MX2013003989A

MX2013003989A - Marine subsea assemblies.

Info

Publication number: MX2013003989A
Application number: MX2013003989A
Authority: MX
Inventors: Roy Shilling; Kevin Kennelley; Robert W Franklin; Vicki Corso; Adam L Ballard; Ricky Thethi; Chau Nguyen; Steve Hatton
Original assignee: Bp Corp North America Inc
Priority date: 2010-10-12
Filing date: 2011-10-11
Publication date: 2013-10-08
Also published as: EP2627859A2; AU2011316731B2; WO2012051148A3; CN103228865A; CA2811110A1; EA026518B1; EA201300439A1; AU2011316731A1; WO2012051148A2

Abstract

A lower riser assembly connects a riser to a seabed mooring and to a subsea hydrocarbon fluid source. The assembly includes sufficient intake ports to accommodate flow of hydrocarbons from the hydrocarbon fluid source, as well as optional flow assurance fluid. The upper end of the member has a profile suitable for fluidly connecting to the riser. The lower end of the member includes a connector suitable for connecting to the seabed mooring. An upper riser assembly connects the riser to a near-surface subsea buoyancy device and to a surface structure. The assembly includes sufficient outtake ports to accommodate flow of hydrocarbons from the riser through a subsea flexible conduit to the surface structure. The upper end of the member includes a connector for connecting to a subsea buoyancy device. The lower end of the member comprises a profile suitable for fluidly connecting to the riser.

Description

MARINE SUBMARINE ASSEMBLIES INFORMATION FROM THE BACKGROUND Technical Field The present invention relates in general to assemblies useful in the exploration, production, drilling of wells, completion of wells, intervention of wells and the containment and evacuation of marine hydrocarbons. More specifically, the present invention relates to upper and lower vertical pipe assemblies useful with vertical pipes in the uses listed above.

Previous art Independent vertical piping systems (FSR) have been used during production and termination operations. For a review, see Hatton et al, Recent Developments in Independent Vertical Pipe Technology, Third Workshop on Subsea Conduits, 3-4 December 2002, Rio de Janeiro, Brazil. For other examples of FSR systems, see US Published Patent Applications Nos. 20070044972 and 20080223583, as well as US Patents No. 4,234,047; 4,646,840; 4,762,180; 6,082,391, 6,321,844, and 7,434,624.

The 2RD Recommended Practice of the American Petroleum Institute, (API-RP-2RD, First Edition, June 1998), Piping Design. Verticals for Floating Production Systems (FPS) and Tension Support Platforms (TLP) is a standard known to those · who practice in the oil and gas production industry.

Szucs et al, Oil and Gas Lift Using COR, SPE 97749 (2005) reveals a vertical pipe assembly (LRA) in an independent vertical pipe.

The retaining connectors have been characterized as "internal" and "external" retainer connectors and each of them has been patented. Patents on internal retainer connectors are US Patent Nos. 6,260,624; 5,299,642; 5,222,560; 5,259,459; 4,893,842; 4,976,458; 7,735,562; 5,279,369; and 5,775,427; and US Published Patent Application No. 20090277645. Patents on external retainer connectors are US Patent Nos. 4,606,557; 6,234,252; 6,540,024; 6,070,669; 6,293,343; 7,503,391; 7,337,848; 5.330.201; 5,255,743; 7,240,735. Drill adapters and their connection to wellheads (casing mouth or pipe mouths) are described in US Published Patent Application No. 20090032265. Adjustable supports are described in US Patent Nos. 6,065. 542; 6,557,644; and 7,219,738.

Due to the complexities of any given reservoir, the design of wells and the vertical pipe system, although certain minimum standards such as those presented in the API vertical pipe standard cited above may be known to those skilled in the art, each Oil or gas well can be a unique accomplishment towards itself (see for example US Pat. No. 6,747,569). Vertical pipe systems that work for a reservoir / well / environment may not be suitable for use with other wells, even those wells located next to them.

In the context of containment and evacuation, subsea vertical pipelines (independent or not) have been known as suitable for such use. Specifically, until recently the industry has not had to intervene with respect to submarine leaks at any significant depth, such as depths at 1500 meters, or more. Specifically, the previous containment efforts do not face the properties of the fluid produced by the combination of hydrocarbons with seawater at pressures and temperatures of deep waters that contribute to the formation of gas hydrates.

As a result, there remains an unfulfilled need for more vigorous upper and lower vertical pipe assembly designs, specifically when securing the flow is a concern, both during normal production operations and during containment and disposal periods.

Extract of the invention According to the present invention, submarine marine assemblies are described, and the methods for manufacturing, installing and using them, which reduce or overcome many of the faults of previously known marine underwater assemblies.

A first aspect of the invention is a assembly for connecting a vertical submarine pipeline to a sea floor mooring and to a source of submarine hydrocarbon fluid, comprising: a generally cylindrical member having a longitudinal perforation, a lower end, an upper end and a generally cylindrical external surface, the member comprises sufficient entry doors extending from the outer surface to the bore to accommodate the flow of hydrocarbons from the source of hydrocarbon fluids as well as the inflow of a functional fluid (flow assurance fluid or other fluid, for example a corrosion or scale inhibitor, a fluid of death and the like), at least one of the gates of Inlet is connected fluidly to a production wing valve assembly, the upper end of the member comprises a profile suitable for fluid connection to a vertical subsea pipeline; Y the lower end of the member comprises a connector suitable for connection to a mooring of the seabed.

In certain embodiments, the generally cylindrical member comprises modified by connecting a transition connection thereto, the upper end of the submarine wellhead cabinet fluidly connected to an external retainer connector fluidly connected to the wellhead cabinet Submarine to vertical pipe stress connection.

In certain embodiments, the submarine well mouth cabinet comprises an internal seal profile adapted to seal with an internal retainer connector, the internal detent connector fluidly connects an inner, underwater vertical tubing to the inner seal profile of the mouth of the submarine well. In certain embodiments, the internal retainer connector comprises a nose seal that seals within the submarine wellhead profile of the subsea wellhead, the nose seal provides the integrity of pressure between an internal flow path in the vertical pipeline interior and a ring between the inner vertical pipe and a substantially concentric outer vertical pipe. In certain embodiments, the internal retainer connector is attached to both the submarine wellbore enclosure and a vertical pipe stress connection, creating a pre-charged structural connection between the underwater wellhead enclosure and the internal retainer connectors. and external. In certain embodiments, the fasteners comprise detents.

Certain embodiments comprise an external connector that secures the internal retainer connector to the cabinet of the submarine wellhead.

In yet other assemblies, the ear valve assembly is fluidly connected to an underwater source through one or more flexible subsea conduits.

In still other assemblies, the vertical pipe stress connection is in turn fluidly connected to an exterior vertical pipe.

In still other assemblies, the transition connection ends with a first eyebolt end forging that serves as an anchor point for an independent vertical pipe.

Still other assemblies comprise valves operated by ROV to control the flow through an internal flow path within the inner vertical pipe and through a ring between the inner vertical pipe and the pipe, substantially concentric outer vertical.

Still other assemblies comprise one or more pressure and / or temperature monitors.

Still other assemblies comprise one or more servomechanism doors for the intervention and / or maintenance of ROV.

In other determined embodiments, the generally cylindrical member comprises a high strength metal forge. These embodiments may comprise two entrance doors connected to the respective wing valve assemblies and a third door including a sub-bay suitable for connecting a functional fluid source, for example, a flow assurance fluid or other fluid. The sub-gallery may include one or more valves operable by ROV.

Certain embodiments comprise two or more entrance doors connected to respective fin valve assemblies and furthermore comprise double clamp supports for holding respective double sub-manifold connectors, each is fluidly connected to the high strength steel member forged through respective blocking elbows, wherein each assembly of production wing valves includes at least one valve operable by ROV.

In certain embodiments, the generally cylindrical member comprises a third door suitable for connection of a ring ventilation sub-gallery, the ring ventilation sub-gallery connects to the third door of the forged high strength steel member through a third elbow of blocking, the ring ventilation sub-bay provides a fluid connection to a source of a functional fluid such as a flow assurance fluid or other fluid. In some embodiments, the ring ventilation sub-gallery comprises one or more valves operable by ROV.

In certain embodiments, each wing valve mounting connector that connects the wing valve assembly to the metal forge, at least one operable valve, by ROV is connected to the locking elbow and an underwater connector for connection to a conduit The flexible underwater, the blocking elbow, the ROV operable valve and the submarine connector are all connected in a fluid way by central perforations that allow the fluid communication from the submarine flexible conduit to the longitudinal perforation of the metal forge.

Certain embodiments comprise a retainer ring having an external threaded portion that engages threads on an inner surface of the metal forge, and an internal threaded portion for engagement with threads of a chain of internal casing tubing.

In other embodiments, the forged high-strength steel member further comprises an internal surface, at least a part of it being threaded, to mesh threadedly to the coupling threads of a retaining ring, the retaining ring includes at least less a group of internal threads that are coupled with a set of threads on the inner riser pipe and that also includes a seal element composed of Inconel or other corrosion resistant metal.

Certain embodiments comprise a servomechanism assembly for the injection of a functional fluid, the servomechanism assembly allows a flow velocity smaller than that which is possible through the ring ventilation sub-gallery.

In other embodiments, the generally cylindrical member comprises a forged, high-strength steel inlet spool fluidly connected to a gooseneck assembly fluidly connected to the lower flexible conduit, the inlet spool also comprising a connector that allows the connection to a source of a functional fluid. In the embodiments, the gooseneck assembly comprises an underwater API flange connected in series to a pipe reel, a high pressure subsea connector, another underwater API flange and a bend restrictor.

In other embodiments, the input spool comprises an internal surface adapted to accept and fluidly connect with an internal detent connector positioned on the inner surface of the input spool; The inlet spool further comprises a clamping mechanism that allows the retainer connector to be releasably connected to the reel of inlets, while an O-ring seal provides a watertight seal between an external surface of the retention connector and the inner surface. of the entrance reel.

Another aspect of this embodiment comprises an assembly suitable for use as a vcal underwater pipe assembly comprising: a submarine well mouth cabinet having a lower end and an upper end, the modified lower end mechanically and fluidly connecting a transition connection to it, the transition connection is in turn fluidly and mechanically connected to a lower forge, the lower forge comprises entrance doors sufficient to accommodate the flow of production or containment fluids and a flow assurance fluid, at least one of the doors is connected to a source of a flow assurance fluid , at least one additional entrance door is fluidly connected to a production flange valve assembly, the upper end of the submarine well mouth enclosure is fluidly connected to an external retainer connector that connects fluid to the cabinet of the submarine well mouth to a vcal pipe stress connection, the submarine well mouth cabinet comprises an internal seal profile adapted to the seal with an external retainer connector, the internal retainer connector fluidly connects a vcal underwater pipe to the internal seal profile of the submarine wellhead, wherein the internal retainer connector comprises a nose seal that is sealed within the profile of the submarine wellhead of the submarine wellhead, the nose seal provides the integrity of pressure between an internal flow path in the vcal pipeline interior and a ring between the inner vcal pipe and an external vcal pipe substantially concentric and where the internal retainer connector is attached to both the submarine wellbore enclosure and a vcal pipe stress connection, creating a pre-charged structural connection between the underwater wellhead enclosure and the internal and external retainer connectors .

