Abstract: A device and method of handling a plug in a tubing hanger includes a pressure actuated sequence valve that has multiple outlets. Hydraulic fluid from a remotely operated vehicle (ROV) provides hydraulic fluid that selectively flows through the valve for operating a tool that handles the plug. The valve outlets are ported to separate lines for operating different functions of the tool. Flow to a specific outlet occurs by sequencing the valve to a corresponding position, where the valve is sequenced by changing pressure of the hydraulic fluid. The sequence valve is disposed in a piston that is axially movable within the tool. A stroking rod attaches to the piston, and is actuated by diverting flow to sides of the piston.

Abstract: A system for maneuvering a plug in and out of a tubing hanger mounts to a subsea wellhead assembly. The system includes a tractor and an end effector that are sheltered in a housing. A control cable spools from a reel mounted on the housing and attaches to the tractor. The control cable provides communication from a remotely operated vehicle (ROV) to the tractor and end effector so that commands from the ROV via the control cable control the tractor and end effector. After the housing connects to the wellhead assembly, control signals from the ROV activate the tractor to drive the end effector into the wellhead assembly and command the end effector to set the plug in the tubing hanger, or to remove the plug from the tubing hanger.

Abstract: A subsea wellhead assembly is provided. The subsea wellhead assembly comprises a tubing head structure with a tree above the tubing head structure, and a recoverable module attached to the tubing head structure below said tree, the recoverable module comprising at least one valve and at least one sensor.

Abstract: A positional feedback system includes a seal assembly coupled to a running tool, the seal assembly having a seal ring and an energizing ring positioned between a hanger and a subsea wellhead. The energizing ring moves relative to the seal ring from an unset position to a set position to seal to the wellhead and the hanger. The system includes a magnet disposed on the energizing ring and having a magnetic field. One or more sensing devices are disposed on running tool and positioned in the magnetic field of the magnet in the set position and the unset position. The sensing devices are configured to communicate with a surface platform when the rare earth magnet passes a magnetic field through the sensing devices.

Abstract: A device and method of handling a plug in a tubing hanger includes a pressure actuated sequence valve that has multiple outlets. Hydraulic fluid from a remotely operated vehicle (ROV) provides hydraulic fluid that selectively flows through the valve for operating a tool that handles the plug. The valve outlets are ported to separate lines for operating different functions of the tool. Flow to a specific outlet occurs by sequencing the valve to a corresponding position, where the valve is sequenced by changing pressure of the hydraulic fluid. The sequence valve is disposed in a piston that is axially movable within the tool. A stroking rod attaches to the piston, and is actuated by diverting flow to sides of the piston.

Abstract: A positional feedback system includes a seal assembly coupled to a running tool, the seal assembly having a seal ring and an energizing ring positioned between a hanger and a subsea wellhead. The energizing ring moves relative to the seal ring from an unset position to a set position to seal to the wellhead and the hanger. The system includes a magnet disposed on the energizing ring and having a magnetic field. One or more sensing devices are disposed on running tool and positioned in the magnetic field of the magnet in the set position and the unset position. The sensing devices are configured to communicate with a surface platform when the rare earth magnet passes a magnetic field through the sensing devices.

Abstract: A system for maneuvering a plug in and out of a tubing hanger mounts to a subsea wellhead assembly. The system includes a tractor and an end effector that are sheltered in a housing. A control cable spools from a reel mounted on the housing and attaches to the tractor. The control cable provides communication from a remotely operated vehicle (ROV) to the tractor and end effector so that commands from the ROV via the control cable control the tractor and end effector. After the housing connects to the wellhead assembly, control signals from the ROV activate the tractor to drive the end effector into the wellhead assembly and command the end effector to set the plug in the tubing hanger, or to remove the plug from the tubing hanger.

Abstract: A subsea wellhead assembly is provided. The subsea wellhead assembly comprises a tubing head structure with a tree above the tubing head structure, and a recoverable module attached to the tubing head structure below said tree, the recoverable module comprising at least one valve and at least one sensor.

