WO2006059220A2 - A hybrid riser system - Google Patents

A hybrid riser system Download PDF

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Publication number
WO2006059220A2
WO2006059220A2 PCT/IB2005/003638 IB2005003638W WO2006059220A2 WO 2006059220 A2 WO2006059220 A2 WO 2006059220A2 IB 2005003638 W IB2005003638 W IB 2005003638W WO 2006059220 A2 WO2006059220 A2 WO 2006059220A2
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WO
WIPO (PCT)
Prior art keywords
riser system
sea
sub
pipe section
unit
Prior art date
Application number
PCT/IB2005/003638
Other languages
French (fr)
Other versions
WO2006059220B1 (en
WO2006059220A3 (en
Inventor
Lars Slagsvold
Original Assignee
Vetco Gray Scandinavia As
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Vetco Gray Scandinavia As filed Critical Vetco Gray Scandinavia As
Priority to EP05823765.2A priority Critical patent/EP1817475B1/en
Priority to ES05823765T priority patent/ES2729828T3/en
Priority to DK05823765.2T priority patent/DK1817475T3/en
Priority to BRPI0520284-1A priority patent/BRPI0520284B1/en
Publication of WO2006059220A2 publication Critical patent/WO2006059220A2/en
Publication of WO2006059220A3 publication Critical patent/WO2006059220A3/en
Publication of WO2006059220B1 publication Critical patent/WO2006059220B1/en
Priority to NO20072611A priority patent/NO20072611L/en

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/01—Risers
    • E21B17/015—Non-vertical risers, e.g. articulated or catenary-type