Another aspect of this invention comprises a mounting suitable for use as a subsea vcal lower pipe assembly comprising: a generally cylindrical high-strength metal forge comprising a longitudinal bore, a lower end, an upper end, a generally cylindrical external surface and sufficient entry ports to accommodate the flow of production or containment fluids, at least one of the doors is connected to a source of a flow assurance fluid, at least one additional entrance port fluidly connected to a production wing valve assembly, the upper end of the metal forge comprises a profile suitable for connect fluidly to an external vcal pipe, the lower end of the metal forge comprises a connector suitable for connection to an underwater mooring, a third door suitable for connecting a ring ventilation sub-gallery, the ring ventilation sub-gallery comprises one or more valves operable by remote operated vehicles (ROVs) and a retaining ring having an external threaded part coupled with threads on a internal surface of the metal forge and an internal threaded part for the coupling with threads of a chain of inner casing pipe.

Another aspect of the present invention comprises an assembly suitable for use as an assembly of subsea under vcal pipes comprising: a generally cylindrical, high strength, forged steel reel connected fluidly to a gooseneck mount, the gooseneck assembly is fluidly connected to a lower flexible conduit, the inlet spool also comprises a connector that allows connection to a source of a functional fluid; the gooseneck assembly comprises an underwater API flange connected in series to a pipe reel, a high-pressure subsea connector, another underwater API flange and a bend restrictor, and wherein the input spool comprises an internal surface adapted to accept and fluidly connect with an internal detent connector positioned on the inner surface of the input spool, the input spool further comprises a clamping mechanism which allows the connector of internal retainer is attached in removable form to the inlet spool, while I ' an O-ring seal provides an airtight seal between an external surface of the internal retainer connector and the inner surface of the inlet spool.

Another aspect of the invention is a mounting for connecting a submarine vertical pipe to a submarine support device and to a surface structure, which comprises: a generally cylindrical member having a longitudinal bore, a lower end and an upper end and a generally cylindrical external surface, the member comprises sufficient entry doors extending from the bore to the generally cylindrical external surface to accommodate the flow of hydrocarbons from the vertical pipe and at least one door that allows the flow of a functional fluid inside the longitudinal perforation, at least one of the suitable doors is connected in fluid form to a production valve assembly to connect in fluid form the member to the surface structure with a submarine flexible conduit, the upper end of the member comprising a connector suitable for connecting to a submarine support device and the lower end of the member comprises a profile suitable to connect fluidly to the vertical pipe.

In certain embodiments the generally cylindrical member comprises a drill spool adapter having a first end fluidly connected to a pipe mouth, the pipe mouth comprises one or more outlet doors, the pipe mouth is connected to a Liner pipe mouth having a rod connection attached (eg, welded) to it, the liner mouth comprises one or more doors to admit a functional fluid and one or more assemblies of production wing valves connected in fluid form to respective exit doors.

In certain embodiments of this aspect, the rod connection is fluidly connected to an outer concentric vertical pipe.

In certain embodiments, at least one of the production wing valve assemblies is fluidly connected to an exit port to a collection vessel through a flexible conduit.

In certain embodiments, the assembly comprises an adjustable pipe support that fluidly connects an inner vertical pipe to the pipe mouth.

In still other embodiments of this aspect, the assembly of production wing valves comprises first and second flow control valves to control the flow in the bore of the inner vertical pipe and in a ring between the inner vertical pipe and the vertical pipe. Exterior.

In still other embodiments, the assembly of production wing valves comprises at least one emergency shut-off valve (ESD) selected from the group consisting of an ESD operated in hydraulic form, an ESD operated in electrical form, and an ESD operated in hydraulic form and an ESD operated in electrical form.

In still other embodiments the production wing valve assembly comprises one or more ROV servomechanism doors that allow a functional fluid to flow into an inner vertical pipe and a ring between the inner vertical pipe and an outer vertical pipe. In certain embodiments, the functional fluid is a flow assurance fluid selected from the group consisting of nitrogen or other gaseous phase, heated seawater or other water, and organic chemical compounds. In certain embodiments, the flow assurance fluid essentially comprises nitrogen.

In certain embodiments, the reel spool adapter is connected to a shackle flange adapter bracket capped on its top with an eyebolt end worm that serves as a mounting junction point to the underwater lift assembly near the surface.

In other embodiments of this aspect of the present invention, the generally cylindrical member comprises a take-up spool having the upper end and the lower end, an eye bolt flange connected to the upper end of the take-point spool and a spool of support connected to the lower end of the take-point reel, wherein the take-point reel and the support reel define the longitudinal perforation.

In certain embodiments, the take-up spool comprises a second bore substantially perpendicular to the longitudinal bore and fluidly connecting the longitudinal bore to one of the production wing valve assemblies through one of the outlet doors.

In certain embodiments, the assembly of production wing valves comprises a gooseneck conduit and two emergency shutoff valves (ESD) connected in fluid form in line to the swan neck conduit, one of the ESD is hydraulically operated , and the second ESD is connected in electronic form.

In certain embodiments, the support spool comprises a third bore substantially perpendicular to the longitudinal bore and fluidly connecting a ring defined by the support spool and an internal vertical pipe connection with a ring access valve assembly. The assembly of ring access valves may comprise one or more valves operable by ROV. The assembly of ring access valves can be connected fluidly to a source of the functional fluid.

Certain embodiments comprise a vertical pipe lock assembly that retains the internal vertical connection connection within the take-point spool. The vertical pipe lock assembly may comprise a vertical pipe lock ring may comprise a lock ring and a wedge with T seals.

In certain embodiments, a double-ring seal arrangement and cable retainer is positioned on an inner surface of the take-point reel to provide a double fluid seal between the ring and the longitudinal bore. In certain embodiments, the URA comprises a production take-off point reel connected fluidly and mechanically to a substantially vertical conduit and to a production line, the production line which in turn is fluidly connected to a restrictor. of bending through an underwater API tab, a high-pressure submarine connector, another underwater API tab connection and optionally a QDC submarine connector. The bending restrictor is mechanically connected to the upper submarine flexible conduit that extends in a catenary loop to the collection surface vessel and the substantially vertical conduit is fluidly connected in series to an adapter which in turn is fluidly connected to a support reel and to an API flange, a casing mouth through an API flange, a rod connection welded to the casing mouth and to the exterior vertical pipe through a threaded connection a rod connection, the take-off reel includes a shackle flange that allows connection to the underwater lift device.

In certain embodiments the URA further comprises an ROV operable ESD fluidly connected to a section of the conduit.

In certain embodiments, the URA further comprises a support clamp that holds the production pipe at an angle s with the conduit, and that also supports a bending shield that provides a mechanical barrier between the production pipe and the conduit, where the angle s is in the range of 0 to 180 degrees.

In certain embodiments the URA further comprises a connection to the support reel for connecting a gooseneck for supplying hot water to the support reel from a surface vessel.

In certain embodiments the swan neck comprises, for initiating on the support reel, an API flange, a pipe section, a high pressure subsea connector, a submarine API connector and an API flange and a bend restrictor.

In certain embodiments, the inner vertical pipe is positioned inside the adapter, the support spool and the jacket pipe mouth, creating the ring between an inner surface of the support spool and the inner vertical pipe.

In certain embodiments, the URA comprises a pair of O-seals that seal the inner vertical pipe within the adapter and one or more wedges that are wedged between an inclined surface of the supporting spool and the inner vertical pipe, firmly securing the inner vertical pipe. inside the support reel.

In some embodiments, the URA further comprises components that allow the circulation of a functional fluid, such as hot water, through the ring.

In other embodiments, the URA also comprises a take-up spool connected in fluid form to a support spool, the support spool in turn can be fluidly connected to a tapered support stress connection of the vertical pipe.

In still other embodiments, the URA further comprises a shackle and a chain rope that allows the URA to be mechanically connected to a support device near the surface.

Other determined embodiments comprise a first block elbow that includes an inner bore that intersects and is substantially perpendicular to a bore within the take-point spool, a second block elbow having an inner bore that is also substantially perpendicular to the bore surface. Take-off reel that does not intersect with the take-off reel borehole and a gooseneck conduit fluidly connected to the first block elbow that provides a flow path for hydrocarbons in combination with the first borehole block elbow. In some cases, the URA comprises first and second emergency closing valves in the swan neck conduit, the gooseneck conduit is fluidly connected to an underwater connector which in turn is fluidly connected to the flexible underwater conduit.

In other embodiments, the assembly further comprises a purge valve in the swan neck conduit that allows the URA to be closed, the contents of the swan neck duct to be flushed and the subsea flexible duct recovered.

In some embodiments, the components that allow the circulation of a functional fluid through the ring comprise a submarine connector, a conduit and one or more valves within the conduit, the conduit is fluidly connected to the support spool.

Yet another aspect of the present invention is a fitting suitable for use as a vertical pipe assembly, comprising: a drill spool adapter having a first end fluidly connected to a pipe mouth, the pipe mouth comprises one or more outlet doors, the pipe mouth is connected to a pipe mouth d coating having a the connection of a rod attached to it, the mouth of the casing also includes one or more doors for the entry of a flow assurance fluid, the rod connection is connected fluidly to an outer concentric vertical pipe, an adjustable pipe support for fluidly connecting an inner vertical pipe to the pipe mouth, forming a ring between the inner vertical pipe and the outer concentric vertical pipe, a production flange valve assembly fluidly connected to one of the respective outlet doors, the production flange valve assembly comprises first and second flow control valves to control the flow to the interior of the interior vertical pipe and the ring and a hydraulically operated emergency shut-off valve and an emergency shut-off valve operated electrically and the assembly of production wing valves comprises one or more ROV servomechanism doors that allow a flow assurance fluid to flow into the inner vertical pipe and / or the ring.

Yet another aspect of the present invention is a mounting suitable for use as an assembly of subsea top vertical pipes, comprising: a take-up spool having an upper end and a lower end, an eye bolt flange connected to the upper end and a support spool connected to the lower end, wherein the take-up spool and the supporting spool define a longitudinal perforation the take-off spool comprises a second bore substantially perpendicular to the longitudinal bore and fluidly connecting the longitudinal bore to a production wing valve assembly through an outlet port of the take-off spool, the assembly of production valves comprises a gooseneck conduit and two emergency shutoff valves (ESD) connected in fluid form in line to the gooseneck conduit, one of the ESD is hydraulically operated and the second ESD is act in electronic form, the support spool comprises a third bore substantially perpendicular to the longitudinal bore for fluidly connecting a ring defined by the support spool and an internal vertical pipe connection with a ring access valve assembly, the valve assembly of Ring access comprises one or more valves operable by vehicles operated by remote control, a vertical pipe lock assembly for interconnecting and retaining the internal vertical pipe connection within the take-point spool, the vertical pipe lock assembly comprises a lock ring with a wedge with T seals and a double ring seal arrangement and cable retainer on an inner surface of the take-point reel that provides a double fluid seal between the ring and the longitudinal bore.

