There is provided a method of interconnecting a conduit and a plurality of subsea structures. The method comprises providing a first manifold header in-line of the conduit, where the first manifold header has at least one valve installed therein, A portion of the conduit is lowered to the sea bed such that the first manifold header is engaged with a first subsea structure, and a further portion of the conduit is lowered to the sea bed. A second manifold header, having at least one valve installed therein, is provided in-line of the conduit and engaged with a second subsea structure. The length of conduit provided on the sea bed between the first subsea structure and the second subsea structure is significantly greater than the distance between the first and second subsea structures.

A system for conveying a fluid produced from at least one producing subsea well to an existing host facility via a flowline includes a support structure having at least a deck, a mooring system, and a plurality of topsides modules. The mooring system anchors the support structure to a seabed and passively positions the support structure proximate to the at least one producing subsea well. The support structure elevates the deck above a water's surface and is normally unmanned. The plurality of topsides modules are disposed on the deck. The topsides modules include at least: a power generation module; a switchgear module a flowline heating module; a chemical injection module; a water injection module; a subsea control module; and a control module that communicates with a remote command center.

The invention relates to an umbilical for use between an offshore construction (10) and a seabed installation (20), comprising one or more of longitudinal umbilical elements, such as one or more filler element, one or more signal cable, one or more fiber optic, one or more electrical power cable, and/or one or more load carrying element like carbon fiber rod, the umbilical further comprises at least one fluid pipe (1a, 1b) arranged within the umbilical (1), the longitudinal umbilical elements (1a, 1b) and the at least one fluid pipe (1a, 1b) are either laid in a continuous helix, or alternatingly/oscillatory laid within the umbilical. The at least one fluid pipe (1a, 1b) is a mix of at least one seamless pipe (1a) and at least one seam-welded pipe (1b), the at least one seamless pipe (1a) and the at least one seam-welded pipe (1b) are spliced together at one or more predetermined locations in the longitudinal direction of the umbilical (1). The invention further relates to a use and a method for arranging the umbilical between the sea-surface offshore construction (10) and a seabed subsea installation (20).

Rigid riser adapter operable to be at least partially installed into a lower riser balcony. The rigid riser adapter includes a receptacle support structure. Additionally, the rigid riser adapter also includes an adapter tube extending from the receptacle support structure substantially along a vertical direction, the adapter tube operable to be inserted through a lower riser balcony. The rigid riser adapter can also include a rigid riser receptacle coupled to the receptacle support structure, wherein the rigid riser receptacle is angled between six degrees and twenty degrees in relation to the vertical direction.

A subsea horizontal tie-in system comprising a porch part (100) with a porch hub (101a), a termination part (200) with a termination hub (201a). The termination part is configured to land on the porch part. The tie-in system further has an alignment system to align the porch hub (101a) and the termination hub (201a) during movement of the termination hub towards the porch hub in a landed state. The alignment system comprises guide arrangements (A1, A2, B1, B2) having porch guide faces (113p, 113q, 113r) on the porch part and termination guide faces (213p, 213q, 213r) on the termination part. The porch guide faces and termination guide faces are configured to slide against each other during said movement. The porch part (100) comprises a base plate (103) on which the porch guide faces are arranged.

A slip lock connector system with a slip lock connector that couples a first annular body to a second annular body. The slip lock connector includes a first tapered surface and a second tapered surface. The first tapered surface and the second tapered surface slide over each other to drive the first and second tapered surfaces in radially opposite directions. The movement of the first and second tapered surfaces in radially opposite directions couples the slip lock connector to the second annular body.

A system disclosed herein comprises a pipeline and a plurality of access node structures axially spaced apart from one another along the pipeline, wherein each of the plurality of access node structures comprises a substantially planar upper surface. Also disclosed is a method for deploying a pipeline that comprises a plurality of future access node structures, wherein, at the time the pipeline is deployed subsea, the future access node structures prevent access to an interior of the pipeline, and wherein the plurality of access node structures comprises at least one of a tapping structure, a pressure-barrier retaining structure that is adapted to receive a pressure-barrier device and a pressure-barrier retaining structure comprised of a recess with a scored pressure-retaining bottom.

This invention relates to oil and gas exploration and comprises a direct connection system referred to as a Lower Riser Termination Assembly (LRTA), between risers made of composite material and horizontal lines installed on the seabed (flowlines). The system is applicable to a hybrid riser and its construction method allows cost reduction and system assembly/installation time optimization. The LRTA connection system is applicable to both rigid and flexible flowlines without need for any intermediate connection section/equipment between these and the risers.

Another important feature of the presented system is the fact that its construction allows free vertical expansion of the risers along the entire structure.

In addition, while, in the state of the art, the conventional methods require a large assembly and construction area, in the construction method developed for this system, the required area is significantly reduced, approximately 10 times smaller than that required for known construction methods.

In one illustrative embodiment, the manifold comprises a block with at least one drilled header hole formed within the block, a plurality of drilled flow inlet holes formed within the block, wherein the number of drilled flow inlet holes corresponds to the number of the plurality of external flow lines that supply fluid (e.g., oil/gas) to the manifold and a plurality of isolation valves coupled to the block wherein the valve element for each of the isolation valves is positioned within the block.

A mass balance is determined for periodic final inlet component flow rates entering Gas Oil Separation Plants (GOSPs). For transfers between GOSPs, constraints are calculated based on capacities of pipelines and a single direction of transfer. Calculated final inlet component flow rates are maintained for each GOSP within the calculated maximum and minimum GOSP pipeline capacities. Raw materials and intermediate and final states are formulated. Consumed power is calculated in in linear form using known flow rates per equipment. Investment decisions are performed with respect to swing pipelines and new equipment and a final net present value (NPV) is calculated with an overall objective function.