Definitions

  • the present invention concerns a hybrid riser system for connection between a floating unit, such as a floating vessel or a production unit for oil and gas production, and a sub-sea unit, such as a sub-sea well facility, located at the sea floor.
  • a floating unit such as a floating vessel or a production unit for oil and gas production
  • a sub-sea unit such as a sub-sea well facility, located at the sea floor.
  • the expression “riser system” is intended to mean a pipe or a string adapted for transport of fluids, i.e. liquids and gases or mixtures thereof, and in particular hydrocarbons, such as oil and/or gas or injection fluids, such as methanol or water, between the floating and sub-sea units.
  • Riser systems include a conduit through which various fluids are transported from a sub-sea facility located at the sea floor to a floating platform or vessel on the sea surface, such as a surface production and/or storage facility or vice versa.
  • the vessel or floating platform is constantly exposed to movements, caused by waves, winds and surface and underwater currents, for example.
  • the floating platform is therefore continuously subjected to forces causing it and the riser system connected thereto to movements.
  • Riser systems must be able to withstand the forces exerted on them without failure due to fatigue or the like.
  • US patent no. 5,639,187 discloses a marine riser system that combines rigid, steel catenary risers with flexible flow lines .
  • the expression "catenary” meaning the curve assumed by a cord of uniform density and cross section that is perfectly flexible but not capable of being stretched and that hangs freely from two fixed points .
  • the steel catenary risers are curved upward through the water in a gentle catenary path to a large, submerged buoy, which, in turn, is moored to the sea bottom by tension leg tether lines at a depth below the turbulence zone of the water.
  • the buoy maintains the rigid steel catenary risers in a substantially vertical position in the water.
  • Flexible flow lines commonly called jumpers
  • a disadvantage with such a system is that a large buoy and clamping means are needed to support the heavy steel risers. Mooring the buoy at a predetermined depth also requires careful planning and engineering, which makes the design and manufacture of the buoy complex, time consuming and expensive. Furthermore, the equipment required for mooring the buoy further increases manufacturing and installation costs.
  • An object of the present invention is to provide a hybrid riser system for connection between a floating unit, and a sub-sea unit that is located at the sea floor, which can withstand or accommodate forces exerted thereon due to movements, such as those caused by the movement of the floating unit.
  • This object is achieved by a riser system that includes a composite conduit for transporting a fluid, i.e. liquid or gas, between said floating and sub-sea units.
  • composite conduit refers to a bonded pipe having an inner liner and an outer protective sheath and optionally at least one reinforcing layer, such as the one described in international application WO 99/67561.
  • WO 99/67561 describes a flexible riser comprising composite material.
  • the riser comprises an inner liner of thermoplastic material, an intermediate reinforced polymer multi layer component and an outer thermoplastic liner.
  • the inner liner is continuously bonded to the intermediate, multi layer component, which is in turn continuously bonded to the outer liner.
  • the inventive riser system also comprises at least one end pipe section that is adapted to be connected between the floating and/or the subsea unit and the composite conduit.
  • Said at least one end pipe section comprises a metallic pipe, i.e. a pipe made of or containing metal, or a non-bonded flexible pipe.
  • non-bonded is intended to mean a pipe consisting of a plurality of layers, comprising a metal or polymer for example, which are not bonded to each other and therefore free to move independently of one another.
  • a non-bonded flexible pipe or a metallic pipe provides an end pipe section of increased strength and weight which will not be deflected and bent like a composite conduit and thus eliminates the need for providing the riser system with additional weight.
  • the hybrid riser system according to the invention has a light and almost buoyant composite conduit section, which implies less load impact on the floating unit.
  • At least one end of the riser system i.e. the end that is connected to the floating unit and/or the end that is connected to the sub-sea unit, is provided with an end pipe section that can better withstand or accommodate the forces exerted on the riser system in the vicinity of the floating and/or sub-sea unit where the riser is deflected and bent the most.
  • the inventive riser system reduces top tension, touchdown curvature, touchdown compression and hold-back tension and is suitable for use at high hydrostatic pressures in deep and ultra deep water.
  • the length of the end pipe section that is connected to the floating unit is approximately 50-600 m. According to another embodiment of the invention the length of the end pipe section that is connected to the subsea unit is approximately 50-100 m.
  • the length of the composite conduit is about 1000-1500 m or longer.
  • said at least one end pipe section is arranged to be negatively buoyant .
  • the composite conduit is constituted by a single, continuous conduit i.e. the composite conduit is connected to at least one end pipe section but there are no other connections along the length of the riser.
  • the riser is adapted to assume a compliant configuration when installed e.g. free hanging (catenary) , Lazy or step S or wave.
  • the composite conduit comprises a bonded pipe having an inner liner and an outer protective sheath, and optionally at least one reinforcing layer.
  • the composite conduit is flexible enough to be spooled onto a reel with a hub radius of about 4500-8500 mm.
  • the composite conduit and said at least one end pipe section have an internal diameter in the range of about 10-40 cm (4-16 inches) .
  • the floating unit is a production or storage unit or a platform or vessel
  • the sub-sea unit is a sub-sea well facility
  • the riser system is adapted for transport of fluids, in particular hydrocarbons, such as oil and/or gas, or injection fluids, such as methanol or water, between the floating and subsea units .