Another aspect of the present invention is a suitable assembly for use as an assembly of submarine upper vertical pipes, comprising: A production take-off point reel connected fluidly and mechanically to a substantially vertical conduit and to a production line, the production line in turn is connected in fluid form to a bending restrictor through a flange of the Underwater API, a high-pressure underwater connector, another underwater API flange connection and optionally a QDC submarine connector, the bending restrictor is connected to the upper underwater flexible conduit that extends in a catenary loop to a surface structure, wherein the substantially vertical conduit is fluidly connected in series to an adapter which in turn fluidly connects to a support spool of an API flange, a coating pipe mouth through another API flange, a rod connection welded to the casing mouth and an exterior vertical pipe through a threaded connection within the rod connection, the take-up reel includes a shackle flange that allows connection to a support device submarine; an ESD operable by remotely operated vehicles connected fluidly within a section of the conduit; a support clamp that holds the production tubing at an angle s with the conduit, and also supports a bending shield that provides a mechanical barrier between the production tubing and the conduit, where the angle s is in the range of 0 to 180 degrees; a connection to the support reel for connecting a gooseneck for supplying hot water to the support reel from a surface vessel, wherein the gooseneck comprises, in order starting from the support reel, an API flange, a pipe section, a high-pressure submarine connector, a submarine API connector and an API tab and a bend restrictor; wherein the inner vertical pipe is positioned inside the adapter, the support spool, and the mouth of the casing, creating the ring between an inner surface of the support spool and the inner vertical pipe; Y a pair of 0-ring seals that seal the inner vertical pipe inside the adapter, and one or more wedges that form a wedge between an inner inclined surface of the supporting spool and the inner vertical pipe, firmly securing the vertical pipe within the spool of support.

In certain embodiments, each of the subsea flexible conduits comprises a flexible discharge wave closure wire with distributed support modules connected to the submarine flexible conduit in a random or non-random manner from a point of connection of the submarine flexible conduit to the base. From the independent vertical pipe to a submarine multiple pipe on the sea floor, the manifold pipe is connected in fluid form to the source or underwater sources.

In certain embodiments, which include an internal retainer connector that fluidly connects the inner vertical pipe to the LRA, the internal retainer connector comprises a nose seal, in some embodiments the nose seal is an Inconel nose seal, which seal inside a submarine wellhead profile of the submarine wellhead, the connector also seals with both the submarine wellhead and the stress connection to create a pre-loaded structural connection between the underwater wellhead and the internal and external retainer connectors. Certain embodiments also comprise an additional external connector latch that secures the internal retainer connector to the submarine wellhead. The nose seal provides pressure integrity between the internal flow path inside the inner vertical pipe and the ring between the inner and outer vertical pipes.

Certain embodiments include those in which the assembly of URA production wing valves comprises emergency shutoff valves operated both hydraulically and manually.

Certain embodiments include those in which the URA production wing valve assembly comprises one or more submarine ship servomechanism doors that allow a functional fluid to be injected into the inner or annular vertical pipe or both. Examples of suitable functional fluids include flow assurance fluids such as a gas atmosphere, heated sea water or other water, or organic chemicals such as methanol and the like. The gas atmosphere can be selected from nitrogen of different degrees of purity, such as nitrogen enriched air, a noble gas such as argon, xenon and the like, carbon dioxide and combinations thereof; hot sea water or other water pumped into the ring and out of the ventilation subgame of the ring, and methanol pumped into the ring and out of the ventilation sub-gallery. Certain hydrate inhibition fluids include liquid chemical compounds selected from the group consisting of alcohols and glycols. The flow assurance fluid may consist essentially of nitrogen, which means that the gas atmosphere comprises nitrogen and may include impurities which do not contribute to the formation, or which themselves form hydrates, and which exclude substantially impurities which do form or they contribute to form hydrates.

Certain embodiments comprise the external wet insulation adjacent to at least a major portion of the outer surface of one or more of the well's mouths, finned valves, lining pipe nozzles, pipe nozzles, metal forges, knit spools of shot, support reels, and the like. In certain embodiments the wet insulation comprises a polymeric material. The polymeric material may comprise a plurality of layers of polypropylene.

Certain embodiments of the URA and the LRA include sub-galleries to allow a functional fluid, such as a flow assurance fluid, to flow within an inner vertical pipe and / or ring spaces between the vertical pipes and within the URA's bores and of the LRA. Certain embodiments include sub-galleries that allow the flow of the inhibitor fluid, hydrates within these spaces. Certain embodiments include sub-galleries to allow the flow of hydrate remediation fluid within these spaces. Certain embodiments include sub-galleries to allow the flow of fluids for all these uses. Once it is introduced into the vertical pipe and / or the annular space, the flow assurance fluid, the hydrate inhibition fluid, and / or the hydrate remediation fluid may be stagnant or running, although the transfer of mass and heat favors a flowing fluid.

Certain embodiments include those in which at least some of the components of the LRA and / or the URA comprise high strength steel, although the use of steel is not required, and other metals may be used. As used herein, the term "high strength steel" includes steels such as P-110, C-110, Q-125 and C-125 and titanium steels.

The assemblies described herein can be used with simple or concentric pipe systems. The assemblies described herein may be used with developments of wet trees, including those that employ an FPSO or other floating production systems (FPS), including, but not limited to, semi-submersible platforms. The assemblies described herein may also be used with developments of dry trees, including those that employ towers, compatible, TLP, poles or other FPS. The assemblies described herein may also be used with so-called hybrid developments (such as TLP or pole with an FPSO or FPS). The assemblies described herein may be used with vertical pipes tensioned by air can systems, hydropneumatic tensioners, or combinations thereof.

These and other features of the systems, apparatuses and methods of the invention will become more apparent upon review of the brief description of the drawings, the detailed description and the following claims.

Brief Description of the Drawings The manner in which the objects of this invention and other desirable characteristics can be achieved is explained in the following description and in the accompanying drawings, wherein: Figures 1, 1A, and IB illustrate in schematic form, Figure 1A in detailed cross-section, an embodiment of a vertical pipe system in which the assemblies of the present invention may be useful.

Figures 2A and 2B are schematic side elevational and cross-sectional views, respectively, of a general embodiment of a lower vertical pipe assembly in accordance with the present invention.

Figures 3A-3G include different views, some of cross-section, of another embodiment of a lower vertical pipe assembly according to the present invention.

Figure 4A is a perspective view, Figure 4B is a cross-sectional view and Figure 4C is a more detailed cross-sectional view of a part of the lower vertical pipeline embodiment of Figure 3.

Figures 5A and B illustrate schematic perspective views of another lower vertical pipe assembly according to the present invention, and Figure 5C is a schematic perspective view of an internal component that is useful with the lower vertical pipe assembly illustrated in FIG. Figures 5A and 5B; Figures 5D and 5E are cross sectional views and Figure FIG. 5G is a plan view of the assembly of lower vertical pipes that are illustrated in Figures 5A and 5B; and Figure 5F is a detailed schematic view of a portion of the lower vertical pipe assembly that is illustrated in Figure 5E.

Figure 6 is a schematic side elevation view with cut-away portions of a general embodiment of a top vertical pipe assembly according to the present invention.

Figures 6A-6G include different views, some of cross-section, of another embodiment of an upper vertical pipe assembly according to the present invention.

Figure 6H is a schematic perspective view and the Figures 61 and 6J are cross-sectional views of a part of the embodiment of the upper vertical pipe assembly of Figure 6; Figure 6K is a perspective view of a seal test door.

Figures 7A and 7B are schematic perspective views of another embodiment of the upper vertical pipe assembly according to the present invention.

Figures 7C-7D are cross-sectional views of the embodiment of Figure 7 and Figure 7E is a detailed cross-sectional view of a part of that embodiment.

Figures 8A and 8B are schematic side elevation and cross sectional illustrations, respectively, of another embodiment of the LRA and Figures 8C and 8D are illustrations in lateral elevation and cross section, respectively, of another embodiment of the LRA according to the present invention.

However, it should be noted that the attached drawings are not in scale and illustrate only typical embodiments of the present invention, and consequently should not be considered as limiting, since the invention can admit other equally effective embodiments. Identical reference numbers are used in all views for the same or similar elements.

Detailed description of the invention In the following description, numerous details are set forth to provide an understanding of the disclosed methods, systems and apparatus. However, those skilled in the art will understand that methods, systems and apparatuses can be practiced without these details and that numerous variations or modifications with respect to the embodiments described may be possible. All published US patent applications and all US Patents cited in the present, as well as all published US patent applications and all literature that are not published patents are explicitly incorporated herein by reference herein. In the event that the definitions of terms of the cited patents and patent applications conflict with the manner in which those terms are defined in the present patent application, it will be deemed to govern the definitions for those terms that are provided in the present patent application.

The main features of the different embodiments of the present invention are now described with reference to the following figures. Equal reference numbers are used throughout the text to indicate the same elements in the figures, unless otherwise indicated.

As previously indicated, subsea maritime assemblies and methods of fabricating, installing and using them are described that can reduce or overcome many of the faults of previously known marine underwater assemblies. ' As used in this, the term "surface structure" means a surface vessel or other structure that can operate to receive one or more fluids from one or more independent vertical pipes. In certain embodiments, the surface structure may also include facilities to allow the surface structure to perform one or more functions selected from the group consisting of storage, processing and discharge of one or more fluids. As used herein, the term "discharge" includes, but is not limited to, the burning (burning) of gaseous hydrocarbons. Suitable surface structures include, but are not limited to, one or more vessels; structures that can be partially submerged, such as semi-submersible structures; floating production and storage structures (FPS); floating storage and unloading structures (FSO); floating production, storage and discharge structures (FPSO); mobile marine drilling structures such as those called mobile marine drilling units (MODU); poles; Tensioned leg platforms (TLP) and the like.

As used herein, the phrase "underwater source" includes, but is not limited to: 1) production sources such as underwater wells, submarine blowout warnings (BOP), other subsea vertical pipelines, multiple subsea pipes, pipelines and subsea pipelines, subsea storage facilities and the like, whether they produce, transport and / or store gas, liquids, or combinations thereof, including organic as well as inorganic materials; 2) underwater containment sources of all types, including BOP, vertical pipelines, multiple tubes, leaking or damaged underwater tanks, and the like; and 3) natural sources. Certain embodiments of systems include those in which the source of containment is a submarine blowout preventer that does not work.

The term "wellhead" is known in the art of drilling and producing hydrocarbons as a structure having a central bore and end connectors at both ends of a varied character, such as shafts, mandrels, ratchets and the like and that they meet API standards for strength and other parameters for wells, as detailed in the API 6A specification. As used herein, the terms "pipe mouth" and "pipe mouth" are wellholes having relative strength ratings, such that a pipe mouth is generally stronger than a pipe mouth. of coating, although this is not always the case. An underwater wellhead can be a pipe mouth or a casing mouth, but it is usually a casing mouth or an even more robust construction due to the conditions found at the bottom of the sea.