Abstract: An apparatus to provide electrical coupling between two components in a well system is proposed. The apparatus includes a first component disposed around a well-bore and configured to host electrical connections. A second component is disposed concentrically around the first component and configured for power coupling with the first component. A first power coupling unit is disposed on the first component and configured to host one or more transceivers and resonators. A second power coupling unit is disposed on the second component and configured to host one or more transceivers and resonators. The transceivers and resonators on the first and second power coupling units are configured to transfer power in a contactless manner.

Abstract: Casing segments and an expansion cone are positioned and cemented within a new section of a wellbore with a lower casing segment in an overlapping relationship with an upper casing segment. The lower casing segment is radially expanded such that an upper end of the lower casing segment comes into contact with the interior wall of the upper casing segment at the overlap region. The upper casing segment has an inward facing profile at the overlap region that includes a set of wickers that are driven into the lower casing exterior when it is expanded. This forms a metal-to-metal seal between the upper and lower casing segments at the overlap region.

Abstract: An apparatus to provide electrical coupling between two components in a well system is proposed. The apparatus includes a first component disposed around a well-bore and configured to host electrical connections. A second component is disposed concentrically around the first component and configured for power coupling with the first component. A first power coupling unit is disposed on the first component and configured to host one or more transceivers and resonators. A second power coupling unit is disposed on the second component and configured to host one or more transceivers and resonators. The transceivers and resonators on the first and second power coupling units are configured to transfer power in a contactless manner.

Abstract: In a subsea wellhead assembly, a tubing hanger in communication with the subsea well has a hanger port extending through its side. A diverter surrounds the tubing hanger and diverts well fluid transmitted from the hanger port around a portion of the tubing hanger. The diverter transmits the well fluid to the inner surface of a wellhead member. A production port extending through a side of the wellhead member transmits the well fluid from the tubing hanger and diverter to an exterior of the wellhead member.

Abstract: A subsea wellhead assembly has a tree that connects internally to the bore of wellhead housing. The tree has a lower end that has a lock member that is moved radially outward into engagement with a profile in the bore of the wellhead housing. The tree is a monobore, having a production passage but no tubing annulus passage extending through it. The tubing hanger has a tubing annulus passage and a production passage. A valve is mounted in the tubing hanger for controlling flow through the tubing annulus passage.

Abstract: In a subsea wellhead assembly, a tubing hanger in communication with the subsea well has a hanger port extending through its side. A diverter surrounds the tubing hanger and diverts well fluid transmitted from the hanger port around a portion of the tubing hanger. The diverter transmits the well fluid to the inner surface of a wellhead member. A production port extending through a side of the wellhead member transmits the well fluid from the tubing hanger and diverter to an exterior of the wellhead member.

Abstract: A subsea wellhead assembly has a tree that connects internally to the bore of wellhead housing. The tree has a lower end that has a lock member that is moved radially outward into engagement with a profile in the bore of the wellhead housing. The tree is a monobore, having a production passage but no tubing annulus passage extending through it. The tubing hanger has a tubing annulus passage and a production passage. A valve is mounted in the tubing hanger for controlling flow through the tubing annulus passage.

Abstract: A subsea well uses a shuttle valve for connecting tubing annulus passageways between a riser and a tree of a subsea well. The riser has a connector that lands on an upper end of a tree. The riser connector has a production passage and an annulus port. An internal tree cap is located within the tree. A production passage passes through the internal tree cap and an annulus passage communicates with a top surface of the internal tree cap and the annulus passage of the tree. The shuttle valve is located within a valve receptacle or valve cylinder in an upper end of the annulus passage. A portion of the shuttle valve extends above the upper surface of the internal tree cap so that the shuttle valve opens when the riser connector lands on the top of the internal tree cap. Alternatively, the shuttle valve may be hydraulically actuated.

Abstract: A method for installing a string of tubing in a subsea well has a provision for killing the well due to malfunction while the tubing is being installed. A running tool is attached to a tubing hanger located at the upper end of the string of tubing. A completion safety module secures to the running tool and to a monobore running string. The assembly is lowered through a riser into the well, with the tubing hanger landing in a production tree. After the tubing hanger has been secured to the tree, earth formation pressure is communicated to the interior of the string of tubing while the running tool still remains connected to the tubing hanger. If a problem occurs, and the valves of the completion safety module fail to open, rams of the riser blowout preventer are closed around the running tool. The running tool is then disconnected from the tubing hanger and allowed to move upward a short distance due to pressure in the well.