an inner cylinder, an outer cylinder circumferentially surrounding the inner cylinder, and a first bar comprising a first end portion coupled to the inner cylinder and a second end portion coupled to the inner cylinder. The second end portion extends radially outwardly through a groove extending circumferentially about a curved wall of the outer cylinder to enable the inner cylinder and the first bar to rotate relative to the outer cylinder.

An apparatus that includes at least two well control mechanisms and at least one sensor to avoid collision between a section of a tubing string coupler or that is moving through the apparatus and a wellbore to which the apparatus is coupled. The sensors detect the presence of magnetic objects, such as sections of a tubing string, and measure their respective outer diameters (OD). The sensors detect when any larger OD sections of the tubing string before the larger OD section can collide with one of the well control mechanisms. The sensors direct their outputs to a controller that can identify an imminent collision state. When an imminent collision state is identified, the controller will send commands to stop movement of the tubular to avoid the collision. Movement of the tubular will not resume until the well control mechanism has been actuated to avoid collision with the larger OD section.

An assembly for a valve includes an inner cylinder, an outer cylinder circumferentially surrounding the inner cylinder, and a first bar comprising a first end portion coupled to the inner cylinder and a second end portion coupled to the inner cylinder. The second end portion extends radially outwardly through a groove extending circumferentially about a curved wall of the outer cylinder to enable the inner cylinder and the first bar to rotate relative to the outer cylinder.

A leak containment system for sealing around a fluid flow member includes a ram sealing system mounted on a mobile vehicle. The ram sealing system has a sealing chamber having a generally cylindrical shape when the ram sealing system is in a closed position, and a ram assembly located at an end of the sealing chamber. The ram assembly has a pair of rams, each ram having an engaging surface, the engaging surface sized and shaped to seal around the fluid flow member. The ram assembly also has an actuating arm assembly connected to one of the rams and a ram body. The pair of rams is rotationally attached to the ram body.

A technique facilitates communication in a subsea well application. The technique involves deployment of a blowout preventer subsea control and telemetry system to a subsea location proximate a wellbore. The blowout preventer subsea control and telemetry system is coupled to both a blowout preventer system and a wireless telemetry system. The wireless telemetry system has a plurality of repeaters deployed along the wellbore. The blowout preventer subsea control and telemetry system is used both to collect data from the wireless telemetry system and to control operation of the blowout preventer system. For example, the blowout preventer subsea control and telemetry system may receive control signals from a surface system and also relay data to the surface system through a common communication line.