The terms "flow assurance" and "flow assurance fluid" include the assurance of the flow in light of the hydrates, waxes, asphaltenes and / or incrustations that are already present, and / or the prevention of their formation and are considered broader than the term "hydrate inhibition", which is used exclusively herein for the prevention of hydrate formation. By the term "hydrate inhibition" it is meant to remove or reduce the amount of hydrates that have already been formed in a given ship, conduit or other equipment. The term "functional fluid" includes flow assurance fluids, as well as fluids that can fulfill additional functions or separately, for example, corrosion resistance, adjustment of the concentration of hydrogen ions (pH), adjustment of pressure, density adjustment and the like, such as death fluids.

As used herein, the term "substantially vertical" is understood to have an angle with the vertical line that is in the range of 0 to 45 degrees, or 0 to 20 degrees, or 0 to 5 degrees. As such the term "substantially vertical" includes and is broader than the term "almost vertical", as the term is used in the description of the angle that can form a vertical pipe with the vertical line.

Figures 1, 1A, and IB schematically illustrate (Figure 1A in detailed cross-section) one of the embodiments of a subsea vertical piping system in which the assemblies described in the present may be useful. It will be recognized that also other different vertical subsea piping systems can benefit from the use of the assemblies described herein. An independent pipe (FSR) 2 is illustrated at an angle a with respect to the vertical line. The angle a can be in the range of 0 to 90 degrees, or from 0 to 45 degrees, or from 0 to 20 degrees (which is considered "almost vertical"). Another angle, ß, is defined as the angle between the vertical line and a line tangent to the flexible conduit 12 near the water surface 20. The angle ß can be in the range of 0 to 90 degrees, or from 0 to 45 degrees, or from 0 to 20 degrees. A third angle?, Defined as the angle between a string or other string 58 (which may or may not be vertical) and an end section of a flexible conduit 14 near the base of the FSR, may be in the range of 5 to 60 degrees, or 5 to 30 degrees. A pile 16 is shown submerged in the bottom of the sea 10, and a chain rope 58 connects the pile 16 to the lower vertical pipe assembly 8 as also described herein. The subsea conduit 14 fluidly connects the lower vertical pipe assembly 8 to a hydrocarbon source, in this case a submarine manifold 26. An upper vertical pipe assembly 6 fluidly connects a vertical pipe 2 with a flexible submarine conduit 12, which in turn fluidly connects to a surface vessel 32. The upper vertical pipe assembly 6 is also connected to the main and secondary air canisters 18 and 19 in this embodiment.

Figure 1A illustrates the relative locations of an interior vertical pipe 60, a concentric exterior vertical pipe 70, an exterior surface 62 of the interior vertical pipe 60, an exterior surface 72 of the exterior vertical pipe 70, an interior surface 74 of the pipe vertical exterior 70, a ring 76 and a flow path 64 inside the interior vertical pipe 60. The solid insulation 80 is positioned adjacent to at least a major portion of the exterior surface 72 of the exterior vertical pipe 70 and in certain embodiments , this solid insulation is adjacent to the complete outer surface 72 of the exterior vertical pipe 70. Vertical pipes heated in electric form may be an option in certain embodiments, although for operational reasons associated with emergency quick disconnect (QDC) situations or hurricane evacuation, this option may not be attractive. Electrical heating can greatly complicate the QDC design.

The circulation of the water in the ring 76 or other flow assurance fluid described herein, and the isolation over the multiple subsea tubes, the flow lines (which include the flexible undersea conduits 12 and 14 and the flexible closing wires and the swan necks mentioned herein) and the connectors, in addition to the independent vertical pipe, may be included in many embodiments. The "circulation" can be continuous or discontinuous. In certain embodiments, the flow assurance fluid may be stagnant after filling the ring. The ability to pump or otherwise inject one or more flow assurance fluids into one or more servomechanism receptacles of remotely operated vehicles is another option, as is the ability to pump or inject otherwise. nitrogen or other gaseous phase within the bottom of the inner vertical pipe or within a subsea manifold within the flexible subsea conduits as a way to obtain the flow assurance fluid beneath an actual or potential, full or partial hydrate plug . In certain embodiments, such as that illustrated in the figures, the flow assurance fluid may be pumped or otherwise injected into a variety of places, for example, non-exhaustively, the bottom of the interior vertical pipe 60, at the bottom of the ring 76, inside the flexible bottom conduit (submarine) 14, at the top of the inner vertical pipe 60 and the ring 76 and inside the upper flexible conduit 12.

Figure IB also schematically illustrates a voltage monitoring system 52 over the FSR 2. The location of the voltage monitoring system is usually near the top of the FSR 2, although the location can be anywhere along the FSR 2 and may comprise a plurality of said monitoring systems separated in a random or non-random manner along the FSR 2. Figure IB schematically illustrates a detail of the voltage monitoring system illustrating a connector 54 and the voltage monitoring module 56.

Figures 2A and 2B are schematic side elevation and cross sectional views, respectively, of a general embodiment of a lower vertical pipe assembly (LRA) according to the present invention. The LRA 8 includes a generally cylindrical body CB, an upper end 8UE and a lower end 8LE and five connections Cl, C2, C3, C4, and C5 in this embodiment. The connection Cl is a mechanical and fluid connection of the cylindrical body CB to the vertical pipe 2. The connection C4 is a mechanical connection of the cylindrical body CB to a submarine mooring (not illustrated) through a chain or other functional rope 58. The connections C2, C3, and C5 are mechanical and fluid connections of the conduits 8A, 8B, and 8C to the cylindrical body CB through the doors 8P of the cylindrical body CB. The doors 8P extend from an inner surface 8IS to an outer surface 8ES of the cylindrical body CB.

The conduits 8A, 8B (and 8C) may be, for example, wing valve assemblies that connect to subsea hydrocarbon sources, connections to fluid sources, functional fluids such as flow assurance fluids, or connections to other subsea equipment or The connections C2, C3, and C5 between the doors 8P and the conduits 8A, 8B, and 8C can be threaded connections, flange connections, welded connections, other connections and can be the same or different with respect to the type of connection , the diameter and shape, according to the diameter and shape of the doors 8P, for example, the doors 8P may have a shape selected from the group consisting of groove, slit, oval, rectangular, triangular, circular, and the like. Cl connection may be a threaded, flanged, welded or other connection and may include one or more ratchets, workpiece clamps, split rings, or other elements.In certain embodiments, the LRA may The ability to connect to multiple tubes and other equipment, such as flexible conduits, within 270 degrees of approach radius.

Another embodiment of an LRA is illustrated in different views in Figures 3A-3G. Figure 3A is a front elevational view of the LRA 8, this embodiment comprising an external retainer connector 102 connected to an underwater manhole 104 (as also explained in relation to Figures 4A-C) and the connection of transition 105. Transition connection 105 is welded on its upper end in this embodiment to the bottom of the submarine well mouth 104 and to a bottom shape 106 that includes two milled flange connections 108A and B and an eye bolt. The milled flange connections 108A and B are substantially perpendicular to the common longitudinal axis to the manhole 104, to the transition point 105 and to the forge 106, and the milled flange connections 108A and B define the LRA entry doors. The forge and the bottom eye bolt are a single piece 106 in this embodiment and the transitional connection 105 is a separate piece that welds the bottom forge 106 to the wellhead 104. The transitional connection 105 includes an end forging. of eye bolt 106, which meshes a U-shaped connector 119 and the rope chain 58, which is derived in the suction pile assembly 16 (not illustrated).

The LRA 8 also comprises a RÓV 110 servomechanism panel for operating the external retention connector 102 when forming the connection to the submarine well 104. The external retention connector 102 may be a thin line or line retention connector. ultrathin such as that available from GE Oil and Gas, Houston, TX (formerly called Veteo); FMC Technologies, Inc., Houston, TX; and possibly other providers. One such retainer connector is described in U.S. Patent No. 7,537,057. Those skilled in the art will understand that external retainer connectors are manufactured with the understanding that when the design stress on the connector increases, the allowable bending moment is reduced in an inverse relationship. The specific curves for these capacity ratios are available from the manufacturers.

A flange 111 connects a bend restrictor 112 and subsea flexible conduit 14 to a high pressure submarine bending reinforcement 180, the latter having an internal profile 81 (see FIG. 3F) that allows the subsea flexible conduit 14 to be connected in fluid form to the gooseneck assembly of LRA 107. As schematically illustrated in Figure 3F, the bending reinforcement 180 has a flange connection 81 connecting the submarine flexible conduit 14 to a high pressure subsea connector 181, the latter is used to mechanically and fluidly connect the conduit 107B of the LRA 8. The bending reinforcement 180 can take the moment outside the flange connection 81 in such a way that it is transferred directly from the bending restrictor 112 to the submarine connector. high pressure 181, which leaves the upper end of the bending reinforcement 180. The containment or production fluids flow up through the underwater flexible conduit 14 and the flange connection 81 into an axle assembly 116B (two shaft assemblies 116A and B are indicated in this embodiment) and also through the valve assembly of the LRA production 114B (two production wing valve assemblies 114A and B are indicated in this embodiment, Figure 3A).

As illustrated in Figures 3A and 3F, each of the LRA production wing valve assemblies 114A and B comprises the respective locking elbows 109A and 109B, and manual gate valves operated by ROV 115A and B as well as the respective flow paths 115C and 115D (Figure 3F). The servomechanism panels of ROV 150A and B, respectively, can be provided for temperature and pressure monitoring. A submarine grapple structural support 118 provides support for submarine connectors 119A and 119B (such as those available from Vector Subsea, Inc. with the OPTIMA brand designation). An ROV 121 servomechanism panel with a mount is provided to shield the shaft assembly 116A, which can accommodate pressure and / or temperature monitoring sensors. Four rotating link hoist rings 123 are also provided on the structural support 118 in this embodiment.

Figure 3C is a detailed view schematically illustrating the hex bolts 94 welded at 93 to a clamp bolt retaining block 95. The block 95 is also welded at the locations 97 to the body of the submarine connector 119B. A similar arrangement is included on the submarine connector 119A, but is not illustrated.

Figure 3D is a side elevational view and Figure 3E is a plan view of the LRA 8. The swan neck 107 can rotate through a wide angle which may be necessary during the connection of the flexible conduit 14, as noted from the plan view, but once it is secured with the connector 119B this movement is restricted.

Figure 3F is a cross-sectional view taken along the dotted line of Figure 3E and illustrates certain internal elements of the LRA 8, more particularly the flow path of containment or production fluid, as indicated with the reference numbers 113, the gooseneck conduit 107B (through the connector 107A), 116C, 115C (through the valve 115B and the locking elbow 109B) and finally the flow path 64 through the retainer connector inner 92 and inner vertical pipe 60. Figure 3F also illustrates five cladding pipe supports (sometimes referred to in the art locks) 103 pre-installed within the submarine wellbore 104, the upper support belay internal retainer connector 92 maximum within the submarine wellbore 104, as also explained with reference to FIGS FIGS. 4A, B and C. In certain embodiments, there may be one, two, three, or more supports 103. Figure 3G indicates the position of the thermal insulation, called INS, on parts of the LRA 8.