  • Fig. 1 is a schematic view of a riser according to an embodiment of the invention connected between a production vessel and a sub-sea facility,
  • Fig. 2 shows a connector for connecting an end pipe section of a riser to the central composite conduit section of the riser
  • Fig. 3 is a cross section of the central composite conduit section of a riser according to an embodiment of the invention, taken along the line A-A of Fig. 2.
  • FIG. 1 shows a riser system 10 for connection between a floating unit 12 and a sub-sea unit 14 located on the sea floor 18.
  • the floating unit 12 is, in the illustrated example, a floating production unit for processing well fluid, by removing gas and water for example, from a sub-sea well assembly 14, and conveying the fluid to an export pipeline or offloading to another vessel, such as an oil tanker, whereby the riser system 10 transports fluid from the sub-sea unit 14 to the floating unit 12.
  • the floating production unit 12 may alternatively, or also, have equipment for injecting water or gas into a sub-sea well 14 for production purposes, whereby the riser 10 transports fluid from the floating unit 12 to the sub-sea unit 14.
  • a riser 10 comprises an upper metallic end pipe section 20, such as a continuous welded or threaded steel pipe, a central composite section 22, and a lower metallic end pipe section 24.
  • Upper end pipe section 20 has a length of about 50 to 600 m and is negatively buoyant. Alternately, part or all of upper end pipe section 20 and/or the lower end pipe section 24 could be formed from a non-bonded flexible pipe.
  • the lower end pipe section 24 connects to a sub-sea facility 14 on the sub-sea floor 18, such as a manifold or production/injection tree, at a location horizontally offset from production vessel 12.
  • the riser 10 is constructed to assume a compliant configuration when installed. Movement of the floating unit is accommodated by the flexibility of the upper end pipe section, i.e.
  • Central composite conduit section 22 constitutes most of the length of the riser 10, and is much longer than upper end pipe section 20 or the lower end pipe section 24. For example, the distance from vessel 12 to sub-sea facility 14 could be 2,000 meters with the central composite conduit section 22 being 1,500 meters or more in length. Central composite conduit section 22 is preferably neutral or slightly negative in buoyancy.
  • Lower end pipe section 24 is utilized in environments where flexibility is required to connect the lower end of riser 10 to a sub-sea facility 14 or where touch down compression may occur.
  • central composite conduit section 22 may be connected directly to sub-sea facility 14.
  • Lower end pipe section 24 may include a metal tapered stress joint if necessary.
  • Lower end pipe section 24 could also comprise non- bonded flexible pipe of a type described above.
  • Lower section 21 could also comprise a continuous steel pipe having a similar structure to upper end pipe section 20. As shown in Fig. 1, since riser 10 has a compliant configuration, a portion of lower end pipe section 24 will likely lie on the sea floor 18.
  • Lower end pipe section 24 is also much shorter than the length of central composite conduit section 22. For example, lower section 24 is preferably from about 50 to 100 meters in length.
  • each, end pipe section 20, 24 can be connected to the composite conduit 22 onshore and stored on a reel for installation purposes or the end pipe section(s) could be wound on a separate reel and connected to the composite conduit during installation.
  • the latter method would be more suitable when the end pipe section(s) comprise (s) a metallic pipe.
  • Figure 2 shows a flange-type connector 26, made of metal for example, for connecting a composite conduit 22 to an upper end pipe section 20 and/or a lower end pipe section 24.
  • the connector 26 is secured by a plurality of bolts 28.
  • the flange-type connector 26 could be a standard API. Alternatively, a more compact flange could be used, but also a flex joint depending on the environment.
  • Upper end pipe section 20 has a conventional floater connection, for example, which couples the riser 10 to the floating production unit 12.
  • the floater connection could include a flex joint or a flange connection with a bend stiffener.
  • Figure 3 shows a cross section of the central composite conduit section of the riser system (outer protective sheath not shown) .
  • the conduit 22 has a fluid impervious inner liner 30, having an inner diameter typically ranging from about 15-30 cm (6-12 inches) , which is continuous and extends from its upper end 20 to its lower end 24.
  • Inner liner 30 may be formed from a conventional thermoplastic material, such as polyamides, polyvinylidene fluoride (PVDF) , polyphenylene sulfide (PPS) or polyether ether ketone (PEEK) , preferably having a thickness between 4-7 mm.
  • PVDF polyvinylidene fluoride
  • PPS polyphenylene sulfide
  • PEEK polyether ether ketone
  • thermoplastic fibre reinforced tape 32 such as carbon fibre or glass fibre, is wrapped around liner 30 in various angles depending on loads and environment.
  • the thermoplastic fibre reinforced tape 32 is then bonded to the liner 30 or tape substrate, by heating for example, which forms a high strength, lightweight tubular member.
  • the upper and/or lower ends of the liner 30 are terminated in a composite-metallic interface connector 26.
  • At least one reinforcing layer can be added which are built up of unidirectional continuous fibres of carbon, glass, or aramid, which are embedded in thermoplastic resins .
  • Typical thermoplastic resins are the following: polyamides (PA, PPA) polysulphone (PSU) , polyether imide (PEI) and polyether sulphone (PES)or polyether ether ketone (PEEK) .
  • PA, PPA polyamides
  • PSU polysulphone
  • PEI polyether imide
  • PES polyether sulphone
  • PEEK polyether ether ketone
  • the invention is of course not in any way restricted to the preferred embodiments described above. On the contrary, many possibilities to modifications thereof will be apparent to a person with ordinary skill in the art without departing from the basic idea of the invention such as defined in the appended claims.
  • said at least one end pipe section may be integrally formed with the composite conduit rather than connecting said at least one end pipe section to the composite conduit.

