An offshore hydrocarbon processing facility (2) comprises an offshore floating structure (8) and a submerged floating riser deck (10). The submerged floating riser deck is operatively connected to a subsea hydrocarbon riser (12). Hydrocarbon processing equipment (26) is disposed on the submerged floating riser deck. The offshore floating structure (8) may be connected to the submerged floating riser deck (10) using a riser (16) that can be disconnected if there is inclement weather.

A method for pressure protection of an offshore platform (14, 16) of an oil and gas installation, the offshore platform (14, 16) being connected to source of hydrocarbons via a pipeline (18), the method comprising: using a safe link device (62) at the pipeline (18); wherein the safe link device (62) is located subsea and outside of the safety zone of the platform (14), (17); protecting the platform via a subsea High Integrity Pressure Protection System (HIPPS) for the platform (14, 16) and/or the pipeline (18); and wherein the safe link device (62) is arranged to activate to release pressure from the pipeline (18) when the pressure exceeds a preset threshold that is above the normal ultimate limit state pressure for the platform (14, 16).

Techniques for allocating hydrocarbon production include receiving a selection of a particular area identification (ID) of a plurality of area IDs stored on the server; determining based on the selected particular area ID, a plurality of hydrocarbon production values that include periodic area-level hydrocarbon production values associated with the particular area ID and a plurality of wells associated with the particular area ID; determining a decline curve model for the area-level hydrocarbon production values associated with the particular area ID; modeling the aggregated periodic well-level hydrocarbon production values with the determined decline curve model; and determining allocated well-level hydrocarbon production values based at least in part on the selected decline curve model to display at a client device.

A subsea connector assembly with flowmeter incorporated therein. The assembly is particularly configured for securing a flexible flowline at subsea production managing hardware such as at a manifold at a seabed or Christmas tree at a well head. Incorporating a flowmeter into the connector as opposed to such comparatively larger scale hardware ultimately saves substantial material, transport, installation, footspace and other costs.

A flow base system (1) for subsea wells is disclosed, the flow base system comprising a header pipe (2) for production fluid extended through the flow base system, wherein from opposite sides of the header pipe (3) a set of flow base modules (2), respectively, is connected for supply of production fluid to the header pipe (3) via individual branch pipes (10) connecting the header pipe (3) with a Christmas tree (XT) interface (11) arranged for vertical connection to an XT respectively. The flow base system (1) is installed in a well template structure (18), wherein a flow base module (2) respectively is inserted into each well slot (S1-S4) formed in the well template structure (18).

A flow base system (1) for subsea wells is disclosed, the flow base system comprising a header pipe (2) for production fluid extended through the flow base system, wherein from opposite sides of the header pipe (3) a set of flow base modules (2), respectively, is connected for supply of production fluid to the header pipe (3) via individual branch pipes (10) connecting the header pipe (3) with a Christmas tree (XT) interface (11) arranged for vertical connection to an XT respectively. The flow base system (1) is installed in a well template structure (18), wherein a flow base module (2) respectively is inserted into each well slot (S1-S4) formed in the well template structure (18).

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.

An underwater hydrocarbon processing facility has at least one fluid processing clusters provided with modules having, each, one fluid processing device and a plurality of first connection members configured to define the inlet and the outlet of the process fluids; and an interconnection unit having a plurality of second connection members defining inlet and outlet for the process fluids and configured to be operatively coupled to corresponding first connection members configured to operatively interconnect the modules.

An underwater hydrocarbon processing facility has at least one fluid processing clusters provided with modules having, each, one fluid processing device and a plurality of first connection members configured to define the inlet and the outlet of the process fluids; and an interconnection unit having a plurality of second connection members defining inlet and outlet for the process fluids and configured to be operatively coupled to corresponding first connection members configured to operatively interconnect the modules.