Other details of this embodiment of an LRA are illustrated in Figures 4A, B, and C, which illustrate the use of two blocking supports 704, 724. In addition to the elements previously detailed, Figures 4A, B, and C illustrate a plurality of connector locking indicator rods 720 traveling up and down and showing whether the external retainer connector 102 is open or completely closed. Also illustrated are one of two secondary mechanical locking plates 702 (the other one is concealed in Figure 4A), as well as the pipe 110A for the flow of the hydraulic fluid through the servomechanisms 110. The servomechanisms and the pipe 110A, which passed through the end cap 110B (or through other outer doors within the connector 102) are parts of an upper active locking system 102A for the external locking connector 102. A lower passive locking system 102F is also included in this realization. An example of mechanical details and operation of the upper active locking system 102A and the lower passive locking system 102F are given in US Pat. No. 6,540,024. In summary, the upper active locking system 102A comprises an inner sleeve 102C, a hydraulic, axially movable piston 102D and an upper locking element 102E, which may be a split ring, work collet, or a plurality of ratchets arranged in circumference within a chamber formed between an inner surface of the outer detent connector 102 and a lower part of the piston 102D.

Some details of the lower passive locking system 102F of the inner retainer connector 102, as well as some details of the inner retainer connector 92, are illustrated schematically in cross-section in FIG. 4C. The blocking supports 704 and 724 are provided, the support 704 provides 2 million lbf (0.9 million Kgf) of blocking capacity in this embodiment. Figure 4C also illustrates an outer body or sleeve 708, and an inner body or mandrel 709. A group of the locking pawls 717 is provided to block the blocking cladding pipe support 704 to the underwater wellhead cabinet 104. Another group of locking pawls 901 is provided to lock the external retainer connector 102 to the submarine wellbore cabinet 104. A lower group of locking pawls 706 block the sleeve 708 of the internal detent connector 92 to the pipe support. of blocking liner 704, and therefore also block the submarine wellbore cabinet 104.

Still with reference to Figure 4C, a similar group of the upper locking pawls 740 block the internal detent connector 92 to the stress connection 2FJB and therefore to the external retainer connector 102. The lower and upper groups of the pawls provide a secondary blockade of the vertical pipe to the underwater manhole 104 and can maintain the integrity of the pressure with the 92A nose seal fully engaged if the external retainer 102 if for any reason unblocked from the underwater wellhead 104 Also schematically illustrated in Figure 4C are the packaging assemblies 710, 711, and 715, and a bearing surface 712 on an inner part of the coating tubing support 704 for supporting the nose seal of the internal retainer connector 92A. . The packing 711 includes a wedge 711A which urges the pawls 717 within a group of internal mating grooves 717A of the wellhead cabinet 104. The pawls 901 are positioned within a grooved window 902 in the internal detent connector 102. Figure 4C also illustrates a wellhead washer 716. As understood by those skilled in the art, one or more of the ratchets described herein may be replaced by a split ring, a collet holder or other functional equivalent.

The internal detent connector 92 has a nose seal 92A, which can be Inconel, which is sealed within the support surface 712 of the blocking support 704. The internal detent connector 92 is secured with the ratchets 706 both to the support lock 704 as to the stress connection 2FJB to create a pre-charged structural connection between the manhole 104 and the internal and external retained connectors 102 and 92 (in addition to the external active connector latch at the wellhead, so that there is multiple redundancy). The nose seal 92A can provide pressure integrity between the internal flow path 64 and the ring 76 between the inner and outer vertical pipes 60, 70. Therefore, as illustrated in Figure 3F, the oil and gas that must be contained or to be produced rising through the underwater flexible closure wire 14 through a passage defined by the interior surface 113 of the flexible conduit 14, enters the wing valve assembly through the passages 107B and 116C, and flows through the elbow block 109B and the forge 106. With the nose seal 92A engaged, the produced fluids have only one way of going upward through the inner vertical pipe 60 through the passage 64 to the URA and finally through the flexible conduit 12 to the containment vessel 32 in this embodiment.

Another embodiment of a lower vertical pipe assembly is provided schematically in Figures 5A-5G. In this embodiment, a substantially cylindrical member 220 is provided, which is a member of forged high strength steel. The member 220 is fluidly connected to a vertical pipeline production connection 221 through a lower crossover connection 222 and a threaded connector 242. An eyebolt flange 223 allows the connection of the member 220 to a pile assembly on the bottom of the sea. The double clamp supports 224A and 224B support the submarine connectors 225A and 225B, respectively. Two production wing valve assemblies 226A and 226B are provided, each fluidly connected to the member 220 through the respective locking elbows 230A and 230B. Each assembly 226A and B includes a valve operable by a vehicle operated by remote control 227A and 227B. A montage or sub-gallery is provided. 228, which fluidly connects the member 220 through a locking elbow 229. The assembly or sub-bay 228 may provide a fluid connection to a source of a functional fluid, such as a flow assurance fluid or other fluid. In this embodiment, the blocking elbow 229 is smaller than the blocking elbows 23OA and 230B, but this is not necessarily the case. Another assembly 231 is a servomechanism assembly for the injection of a functional fluid. In this embodiment, the servomechanism assembly 231 provides a lower flow velocity of the functional fluid than is possible through the assembly 228, but again this is not necessarily so. A small diameter conduit 241 (Figure 5F) allows the delivery of the functional fluid.

Figure 5C illustrates a perspective view of a production casing or pipe 232 connecting to an internal surface of the member 220. The production pipe 232 includes a retainer ring 233 and a seal element 234, which may be a seal element of type S. Seal element 234 may be composed of Inconel or other corrosion resistant metal. As also schematically illustrated in Figures 5D and 5E, the retaining ring 233 includes at least one group of the internal threads 235 that engage with a set of threads on the production pipe 232. The retaining ring 233 it also includes at least a group of the external threads 236 which engage the threads on an internal surface of the member 220. FIG. 5E illustrates the valves operable by a double in-line remote operated vehicle 237A and 237B for injection of the functional fluid (or outward circulation) included in the ring ventilation subassembly 228, which includes a perforation 238 that provides access to a ring between the production pipe 232 and the member 220 and the lower crossing connection 222. it may provide a flange connection 239 or other connection for this purpose. Each production wing valve assembly 226 includes a connector 240 (240A and B) that allows connection to the subsea flexible conduits, as illustrated in the plan view of Figure 5G. Connectors 240A and 240B can be known connectors with the OPTIMA brand designation, available from Vector Subsea, Inc.

Figure 8C is a side elevation view of another LRA assembly in accordance with the present invention. This embodiment of the LRA may include a high strength steel forged reel 920, a 921 connector and the swan neck 944, the submarine API 945 flange, the pipe reel 946, the high pressure submarine connector 180, another underwater API tab 111, bending restrictor 112, and submarine flexible conduit 14 that can be connected to a subsea source of hydrocarbons (not illustrated). Another connector 947 on the inlet spool 920 may allow connection to a functional fluid source.

Figure 8D illustrates, in cross-section indicated 8D-8D in Figure 8C, details of this embodiment of the LRA, illustrating an internal detent connector 92 supported on an inner surface of the input spool 920. A clamping mechanism 930 allows the internal detent connector 92 is releasably connected to the inlet spool, while an O 928 seal can provide an airtight seal between the bore of the internal detent connector 92 and the ring 76. The flexible connection 2FJB is connected to the input spool in known manner, for example through split rings, collet clips, or ratchets as described herein for other embodiments.

Assembly of Superior Vertical Pipes (URA) Figure 6 is a schematic side elevation view, with cut-away portions, of a general embodiment of an upper vertical pipe assembly 6 according to the present invention. The upper vertical pipe assembly (URA) 6 of this embodiment is a generally cylindrical member that includes an upper end 6UE and a lower end 6LE and defines an inner bore 6IB. The URA 6 shares a common bore with the outer vertical pipe 70 of this embodiment and may share more than one common bore with it. The conduits 6A and 6B are fluidly connected to the URA through the take-point gates 60T, the conduit 6A is fluidly connected to the inner bore of the inner vertical pipe 60 while the conduit 6B is connected in the form fluid with an annular space created by the inner bore of URA 6B and the inner vertical pipe 60. The upper end of URA 6UE can be connected to a support device near the surface (not illustrated) through a chain rope or another connector 127.

Figures 6A-6G include different views, some in cross-section, of another embodiment of an upper vertical pipe assembly according to the present invention. Figure 6H is a schematic perspective view and Figures 61 and 6J are cross-sectional views of a part of the upper vertical pipe assembly embodiment of Figure 6; Figure 6K is a perspective view of a seal test door. The URA 6 of this embodiment includes a pipe mouth 122, which serves as a fluid connection between a liner pipe mouth and the rod connection 124 manufactured by GE Oil & Gas, and a drill adapter spool 120. The drill adapter spool 120 and the pipe mouth 122 are mechanically connected together using a plurality of locking assemblies 120A, while the pipe mouth 122 and the mouth of the pipe 120"Casing pipe and stem connection 124 are also mechanically connected using a second plurality of locking assemblies 122 B. The locking assemblies 120A and 122B may be the same or different and may be locking screw assemblies or other assemblies. is known from the art, a non-restrictive example of a locking screw assembly is provided in U.S. Patent No. 4,606,557. Also included is a shackle adapter flange 126, an eyebolt end worm! 128, and a U-shaped connection 125 providing a connection for the rope chain 127. All of the elements (except the eyebolt eyelet) are available from GE Oil &Gas.

Pipe mouth 122 can be milled with a 5-1 / 8"10K API flange connection and mounting, mounted production wing valves 136 fitted with a 13 cm emergency shut-off valve, 10,000 psi (69 MPa) hydraulically operated, 137B, and a 10,000 psi (69 MPa) emergency shut-off valve operated by a remotely operated vehicle, 131. A servo-operated vehicle door panel can be provided by control remote monitoring of pressure and temperature 139 in certain embodiments and a vehicle panel operated by remote control of nitrogen (or other fluid) injection 152 may be provided in certain embodiments for the injection of nitrogen or other gas atmosphere into the ring vertical pipe The pipe 158 for the injection of nitrogen or other gas atmosphere within the ring may be included in this embodiment, as well as pressure, temperature and purge gates ( through the remote control vehicle access panel 153) between the valves on the production flow path. A burst disk 156 may be provided on the ROV panel 152. The ROV servomechanism doors and gauges may be provided between the two ESD valves on the URA to circulate the functional fluid back through the flexible conduit 12 to the surface structure and the purge pressure from the line if necessary (while keeping the first valve closed). An umbilical saddle clamp 155 is provided. A series of exit doors 130 can be provided in the pipe mouth 122 (see Figure 6A), as well as a plurality of intervention doors 135.

As illustrated in Figure 6B, a flange connection 133 can connect a high pressure underwater connector 184 to a bend restrictor 134. A kick reel 138 and a bend restrictor adapter 157 are also provided. lifting eye 129A for lifting the assembly of production wing valves 136, but not when mounting the underwater flexible conduit 12.