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  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • Mechanical Engineering (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Earth Drilling (AREA)
  • Rigid Pipes And Flexible Pipes (AREA)
  • Quick-Acting Or Multi-Walled Pipe Joints (AREA)
  • Joints Allowing Movement (AREA)

Abstract

A hybrid riser system (10) for connection between a floating unit (12) and a sub-sea unit (14) that is located at the sea floor (18). The riser system (10) comprises a composite conduit (22) for transporting a fluid between said floating (12) and sub-sea units (14) and at least one end pipe section (20,24) that is adapted to be connected between the floating (12) and/or the subsea unit (14) and the composite conduit (22). Said at least one end pipe section (20,24) comprises a metallic pipe or a non-bonded flexible pipe.

Description

A HYBRID RISER SYSTEM
TECHNICAL FIELD
The present invention concerns a hybrid riser system for connection between a floating unit, such as a floating vessel or a production unit for oil and gas production, and a sub-sea unit, such as a sub-sea well facility, located at the sea floor. The expression "riser system" is intended to mean a pipe or a string adapted for transport of fluids, i.e. liquids and gases or mixtures thereof, and in particular hydrocarbons, such as oil and/or gas or injection fluids, such as methanol or water, between the floating and sub-sea units.
BACKGROUND OF THE INVENTION Riser systems include a conduit through which various fluids are transported from a sub-sea facility located at the sea floor to a floating platform or vessel on the sea surface, such as a surface production and/or storage facility or vice versa. The vessel or floating platform is constantly exposed to movements, caused by waves, winds and surface and underwater currents, for example. The floating platform is therefore continuously subjected to forces causing it and the riser system connected thereto to movements. Riser systems must be able to withstand the forces exerted on them without failure due to fatigue or the like. If part of a riser undergoes fatigue or becomes damaged to the point of failure or possible failure, at least part of the riser system has to be replaced, which is both expensive and may be difficult and time consuming to accomplish. When using light weight riser pipes e.g. composite, additional weight may be required added to the upper part of the riser that is connected to the floating platform or vessel to ensure that the pipe is in tension, however this additional weight compresses the riser, adversely affects fluid flow through the riser system and increases manufacturing and installation costs.
US patent no. 5,639,187 discloses a marine riser system that combines rigid, steel catenary risers with flexible flow lines . The expression "catenary" meaning the curve assumed by a cord of uniform density and cross section that is perfectly flexible but not capable of being stretched and that hangs freely from two fixed points . The steel catenary risers are curved upward through the water in a gentle catenary path to a large, submerged buoy, which, in turn, is moored to the sea bottom by tension leg tether lines at a depth below the turbulence zone of the water. The buoy maintains the rigid steel catenary risers in a substantially vertical position in the water. Flexible flow lines (commonly called jumpers) are fluidly connected to the steel catenary risers at the buoy and extend upward through the turbulence zone to the surface.
A disadvantage with such a system is that a large buoy and clamping means are needed to support the heavy steel risers. Mooring the buoy at a predetermined depth also requires careful planning and engineering, which makes the design and manufacture of the buoy complex, time consuming and expensive. Furthermore, the equipment required for mooring the buoy further increases manufacturing and installation costs.
SUMMARY OF THE INVENTION
An object of the present invention is to provide a hybrid riser system for connection between a floating unit, and a sub-sea unit that is located at the sea floor, which can withstand or accommodate forces exerted thereon due to movements, such as those caused by the movement of the floating unit. This object is achieved by a riser system that includes a composite conduit for transporting a fluid, i.e. liquid or gas, between said floating and sub-sea units. The term "composite conduit" refers to a bonded pipe having an inner liner and an outer protective sheath and optionally at least one reinforcing layer, such as the one described in international application WO 99/67561. WO 99/67561 describes a flexible riser comprising composite material. The riser comprises an inner liner of thermoplastic material, an intermediate reinforced polymer multi layer component and an outer thermoplastic liner. The inner liner is continuously bonded to the intermediate, multi layer component, which is in turn continuously bonded to the outer liner. The inventive riser system also comprises at least one end pipe section that is adapted to be connected between the floating and/or the subsea unit and the composite conduit. Said at least one end pipe section comprises a metallic pipe, i.e. a pipe made of or containing metal, or a non-bonded flexible pipe.
