The present invention relates to a hub block (2) with two hubs (3a, 3b), each configured for connection with a branch pipe from a well. The two hubs are in line with each other. A flowline bore (12) extends between flowline inlet and exit ports (5, 10). The flowline bore (12) is intersecting and in fluid connection with two branch bores (23a, 23b) extending from the flowline bore (12) and to the hubs (3a, 3b). Two valve bores (11a, lib) extend across the branch bores (23a, 23b). Furthermore the invention relates to a 2-slot inline block (1) with a hub block (2) and a manifold assembly of a plurality of 2-slot inline blocks (1).

The present invention relates to a hub block (2) with two hubs (3a, 3b), each configured for connection with a branch pipe from a well. The two hubs are in line with each other. A flowline bore (12) extends between flowline inlet and exit ports (5, 10). The flowline bore (12) is intersecting and in fluid connection with two branch bores (23a, 23b) extending from the flowline bore (12) and to the hubs (3a, 3b). Two valve bores (11a, lib) extend across the branch bores (23a, 23b). Furthermore the invention relates to a 2-slot inline block (1) with a hub block (2) and a manifold assembly of a plurality of 2-slot inline blocks (1).

A method includes mounting a lower platform block (300) to a plurality of piles (215) positioned on a surface. The lower platform block includes a first frame (315), a plurality of docking assemblies (305) connected to the first frame and engaging the piles, and a plurality of conductor tubes (310) connected to the first frame to a plurality of piles. The docking assemblies are released from the piles to separate the lower platform block from the piles.

A subsea manifold (150) is integrated into a pipeline (22) so as to be deployable to the seabed together with the pipeline, from a pipe-laying vessel. The subsea manifold comprises a hub (106a, 106b) for receiving production fluid from at least one subsea christmas tree (54a, 54b), and further comprises a connection (112) for at least one service line (116) connected to a surface supply or control or monitoring facility.

A subsea manifold (150) is integrated into a pipeline (22) so as to be deployable to the seabed together with the pipeline, from a pipe-laying vessel. The subsea manifold comprises a hub (106a, 106b) for receiving production fluid from at least one subsea christmas tree (54a, 54b), and further comprises a connection (112) for at least one service line (116) connected to a surface supply or control or monitoring facility.

A subsea well installation is provided, comprising a first pipeline comprising a first valve arrangement and a second pipeline comprising a second valve arrangement. The first valve arrangement is connected to a first subsea well and the second valve arrangement is connected to a second subsea well. The first valve arrangement is connected to the second valve arrangement. The installation is arranged such that fluid can be routed from the first well to any of the first pipeline and second pipeline. Each valve arrangement may comprise three two-way ball valves. Also provided is a method of installing the subsea well installation and a method of operating the subsea well installation.

A subsea well installation is provided, comprising a first pipeline comprising a first valve arrangement and a second pipeline comprising a second valve arrangement. The first valve arrangement is connected to a first subsea well and the second valve arrangement is connected to a second subsea well. The first valve arrangement is connected to the second valve arrangement. The installation is arranged such that fluid can be routed from the first well to any of the first pipeline and second pipeline. Each valve arrangement may comprise three two-way ball valves. Also provided is a method of installing the subsea well installation and a method of operating the subsea well installation.

A method transports and installs a heavy subsea structure such as a subsea processing center for produced crude oil or natural gas. The method includes controlledly flooding at least one ballast tank attached to or incorporated into the structure to the extent that the structure becomes negatively buoyant at a pre-determined towing depth. The method also includes towing the negatively-buoyant structure at the towing depth by the Controlled Depth Towing Method (CDTM). After towing to the installation location, the method includes further flooding the ballast tank to lower the structure onto the seabed. At the seabed, a fluid transportation pipe of a subsea production installation may be coupled to pipework of the structure.

A method transports and installs a heavy subsea structure such as a subsea processing center for produced crude oil or natural gas. The method includes controlledly flooding at least one ballast tank attached to or incorporated into the structure to the extent that the structure becomes negatively buoyant at a pre-determined towing depth. The method also includes towing the negatively-buoyant structure at the towing depth by the Controlled Depth Towing Method (CDTM). After towing to the installation location, the method includes further flooding the ballast tank to lower the structure onto the seabed. At the seabed, a fluid transportation pipe of a subsea production installation may be coupled to pipework of the structure.

A rigid valve block body and a method for determining fluid flow direction are disclosed. The valve block body includes a first fluid inlet and a further fluid inlet at opposed sides of a rigid valve block body. A first fluid outlet of the valve block body and a further fluid outlet of the valve block body are disposed in a spaced apart relationship. A first V-shaped fluid communication passageway comprises two passageway portions each extending within the valve block body from a first common root region proximate to the first fluid inlet. A further V-shaped fluid communication passageway comprises two further passageway portions each extending within the valve block body away from a further common root region proximate to the further fluid port. An end region of each passageway portion of the first V-shaped fluid communication passageway meets an end region of a respective passageway portion of the further V-shaped fluid communication passageway proximate to a respective fluid outlet.