Figure 6D is a side elevational view of the URA 6, and Figure 6E is a cross-sectional view through section A-A of Figure 6D. As illustrated in Figure 6E, an adjustable support of the URA 159 is provided in this embodiment. The containment fluid flow path is also indicated 64, first upwards through the perforation 64, then laterally through the passage 137D in the blocking elbow 137A and the connection 132, then downwards through a passage 137C in the valve 137B and the passage 131A in the valve 131 , and finally outside the URA through the flow path 184B in the submarine connector 184A, which is connected to the flexible conduit 12 through the flange 184C, and the flow path 12A through the flexible conduit 12 to the containment vessel 32. on the surface of the sea in this embodiment.

Figure 6F is a plan view of the URA 6, which illustrates in more detail some of the elements mentioned previously. Other details of this embodiment of this embodiment of a URA are illustrated in Figures 6H-K. A nitrogen injection gate 158A is illustrated, as well as a lower part 122A of the pipe mouth 122, the lower part includes a seal test door 718. A seal ring 720 is also illustrated between the pipe mouth 122 and the casing mouth 124; a metal-to-metal seal 722; a torsion tool profile 724, a crossover connection 726, and a support load ring 728, as well as a packing 730. Figure 6J also illustrates a URA forging 734 having the doors 732 therein suitable for mounting the manometers and thermometers. Finally, a seal ring 736 is illustrated positioned between the piercing adapter spool 120 and the pipe mouth 122. Figures 6H and 61 illustrate the casing mouth and the shank connection 124 comprise a lower mouth portion. casing 124A and a rod connection 124B welded at 124C to the lower part of casing nozzle 124A.

Figure 6G is a schematic perspective view of the URA 6, illustrating the placement of the insulation material, INS, around the valves 137B and 131, as well as an associated pipeline.

Figures 7A and 7B are schematic perspective views of another embodiment of the upper vertical pipe assembly (URA) according to the present invention, Figures 7C-7D are cross-sectional views of the embodiment of Figures 7A and 7B, and Figure 7E is a detailed cross-sectional view of a part of this embodiment. This embodiment of the URA is different from the embodiment of the URA illustrated in Figures 6A-6K mainly when it allows the circulation of a functional fluid, such as heated water, through the ring. The embodiment of the URA illustrated schematically in Figures 7A-7E, replaces two of the large-bore valves and the large-bore passages of the embodiment illustrated schematically in Figures 6A-6K with a servomechanism functionality. of ROV to inject a functional fluid such as nitrogen. In the embodiment illustrated in Figures 7A-E, another flexible conduit (not illustrated for clarity) can be connected to the URA through the submarine connector 818 and extended to a surface vessel if continuous or semi-continuous circulation is desired within or to through the ring.

A take point reel 804 is fluidly connected to a support reel 803. The support reel in turn is connected in this embodiment to a tapered stress connection 802, which is not part of the URA but is illustrated for make it complete and show the way in which the URA can be connected to a vertical pipe system. A shackle 806 and the chain rope 807 allow the URA to be mechanically connected to the support device near the surface (not illustrated). As best shown in Figure 7D, blocking elbow 808 includes an interior borehole '808? intersecting and being substantially perpendicular to a bore 804A in the take-point reel 804. Also included in this embodiment is a locking elbow 809 and an inner bore 809A that is also substantially perpendicular to bore 804A but does not intersect with the bore 804A. 804A drilling.

A gooseneck conduit 810 provides, in embodiments, a flow path for the hydrocarbons in combination with the elbow bore 808A, the first emergency shutoff valve (ESD) 811 and the second ESD valve 812. An outlet 813 in connector 813A it can be connected to a subsea flexible conduit 12 for production or containment operations. The connector 813A can be a known connector with the OPTIMA brand designation, or another connector suitable for submarine use. An ROV 814 connection is provided for the 813A connector operation. A purge valve 815 can also be provided, which serves to allow closure within the URA, purging the contents of the gooseneck assembly 810, and recovering the subsea flexible conduit, for example for a hurricane or other unplanned event, or a planned event.

Valves 816 and 817 are provided for ring circulation and / or production and / or injection of functional fluid through connector 818. Valves 816 and 817 may be operable by a vehicle operated by remote control. A functional fluid may also be injected into the ring through another valve operable by a remote operated vehicle 819 and connector 820, which may be a flange connector.

Figure 7E is a detailed cross-sectional view of a surface where the take-point reel 804 and the support reel 803 are connected. Two ring seal and cable retainer 822 arrangements provide double seals between the flowing fluid within the bore 825A within the pipe 825 and the chamber 827 that contains the wedges 824. A passage 826 that allows access to the 822 arrangement may also be included.

Another embodiment of an upper vertical pipe assembly according to the present invention is illustrated schematically in side elevation in Figure 8A. URS 6 includes, in some embodiments, a production take-off point reel 910 fluidly connected to a conduit 911 and to a production line; 913. The production line 913 is fluidly connected to a bending restrictor 134 through an underwater API flange 905, a submarine high-pressure connector 184, another underwater API flange connection and optionally a submarine connector (such as as available in Vector Subsea, Inc. under the brand name OPTIMA). The bend restrictor 134 may be connected to a subsea flexible conduit 12, which extends within a catenary loop to a surface structure in a known manner. A USD 915 is provided in this embodiment in the pipe section 911, which may be operable by a vehicle operated by remote control. A support clamp 916 is provided in this embodiment, which in addition to the support pipe 913 at an angle s, also bears a bending shield 942 which provides a mechanical barrier between the wing assemblies. The angle s can be in the range of 0 to 180 degrees, or 30 degrees to 90 degrees, or 30 to 45 degrees. The pipe 911 is fluidly connected to an adapter 926, which in turn fluidly connects to a support reel 912 through an API flange 917, pipe mouth 124 through another API flange 918 , rod connection 124B welded to the liner mouth 124, and the vertical pipe 2 threaded into the rod connection 124B. The take-up spool 910 may include a ratchet flange 127 which allows connection to a chain rope 125 and the support device near the surface (not shown).

Another element of the present embodiment, illustrated in Figure 8A, is the provision of a connection 906 within the support reel 912 to connect a swan neck 907, an API 908 flange, a 909 pipe, a high submarine connection. pressure 940, another submarine API connector 940 and API flange 941, and bending restrictor 923 for a subsea flexible conduit 919 for supplying heated water (or other flow assurance fluid) to support reel 912 from a structure of surface. The heated water, (or other flow assurance fluid) can then circulate within the ring, or traverse the ring generally downward to an LRA and exit the ring through one or more ring ventilation valves, as illustrated in FIG. 142, 144 in FIG. 8G.

Figure 8B illustrates, in a cross-section indicated 8B-8B in Figure 8A, details of this embodiment of the URA. An inner vertical pipe 60 is illustrated positioned inside the adapter 926, the support reel 912 and the coating pipe mouth 124, creating an annular space 76 between the inner surface 912A of the support spool 912 and the inner vertical pipe 60 A pair of O-ring seals 925 seal the inner vertical pipe 60 within the adapter 926 in this embodiment. One or more wedges 924 form a wedge between an inner inclined surface 943 of the support reel 912 and the inner vertical pipe 60, firmly securing the inner vertical pipe of a support reel 912.

Figure 8C is a side elevational view of another LRA assembly in accordance with the present invention, the LRA embodiment includes a high strength steel forged inlet reel 920, a connector 921 and a swan neck 944, a underwater API tab 945, a pipe reel 946, a high pressure underwater connector 180, another underwater API tab 111, a bending restrictor 112 and the submarine flexible conduit 14 that is connected to a subsea source of hydrocarbons (not illustrated). Another connector 947 on the inlet spool 920 allows connection to a functional fluid source.

Figure 8D illustrates, in a cross-section indicated 8D-8D in Figure 8C, details of this embodiment of the LRA, illustrating an internal detent connector 92 supported on an inner surface of the input spool 920. A locking mechanism 930 allows that the inner detent connector 92 is releasably connected to the inlet spool, while a 0 928 ring seal provides a hermetic seal between the bore of the internal detent connector 92 and the ring 76. The flexible connection 2FJB is connected to the input spool in a known manner, for example, by split rings, collet clips, or ratchets as described herein for other embodiments.

Flow assurance calculations may indicate that an FSR can be designed with a 7.6 cm thick, 5-layer polypropylene thermal insulation coating applied to the exterior vertical pipe, while the ring between the interior vertical pipe and outside would move with low pressure nitrogen. During the operation, this scheme can substantially maintain the temperature of the hydrocarbons from an underwater source until their arrival on the surface structure.

Materials, Methods of Construction and Installation In addition to the washers, hoses, flexible conduits and other components that are not considered a part of the present invention, the main components of the LRA and URA described in the present invention (take-up spools, reels of entry, reels of support, generally cylindrical members, vertical pipe sections, pipe nozzles, lining pipe nozzles, pipe spools, high pressure subsea connectors, rod connections, vertical pipe stress connections and the like) may be composed mainly of alloys of steel. While low alloy steels may be useful in certain embodiments where the water depth is no more than a few thousand meters, activities in water of greater depth, with wells reaching 6,000 meters and beyond can result in temperatures and pressures higher than normal. In these "high temperature, high pressure" (HPHT) applications, high strength low alloy steel metallurgies such as C-110 and C-125 steel may be more appropriate.

The programs of the Research Association to obtain Energy for the United States (RPSEA) and Deepstar have initiated a large-scale, long-term prequalification program to develop data bases of fatigue data and obtain factors of lowering on high-strength materials. for vertical pipe applications with the contribution of major operators, engineering companies and material sellers. High strength steels (such as X-100, C-110, Q-125, C-125, V-140), Titanium (such as Grade 29 and possibly newer alloys) and other possible candidate materials in the category of higher strength can be tested for pipe applications and according to those results, they can be useful as materials for the vertical pipes, LRA, and URA that are described herein. Higher strength forging materials (such as F22, 4330M, Inconel 718 and Inconel 725) have been tested or will be tested early for component applications in the coming years and may prove to be useful for one or more assembly components. LRA and / or URA and / or vertical pipes that have been described. The test matrix can be designed to reflect different production media and different types of vertical pipe configurations such as vertical single catenary (SCR) pipes, vertical dry tree pipes, vertical drilling and completion pipes. The project is currently being programmed to be divided into 3 separate Phases: Phase 1 will face tensile and fracture toughness, FCGR and SN tests (both smooth and serrated) on specimens of high strength piping strips, high-strength forging materials and alloy forgings based on nickel in an air, seawater plus Cathodic (CP) and sulfurous (uninhibited) and a termination fluid called INSULGEL (BJ Services Company, USA) with contamination of the sulfurous medium (uninhibited) (2008).

Phase 2 is programmed to be an Intermediate Inlay Test (2009), and Phase 3 is a Complete Inlay Test with H2S / C02 / Seawater (2010). For more information, please see Shilling, et al., Development of Fatigue Resistant Heavy Wall Vertical Pipe Connectors for Deepwater HPHT Dry Tree Vertical Pipe Systems, OMAE (2009) 79518 (ASME Copyright 2009). . See also RPSEA RFP2007DW1403, Fatigue Performance of High Vertical Pipe Materials, Resistance, November 28, 2007. The artisan, who has knowledge of the depth, pressure, temperature and particular materials available, can design a system for each particular application without undue experimentation.