The term "non-bonded" is intended to mean a pipe consisting of a plurality of layers, comprising a metal or polymer for example, which are not bonded to each other and therefore free to move independently of one another. A non-bonded flexible pipe or a metallic pipe provides an end pipe section of increased strength and weight which will not be deflected and bent like a composite conduit and thus eliminates the need for providing the riser system with additional weight.
The hybrid riser system according to the invention has a light and almost buoyant composite conduit section, which implies less load impact on the floating unit. At least one end of the riser system, i.e. the end that is connected to the floating unit and/or the end that is connected to the sub-sea unit, is provided with an end pipe section that can better withstand or accommodate the forces exerted on the riser system in the vicinity of the floating and/or sub-sea unit where the riser is deflected and bent the most. The inventive riser system reduces top tension, touchdown curvature, touchdown compression and hold-back tension and is suitable for use at high hydrostatic pressures in deep and ultra deep water.
According to an embodiment of the invention the length of the end pipe section that is connected to the floating unit is approximately 50-600 m. According to another embodiment of the invention the length of the end pipe section that is connected to the subsea unit is approximately 50-100 m.
According to a further embodiment of the invention the length of the composite conduit is about 1000-1500 m or longer.
According to a yet further embodiment of the invention said at least one end pipe section is arranged to be negatively buoyant .
According to an embodiment of the invention the composite conduit is constituted by a single, continuous conduit i.e. the composite conduit is connected to at least one end pipe section but there are no other connections along the length of the riser.
According to an embodiment of the invention the riser is adapted to assume a compliant configuration when installed e.g. free hanging (catenary) , Lazy or step S or wave.
According to another embodiment of the invention the composite conduit comprises a bonded pipe having an inner liner and an outer protective sheath, and optionally at least one reinforcing layer.
According to a further embodiment of the invention the composite conduit is flexible enough to be spooled onto a reel with a hub radius of about 4500-8500 mm. According to an embodiment of the invention the composite conduit and said at least one end pipe section have an internal diameter in the range of about 10-40 cm (4-16 inches) .
According to a further embodiment of the invention the floating unit is a production or storage unit or a platform or vessel, the sub-sea unit is a sub-sea well facility, whereby the riser system is adapted for transport of fluids, in particular hydrocarbons, such as oil and/or gas, or injection fluids, such as methanol or water, between the floating and subsea units .
DETAILED DESCRIPTION OF EMBODIMENTS The present invention will hereinafter be further explained by means of non-limiting examples with reference to the appended figures where:
Fig. 1 is a schematic view of a riser according to an embodiment of the invention connected between a production vessel and a sub-sea facility,
Fig. 2 shows a connector for connecting an end pipe section of a riser to the central composite conduit section of the riser, Fig. 3 is a cross section of the central composite conduit section of a riser according to an embodiment of the invention, taken along the line A-A of Fig. 2.
It should be noted that the drawings have not been drawn to scale and that the dimensions of certain features have been exaggerated for the sake of clarity. DETAILED DESCRIPTION OF EMBODIMENTS
Figure 1 shows a riser system 10 for connection between a floating unit 12 and a sub-sea unit 14 located on the sea floor 18. The floating unit 12 is, in the illustrated example, a floating production unit for processing well fluid, by removing gas and water for example, from a sub-sea well assembly 14, and conveying the fluid to an export pipeline or offloading to another vessel, such as an oil tanker, whereby the riser system 10 transports fluid from the sub-sea unit 14 to the floating unit 12. The floating production unit 12 may alternatively, or also, have equipment for injecting water or gas into a sub-sea well 14 for production purposes, whereby the riser 10 transports fluid from the floating unit 12 to the sub-sea unit 14.