During the last several years, the assignee of the present has participated in the development of a program: qualification of vertical pipes of dry tree of 15 / 20Ksi (103/138 MPa) wide that focuses on the demonstration of the adequacy of the use of high strength steel materials and specially designed threaded and coupled (T &C) connections that are directly milled on the vertical pipe connections in the mill. See Shilling et al., "Development of Heavy-Duty, Heavy-Wall Vertical Pipe Connectors for Deep-water HPHT Dry Tree Vertical Pipe Systems", OMAE2009-79518. These connections can eliminate the need for welding and facilitate the use of high-strength materials such as metallurgies of C-110 and C-125 that are qualified by NACE. (As used herein, "NACE" refers to the organization for the prevention of corrosion formerly called the National Association of Corrosion Engineers, which now operates under the name NACE International, Houston, Texas.).

The use of high-strength steel and other high-strength materials can limit the thickness of the wall needed, allowing vertical pipe systems to be designed to tolerate pressures much greater than. those that can be handled with the X-80 materials and installed at much greater depths of water due to the reduced weight and therefore the tension requirements. T &C connections can reduce the need for third forges and costly welding processes, which greatly improves the time and total cost of system supply. Using these materials and connectors to design a FSR containment system of 15 Ksi (103/138 MPa) fully qualified second generation, the outer vertical pipe can actually be reduced in size from the outside diameter of 35,085 cm to the outside diameter of 27,305 cm x 1.91 cm wide with an inner vertical pipe of C-110 of 17.8 cm outside diameter x 1.15 cm wide. It will be understood, however, that the use of third forgings and welding is not excluded for the URA, LRA and vertical pipes that are described herein and may actually be preferable 1 in certain situations. The person skilled in the art, who knows the depth, pressure, temperature and particular available materials, can design a system for each particular application without undue experimentation.

The assembly connections described herein for vertical pipes and intra-mohtaj e connections, such as the drill-spool adapter to pipe-end connections and the connections of cylindrical members to pipes ? verticals and the like, may include threading as described in the Shilling et al article mentioned above, as well as those described in the following patent documents: WO2005093309; O2005059422; U.S. Patent Nos. 6,752,436 and 6,729,658. More information can be found in the following publications: Sches et al .; Fatigue Resistant Couplings and Couplings: The New Standard for Vertical Deepwater Pipe Applications, OMAE 2007-29263; Sches et al., Threaded Connectors and Fatigue Resistant Couplings for Deepwater Vertical Pipe Systems: Evaluation of Design and Performance by Full Scale Analysis and Testing, OMAE 2008-57603; and Shilling et al., Developments in Vertical Pipe Technology for HPHT Ultra-Deep Wells of the Next Generation, DOT Conference, 2008 Proceedings.

The construction materials for washers, flexible conduits and hoses useful in conjunction with the assemblies and methods described herein depend on the specific depth, temperature and pressure of the water to which the assemblies are used. While elastomeric washers can be used in certain situations, metal washers have been increasingly used in underwater applications. For a review of the art around 1992, please see Milberger, et al., "Evolution of the Principles of Metal Seals and their Application in Underwater Production and Drilling", OTC-6994, Conference on Maritime Technology, Houston, Texas, 1992. See also API Standard 601: Standard for Metal Washers for High Surface Pipe Lashes and Eyelash Connections and API Specification 6A: Specification for Wellhead and Christmas Tree Equipments.

The washers are not, by themselves, a part of the assemblies and methods of the present invention, but: as certain embodiments of LRA and URA may employ washers (such as the wellhead washer 716 mentioned in connection with the LRA embodiment). of Figure 3J), mention is made of the following US Patents that describe washers that may be suitable for use in particular embodiments, US Patent Nos. 3,637,223, 3,918,485, 4,597,448, 4,294,477, and 7,467,663. In certain embodiments, the material of the washer called DX washer qualified for 20 ksi can be used.

Another washer that can be used under the sea is one called with the Pikotek VCS brand designation, available from Pikotek, Inc., Wheat Ridge, Colorado (USA). It is believed that this type of washer should be described in U.S. Patent No. 4,776,600, which is incorporated herein by reference.

In certain embodiments, the URA may have a recoverable impulse disk, which allows ventilation of the URA to the atmosphere. In certain embodiments, the pulse disk may be a recoverable pulse disk. The pulse discs may allow, among other things, the ventilation of the annulus above the LRA and in certain embodiments may allow pumping of a functional fluid such as nitrogen within the annulus near the top of the FSR. The impulse disks can allow the measurement of the pressure and / or the temperature of the flow stream (inside the inner vertical pipe) or the ring between the inner and outer vertical pipes. In addition to impulse disks, high-flow servomechanisms can be used in different types of equipment, for example, in emergency disconnection systems.

Subsea flexible conduits, sometimes referred to herein simply as "flexible" or "flexible closure wires", are known to those skilled in the art of subsea drilling and production. For example, U.S. Patent No. 6,039,083 discloses that flexible conduits are commonly used to transport liquids and gases between submerged pipelines and marine oil and gas production facilities and other facilities. These ducts are subject to high internal and external pressures, as well as to chemical actions associated with the seawater that surrounds the submerged ducts and the fluids that are transported inside the ducts. U.S. Patent No. 6,263,982 discloses flexible undersea conduits which may comprise a flexible steel pipe, such as that manufactured by Coflexip International of France, under the trademark "COFLEXIP", such as its 12.7 cm diameter flexible pipe. internal, or shorter segments of rigid tubing connected by flexible connections and other flexible conduits known to those skilled in the art. Other patents of interest, assigned to Coflexip and / or Coflexip International, include US Patent Nos. 6,282,933; 6,067,829; 6,401,760; 6,016,847; 6,053,213 and 5,514,312. Other possibly useful flexible conduits are described in U.S. Patent No. 7,770,603, assigned to Technip, Paris, France. U.S. Patent No. 7,445,030, also assigned to Technip, discloses a flexible tubular conduit comprising successive independent layers including helical coils of different strips or sections and at least one polymeric shell. At least one of the windings is a strip or strips of polytetrafluoroethylene (PTFE). This list does not include all of the flexible conduits that can be used in systems and methods of the present invention.

Hoses, which may also be referred to herein as flexible closure wires in certain embodiments, suitable for use in the systems and methods of the invention may be selected from a variety of materials or a combination of materials suitable for subsea use. In other words, they have high resistance to temperature, high resistance to chemical compounds and low penetration ratings. Some fluoropolymers and nylons are particularly suitable for this application except for conduits of a very long length (several kilometers or more) where penetration can be problematic. A good survey of hoses and materials can be found in U.S. Patent No. 6,901,968, currently assigned to Oceaneering International Services, London, Great Britain, which describes the so-called "Hoses of High Resistance to Sinking" of the type used in the applications of deep sea, which, in use, must be capable of resisting sinking due to very high pressures exerted on them.

In certain embodiments, it may be necessary or desirable to join one hose to another, or replace a damaged hose. In these cases, hose splicing devices operable by vehicles operated by remote control of the serial numbers of transferee 61479486: and 61479489, both filed on April 27, 2011 may be useful. Patent application '486 discloses hydraulically powered splice devices operable by remotely operated vehicles, while patent application 89 discloses hose splice devices supplied in a non-hydraulic (mechanical) manner operable by vehicles operated by remote control . Each device provides a full drill connector while allowing full pressure service that may be preferred for applications that require high flow rates and high pressure. A simple servomechanism movement that employs a guide funnel minimizes the necessary dexterity of the remotely operated vehicle pilot. Hydraulically powered devices include at least two chambers and at least one mechanical self-gearing lock for each chamber, where after a hose is traversed in a chamber, the remotely operated vehicle pilot energizes the device and the connection is made without needing to move again the manipulators of vehicle operated by remote control and the hydraulic pressure can be released from the cameras. A remotely operated vehicle servomechanism can be used in certain embodiments to connect the device to the remote controlled vehicle hydraulic power unit and charge with power and operate the device.

The assemblies described herein may be useful with a single pipeline (Single Line Shifted Vertical Pipe, SLOR) or a pipeline in a pipeline design (Concentric Shifted Vertical Pipe, COR) that provides additional insulation and allows the hoisting of Vertical pipe base gas or active heating through the ring. These vertical pipes can be a welded or threaded construction and can be tensioned with an upper air canister located 50-150 m below the surface according to environmental conditions, or with hydropneumatic tensioners, or both. Each independent vertical pipe can be connected to the surface structure (for example, a surface vessel or a production platform) by means of a flexible shallow water closing wire.

In certain embodiments, the tension of the vertical pipe is maintained using a non-integral air-boat system chain attached by a rope above the vertical pipeline chain. The air boats provide the necessary lift necessary for: the control of overall stability and movement behavior and ensures that the positive stress of 100 kips (45,000 kg) positive on the vertical pipe hose is experienced under all conditions of load, which include the failure of one or more airboat chambers. In one embodiment, an LRA generally manufactured in accordance with Figures 3 and 4 weighs approximately 30 kips (13,600 kg) in air, 26 kips (11,800 kg) submerged. It can be mounted to the suction pile with 27 meters of chain without right foot R-4 of 117 mm with a breaking strength of 2,915 kips (1,300,000 Kg) and a shackle Crosby G-2140 of 250 tons (230,000 Kg) ) with a breaking strength of 2,750 kips (1,230,000 Kg). The LRA of this embodiment is comprised of a subsea wellhead H-4 of GE Oil &; 15 Ksi (103 Mpa) gas, especially milled with 10,000 psi (69 MPa) inputs of 5.08 x 18 (2cm to accommodate several flexible closure wire connections or as illustrated in Figure 3, a Production closing wire and a vehicle interconnection operated by remote control for methanol injection.

The concept of containment or production of the FSR using the assemblies that are disclosed herein is scalable in a wide range of water depths and well pressures and conditions. The flow assurance calculations indicate that the FSRs, the LRA and the URA that are used, are capable of handling more than 40,000 bbls per day (6400 m3 / day) each with an internal diameter flow path of 15 cm. The existing dry tree vertical pipe hardware can be used to build the FSRs as it is readily available. The exterior vertical pipe connections can be an X-80 wall material of 35.085 cm outside diameter x 1.43 cm and rated at 6,500 psi (45 MPa). The X-80 material can be used for welding on high quality vertical pipe fittings with metal-to-metal external and internal seals and fatigue performance for anticipated service life.

The vertical pipe system employing the URA and / or LRA assemblies of the present invention can be installed, in certain embodiments, by a MODU and then housing the upper flexible closure wire installation after the pipe has been run vertical The upper flexible conduit can be connected to the LRA during installation from the drilling MODU and optionally stapled in the intervals hanging vertically along the vertical pipe. The lower flexible subsea conduit can be connected several days later to the LRA by underwater installation vessels after the FSR is connected and taut to the suction pile.

The surface structure can be equipped with a quick disconnect system (QDC) for the upper flexible conduit. The embodiments of a quick connect / disconnect coupling element are described in the US provisional patent application of transferee act number 61480368, filed on April 28, 2011. A detachable buoy can be used to support the end of the structure of surface of the upper flexible duct during an emergency disconnection. The buoy can be mounted to provide lift and drag and ensure that the flexible conduit is not damaged by a too fast descent (i.e., excessive compression exceeding the minimum bend radius) after it is released to fall freely. In the case of a hurricane or planned disconnection, the 15 cm top flexible duct is disconnected from the surface structure in a controlled manner and lowered with a support vessel to hang along the side of the FSR, where Engrampa instead - through a vehicle operated by remote control.