A riser 10 comprises an upper metallic end pipe section 20, such as a continuous welded or threaded steel pipe, a central composite section 22, and a lower metallic end pipe section 24. Upper end pipe section 20 has a length of about 50 to 600 m and is negatively buoyant. Alternately, part or all of upper end pipe section 20 and/or the lower end pipe section 24 could be formed from a non-bonded flexible pipe. The lower end pipe section 24 connects to a sub-sea facility 14 on the sub-sea floor 18, such as a manifold or production/injection tree, at a location horizontally offset from production vessel 12. The riser 10 is constructed to assume a compliant configuration when installed. Movement of the floating unit is accommodated by the flexibility of the upper end pipe section, i.e. the non-bonded flexible pipe or metallic pipe. Tensioning means are not required to maintain tension in the riser 10. Tension is obtained through the upper end pipe section 20 and buoyancy is optionally applied to the central composite conduit section 22 in order to avoid compression in the riser string 10. Central composite conduit section 22 constitutes most of the length of the riser 10, and is much longer than upper end pipe section 20 or the lower end pipe section 24. For example, the distance from vessel 12 to sub-sea facility 14 could be 2,000 meters with the central composite conduit section 22 being 1,500 meters or more in length. Central composite conduit section 22 is preferably neutral or slightly negative in buoyancy.
Lower end pipe section 24 is utilized in environments where flexibility is required to connect the lower end of riser 10 to a sub-sea facility 14 or where touch down compression may occur. In some environments, central composite conduit section 22 may be connected directly to sub-sea facility 14. Lower end pipe section 24 may include a metal tapered stress joint if necessary. Lower end pipe section 24 could also comprise non- bonded flexible pipe of a type described above. Lower section 21 could also comprise a continuous steel pipe having a similar structure to upper end pipe section 20. As shown in Fig. 1, since riser 10 has a compliant configuration, a portion of lower end pipe section 24 will likely lie on the sea floor 18. Lower end pipe section 24 is also much shorter than the length of central composite conduit section 22. For example, lower section 24 is preferably from about 50 to 100 meters in length.
The, or each, end pipe section 20, 24 can be connected to the composite conduit 22 onshore and stored on a reel for installation purposes or the end pipe section(s) could be wound on a separate reel and connected to the composite conduit during installation. The latter method would be more suitable when the end pipe section(s) comprise (s) a metallic pipe.
Figure 2 shows a flange-type connector 26, made of metal for example, for connecting a composite conduit 22 to an upper end pipe section 20 and/or a lower end pipe section 24. The connector 26 is secured by a plurality of bolts 28. The flange-type connector 26 could be a standard API. Alternatively, a more compact flange could be used, but also a flex joint depending on the environment. Upper end pipe section 20 has a conventional floater connection, for example, which couples the riser 10 to the floating production unit 12. The floater connection could include a flex joint or a flange connection with a bend stiffener.
Figure 3 shows a cross section of the central composite conduit section of the riser system (outer protective sheath not shown) . According to an embodiment of the invention the conduit 22 has a fluid impervious inner liner 30, having an inner diameter typically ranging from about 15-30 cm (6-12 inches) , which is continuous and extends from its upper end 20 to its lower end 24. Inner liner 30 may be formed from a conventional thermoplastic material, such as polyamides, polyvinylidene fluoride (PVDF) , polyphenylene sulfide (PPS) or polyether ether ketone (PEEK) , preferably having a thickness between 4-7 mm. A thermoplastic fibre reinforced tape 32, such as carbon fibre or glass fibre, is wrapped around liner 30 in various angles depending on loads and environment. The thermoplastic fibre reinforced tape 32 is then bonded to the liner 30 or tape substrate, by heating for example, which forms a high strength, lightweight tubular member. The upper and/or lower ends of the liner 30 are terminated in a composite-metallic interface connector 26.
At least one reinforcing layer can be added which are built up of unidirectional continuous fibres of carbon, glass, or aramid, which are embedded in thermoplastic resins . Typical thermoplastic resins are the following: polyamides (PA, PPA) polysulphone (PSU) , polyether imide (PEI) and polyether sulphone (PES)or polyether ether ketone (PEEK) . The invention is of course not in any way restricted to the preferred embodiments described above. On the contrary, many possibilities to modifications thereof will be apparent to a person with ordinary skill in the art without departing from the basic idea of the invention such as defined in the appended claims. For example, said at least one end pipe section may be integrally formed with the composite conduit rather than connecting said at least one end pipe section to the composite conduit.

Claims

1. A hybrid riser system (10) for connection between a floating unit (12) and a sub-sea unit (14) that is located at the sea floor (18) , characterized in that it comprises a composite conduit (22) for transporting a fluid between said floating (12) and sub-sea units (14) and at least one end pipe section (20,24) that is adapted to be connected between the floating (12) and/or the sub-sea unit (14) and the composite conduit (22) , whereby said at least one end pipe section (20,24) comprises a metallic pipe or a non-bonded flexible pipe.
2. A riser system (10) according to claim 1, characterized in that the length of the end pipe section (20) that is connected to the floating unit (12) is approximately 50-600 m.
3. A riser system (10) according to claims 1-2, characterized in that the length of the end pipe section (24) that is connected to the sub-sea unit is approximately 50-100 m.
4. A riser system (10) according to claims 1-3, characterized in that the length of the composite conduit (22) is about 1000-1500 m or longer.
5. A riser system (10) according to claims 1-4, characterized in that said at least one end pipe section (20, 24) is arranged to be negatively buoyant.
6. A riser system (10) according to any of the preceding claims, characterized in that the composite conduit (22) is constituted by a single, continuous composite conduit.
7. A riser system (10) according to any of the preceding claims, characterized in that it is adapted to assume a compliant configuration when installed.
8. A riser system (10) according to any of the preceding claims, characterized in that the composite conduit (22) comprises a bonded pipe having an inner liner (30) and an outer protective sheath, and optionally at least one reinforcing layer (32) .
9. A riser system (10) according to any of the preceding claims, characterized in that the composite conduit (22) is flexible enough to be spooled onto a reel with a hub radius of about 4500-8500 mm.
10. A riser system (10) according to any of the preceding claims, characterized in that the composite conduit (22) and said at least one end pipe section (20,24) have an internal diameter in the range of about 10-40 cm.
11. A riser system (10) according to any of the preceding claims, characterized in that the floating unit (12) is a production or storage unit or a platform or vessel, and the sub-sea unit (14) is a sub-sea well facility, wherein the riser system (10) is adapted for transport of fluids, in particular hydrocarbons, such as oil and/or gas, or injection fluids, such as methanol or water, between the floating (12) and sub-sea (14) units.
PCT/IB2005/003638 2004-12-01 2005-12-01 A hybrid riser system WO2006059220A2 (en)

Priority Applications (5)

Application Number Priority Date Filing Date Title
EP05823765.2A EP1817475B1 (en) 2004-12-01 2005-12-01 A hybrid riser system
ES05823765T ES2729828T3 (en) 2004-12-01 2005-12-01 A hybrid lifting system
DK05823765.2T DK1817475T3 (en) 2004-12-01 2005-12-01 HYBRID STIGROSE SYSTEM
BRPI0520284-1A BRPI0520284B1 (en) 2004-12-01 2005-12-01 HYBRID RISER SYSTEM
NO20072611A NO20072611L (en) 2004-12-01 2007-05-24 A hybrid riser system

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US63224504P 2004-12-01 2004-12-01
US60/632,245 2004-12-01

Publications (3)

Publication Number Publication Date
WO2006059220A2 true WO2006059220A2 (en) 2006-06-08
WO2006059220A3 WO2006059220A3 (en) 2006-07-27
WO2006059220B1 WO2006059220B1 (en) 2006-10-12

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PCT/IB2005/003638 WO2006059220A2 (en) 2004-12-01 2005-12-01 A hybrid riser system

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Country Link
EP (1) EP1817475B1 (en)
BR (1) BRPI0520284B1 (en)
DK (1) DK1817475T3 (en)
ES (1) ES2729828T3 (en)
NO (1) NO20072611L (en)
WO (1) WO2006059220A2 (en)