In certain embodiments of concentric vertical pipes in which one or more of the LRA and / or URA described herein may be useful, the LRA may allow flow control of the inner vertical pipe as well as the ring between the pipes Vertical interior and exterior. The internal vertical pipe flow path may have provisions for pressure and temperature sensors; an ESD valve operated hydraulically near the fault controlled from the surface structure; a vehicle servo pressure purge door operated by remote control; and / or a manual gate valve operated by a vehicle operated by remote control. The ring can incorporate the provision for injection of servomechanism nitrogen of vehicle operated by remote control and a temperature and pressure sensor. A pressure safety valve (PSV) set at 4,500 psi (31 MPa) above the vertical pipe ring can prevent failure due to excessive pressure from the exterior vertical pipe in the event of a hydrocarbon leak from the interior vertical pipe .

In certain embodiments, the LRA provides remotely operated vehicle servomechanism access to both the vertical pipe ring and the production flow path for injection., ventilation, monitoring of pressure and temperature. Two 7.5 cm valves operated by a remotely operated vehicle on the ring vent provide greater drilling access to the ring for nitrogen purging and venting operations, or other functional operations. In certain embodiments, the flow path of the LRA is comprised of two reels, each of which is equipped with a 10 Ksi valve (69 MPa of 13 cm operated by a vehicle operated by remote control and clamps operated by an operated vehicle by remote control (such as those provided by Vector Subsea) for underwater connection of flexible production closing wires.

In certain embodiments, the LRA and URA assemblies described herein may be used as components of a containment and disposal system, or production. In such systems, a hydrate inhibition system (HIS) can be integrated into the systems and methods. The supply lines of chemical compounds for the inhibition of hydrates from a surface vessel can supply chemical compounds to a submarine blowout preventer stack cover, BOP, and to submarine flexible conduits through a submarine manifold. When the chemical compound is circulated, it can return to the vessel through a return line. The chemical compound can also be supplied to the strangulation and death lines of the submarine BOP through a multiple strangulation death tube.

From the foregoing detailed description of specific embodiments, it should be evident that patentable assemblies and methods have been described. While the specific embodiments of the invention have been described herein in some detail, this has been done solely for the purpose of describing different elements and aspects of the methods and apparatus and is not intended to be exhaustive with respect to the scope of the invention. montages and methods. It is contemplated that various substitutions, alterations and / or modifications may be made, including but not limited to those variations of implementations that may have been suggested herein, to the embodiments described herein without departing from the scope of the appended claims.

Claims

1. A mount for connecting a vertical submarine pipeline to a sea floor mooring and a submarine hydrocarbon fluid source, comprising: a generally cylindrical member having a longitudinal perforation, a lower end, an upper end and a generally cylindrical external surface, the member comprises sufficient entry doors extending from the outer surface to the bore to accommodate the flow of hydrocarbons from the source of hydrocarbon fluids as well as the inflow of a functional fluid, at least one of the entrance doors is fluidly connected to a production wing valve assembly, the upper end of the member comprises a profile suitable for fluid connection to a vertical subsea pipeline; and the lower end of the member comprises a connector suitable for connection to a mooring of the seabed.

2. The assembly according to claim 1, wherein the generally cylindrical member comprises: a submarine wellhead cabinet, the modified lower end connecting a transition connection to it-, the transition connection comprises said entry ports sufficient; the upper end of the submarine well mouth cabinet fluidly connected to an external retainer connector fluidly connected to the submarine well mouth cabinet to the vertical pipe stress connection, the submarine well mouth cabinet has an internal seal profile adapted to seal with an internal retainer connector, the internal detent connector that fluidly connects an inner submarine vertical pipe to the inner seal profile; Y the internal retainer connector has a nose seal that seals within the inner seal profile of the submarine wellhead, the nose seal provides the integrity of pressure between an internal flow path in the inner vertical pipe and a ring between the pipe vertical inside and a substantially concentric outer vertical pipe.

3. The assembly according to claim 2, wherein the assembly of production wing valves is fluidly connected to an underwater source through a subsea flexible conduit.

4. The assembly according to claim 2, wherein the vertical pipe stress connection is in turn fluidly connected to the outer vertical pipe.

5. The assembly according to claim 2, comprising valves operated by a vehicle operated by remote control to control the flow through the internal flow path within the inner vertical pipe and the ring.

6. The assembly according to claim 2, comprising one or more servomechanism doors for intervention and / or maintenance of vehicle operated by remote control.

7. The assembly according to claim 1, wherein: the generally cylindrical member comprises a high strength metal forge fluidly connected to a vertical production pipe turning connection through a lower crossover connection and threaded connector, the forge comprises said longitudinal perforation, lower end; upper end, generally cylindrical external surface and said sufficient entrance doors, the lower end of the metallic form comprises the connector suitable for connection to the underwater mooring.

8. The assembly according to claim 1, wherein the generally cylindrical member comprises a forged, high strength steel inlet spool, fluidly connected to a swan neck assembly, the neck assembly of .cisne is connected in fluid form to a submarine source through a flexible underwater conduit, the inlet spool also comprises a connector that allows connection to a source of a functional fluid.

9. A mounting for connecting a ver.tical submarine pipeline to a submarine lift device and to a surface structure comprising: a generally cylindrical member having a longitudinal perforation, a lower end, an upper end and a generally cylindrical external surface, the member comprises sufficient exit doors extending from the perforation to the generally cylindrical external surface to accommodate the flow of hydrocarbons from the vertical pipe, and at least one door allows the flow of a functional fluid within the longitudinal perforation, at least one of the outlet doors is fluidly connected to a production flange valve assembly to connect in fluid form the member to the surface structure with a submarine flexible conduit; the upper end of the member comprises a connector suitable for connection to a submarine support device; and the lower end of the member comprises a 'profile suitable for the fluid connection to the vertical pipe.

10. The assembly according to claim 9, wherein the member comprises a drill spool adapter having a first end fluidly connected to a pipe mouth, the pipe mouth comprises one or more outlet doors, the mouth of the pipe The pipe is connected to a casing pipe mouth having a shank connection attached thereto, the casing pipe mouth comprises one or more doors for the entry of a flow assurance fluid.

11. The assembly according to claim 10, wherein the rod connection is fluidly connected to an outer concentric vertical pipe.

12. The assembly according to claim 11, comprising an adjustable pipe support that fluidly connects an inner vertical pipe to the pipe mouth.

13. The assembly according to claim 12, wherein the assembly of production wing valves comprises first and second flow control valves for; control the flow within the inner vertical pipe and within a ring between the inner vertical pipe and the outer vertical pipe.

14. The assembly according to claim 9, wherein the assembly of production wing valves comprises one or more remotely operated vehicle servomechanism doors that allow a flow assurance fluid to flow into an inner vertical pipe and a ring between the inner vertical pipe and an outer vertical pipe, the flow assurance fluid is selected from the group consisting of nitrogen or other gas phase, heated seawater or other water, and organic chemical compounds.

15. The assembly according to claim 9, wherein the generally cylindrical member comprises a take-up spool having the upper end and the lower end, an eye bolt flange connected to the upper end of the take-point spool and a spool of support connected to the lower end of the tona point reel, wherein the take point reel and the support reel define the longitudinal perforation.

16. The assembly according to claim 15, wherein the take-up spool comprises a second bore substantially perpendicular to the longitudinal bore and which fluidly connects the longitudinal bore to one of the production wing valve assemblies through of the exit doors.

17. The assembly according to claim 16, wherein the assembly of production wing valves comprises a gooseneck conduit and two emergency shutoff valves (ESD) connected in fluid form in line to the gooseneck conduit, a of the ESD is operated in hydraulic form and the second ESD is operated in electronic form.

18. The assembly according to claim 15, wherein the support reel comprises a third bore substantially perpendicular to the longitudinal bore and fluidly connecting a ring defined by the support spool and an internal vertical pipe connection with an assembly of ring access valves.

19. The assembly according to claim 18, wherein the assembly of ring access valves comprises one or more valves operable by a vehicle operated by remote control.

20. The assembly according to claim 19, wherein the assembly of ring access valves is fluidly connected to a flow assurance fluid source.

21. The assembly according to claim 9, further comprising a production take-off take-up reel connected fluidly and mechanically to a substantially vertical conduit and to a pipe > For production, the production pipeline is in turn fluidly connected to a bending restrictor through an underwater API flange, a high-pressure submarine connector, an underwater API flange connection and optionally a QDC submarine connector , the bending restrictor connected to the upper submarine flexible conduit extending in a catenary loop to the surface structure and wherein the substantially vertical conduit is connected in fluid form in series to an adapter which in turn is connected in fluid form to a support spool, an API flange, a casing pipe mouth through another API flange, a rod connection welded to the casing pipe mouth and to the exterior vertical pipe through a threaded connection within A rod connection, the take-off spool includes a ratchet flange which allows connection to the underwater support device.

22. The assembly according to claim 21, further comprising an ESD operable by a remotely operated vehicle fluidly connected to a section of the conduit.

23. The assembly according to claim 22, further comprising a support clamp that holds the production line at an angle s with the conduit and also maintains a bending shield that provides a mechanical barrier between the production line and the conduit. , where angle s is in the range of 0 to 180 degrees.

24. The assembly according to claim 23, further comprising a connection to the support reel for connecting a gooseneck for the supply of heated water to the support reel from a surface vessel.

25. The assembly according to claim 24, wherein the swan neck comprises, in order starting from the support reel, an API flange, a pipe section, a high pressure submarine connector, an underwater API connector and a API tab and a bend restrictor.

26. The assembly according to claim 25, wherein the inner vertical pipe is positioned within the adapter, the support spool and the casing mouth, creating the ring between the inner surface of the support spool and the inner vertical pipe.

27. The assembly according to claim 9, further comprising components that allow the circulation of a functional fluid, such as heated water, through the ring.

28. The assembly according to claim 27, comprising a take-up spool connected in fluid form to a support spool, the support spool in turn can be connected to a tapered stress connection of the independent vertical pipe.

29. The assembly according to claim 28, further comprising a first locking elbow that includes the inner bore that intersects and is substantially perpendicular to a bore within the take-point reel, a second locking elbow having a bore. interior that is also substantially perpendicular to the perforation of the take-point reel but does not intersect the take-point reel bore and a gooseneck conduit fluidly connected to a first blocking elbow that provides a path of flow for hydrocarbons in combination with the first block elbow drilling.

30. The assembly according to claim 29, further comprising first and second emergency shut-off valves in the gooseneck conduit, the gooseneck conduit is fluidly connected to an underwater connector which in turn is connected in fluid form to the upper sub-marine flexible conduit.

31. The assembly according to claim 27, wherein the components that allow the circulation of a functional fluid through the ring comprise a submarine connector, a conduit and one or more valves within the conduit, the conduit is fluidly connected to the spool of support.