Cited By (11)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
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WO2011128201A1 (en) * 2010-04-13 2011-10-20 Evonik Degussa Gmbh Flexible tube having high temperature resistance
WO2013182196A1 (en) * 2012-06-06 2013-12-12 National Oilwell Varco Denmark I/S A riser and an offshore system
GB2504065A (en) * 2012-06-29 2014-01-22 Statoil Petroleum As Subsea flexible riser
US8865281B2 (en) 2008-09-19 2014-10-21 Solvay Advanced Polymers, L.L.C. Flexible pipes made of a polyaryletherketone/perfluoropolymer composition
US9909368B2 (en) 2008-10-09 2018-03-06 Ge Oil & Gas Uk Limited Flexible pipe and a method for providing buoyancy to a jumper or riser assembly
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WO2020128907A1 (en) 2018-12-18 2020-06-25 Eni S.P.A. Composite tubular element and relevant manufacturing method
WO2022269024A1 (en) 2021-06-25 2022-12-29 Technip N-Power Thermoplastic composite hose for transporting fluid and flexible pipe comprising same

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Cited By (20)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2008125807A1 (en) * 2007-04-17 2008-10-23 C.S. Technical Services Limited Tubular conduit
US8865281B2 (en) 2008-09-19 2014-10-21 Solvay Advanced Polymers, L.L.C. Flexible pipes made of a polyaryletherketone/perfluoropolymer composition
US9909368B2 (en) 2008-10-09 2018-03-06 Ge Oil & Gas Uk Limited Flexible pipe and a method for providing buoyancy to a jumper or riser assembly
WO2011117607A1 (en) 2010-03-25 2011-09-29 Victrex Manufacturing Limited Method of prudicng a composite pipe and such a composite pipe
US10428979B2 (en) 2010-03-25 2019-10-01 Victrex Manufacturing Limited Method of producing a composite pipe and such a composite pipe
US11504939B2 (en) 2010-04-13 2022-11-22 Evonik Operations Gmbh Flexible tube having high temperature resistance
WO2011128197A1 (en) * 2010-04-13 2011-10-20 Evonik Degussa Gmbh Flexible pipe having a diffusion barrier
WO2011128201A1 (en) * 2010-04-13 2011-10-20 Evonik Degussa Gmbh Flexible tube having high temperature resistance
CN102821939A (en) * 2010-04-13 2012-12-12 赢创德固赛有限公司 Flexible tube having high temperature resistance
US9303463B2 (en) 2012-06-06 2016-04-05 National Oilwell Varco Denmark I/S Riser and an offshore system
EP2859173A4 (en) * 2012-06-06 2016-03-23 Nat Oilwell Varco Denmark Is A riser and an offshore system
WO2013182196A1 (en) * 2012-06-06 2013-12-12 National Oilwell Varco Denmark I/S A riser and an offshore system
GB2504065A (en) * 2012-06-29 2014-01-22 Statoil Petroleum As Subsea flexible riser
WO2019007975A3 (en) * 2017-07-03 2019-03-07 Subsea 7 Norway As Offloading hydrocarbons from subsea fields
US11421486B2 (en) 2017-07-03 2022-08-23 Subsea 7 Norway As Offloading hydrocarbons from subsea fields
AU2018296421B2 (en) * 2017-07-03 2024-03-21 Subsea 7 Norway As Offloading hydrocarbons from subsea fields
WO2020128907A1 (en) 2018-12-18 2020-06-25 Eni S.P.A. Composite tubular element and relevant manufacturing method
US11802639B2 (en) 2018-12-18 2023-10-31 Eni S.P.A. Composite tubular element and relevant manufacturing method
WO2022269024A1 (en) 2021-06-25 2022-12-29 Technip N-Power Thermoplastic composite hose for transporting fluid and flexible pipe comprising same
FR3124426A1 (en) 2021-06-25 2022-12-30 Technip N-Power Thermoplastic composite pipe for the transport of fluid and flexible pipe comprising it

Also Published As

Publication number Publication date
BRPI0520284A2 (en) 2009-04-28
EP1817475B1 (en) 2019-05-08
ES2729828T3 (en) 2019-11-06
BRPI0520284B1 (en) 2017-07-04
EP1817475A2 (en) 2007-08-15
EP1817475A4 (en) 2012-09-05
WO2006059220B1 (en) 2006-10-12
NO20072611L (en) 2007-08-30
WO2006059220A3 (en) 2006-07-27
DK1817475T3 (en) 2019-06-24

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