EP1817475B1 - Systeme hybride de tube prolongateur - Google Patents

Systeme hybride de tube prolongateur Download PDF

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Publication number
EP1817475B1
EP1817475B1 EP05823765.2A EP05823765A EP1817475B1 EP 1817475 B1 EP1817475 B1 EP 1817475B1 EP 05823765 A EP05823765 A EP 05823765A EP 1817475 B1 EP1817475 B1 EP 1817475B1
Authority
EP
European Patent Office
Prior art keywords
riser system
composite conduit
end pipe
sea
sub
Prior art date
Legal status (The legal status 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 status listed.)
Active
Application number
EP05823765.2A
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German (de)
English (en)
Other versions
EP1817475A4 (fr
EP1817475A2 (fr
Inventor
Lars Slagsvold
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Baker Hughes Energy Technology UK Ltd
Original Assignee
GE Oil and Gas UK Ltd
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Publication date
Application filed by GE Oil and Gas UK Ltd filed Critical GE Oil and Gas UK Ltd
Publication of EP1817475A2 publication Critical patent/EP1817475A2/fr
Publication of EP1817475A4 publication Critical patent/EP1817475A4/fr
Application granted granted Critical
Publication of EP1817475B1 publication Critical patent/EP1817475B1/fr
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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. 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.
  • 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.
  • 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.
  • US patent no. 6,364,022 B1 discloses a hybrid pipe for deep water comprising a metallic rigid central part.
  • 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.
  • a riser system that includes a flexible 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.
  • the riser system is adapted to assume a compliant flexible configuration when installed.
  • 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.
  • a hybrid riser system for connection between a floating unit and a sub-sea unit as described in claim 1.
  • 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.
  • 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 system has a light and almost buoyant composite conduit section so as to assume a neutral or slightly negative buoyancy.
  • the riser is adapted to assume a compliant configuration when installed e.g. free hanging (catenary), Lazy S or wave, or Steep S or wave.
  • the composite conduit further comprises an outer protective sheath, and optionally at least one reinforcing layer.
  • the upper and/or lower ends of the composite conduit section are terminated in a composite-metallic interface connector.
  • 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 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.
  • 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 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, 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. According to the invention, all of upper end pipe section 20 and the lower end pipe section 24 are 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. As shown in Fig. 1 , the installed riser 10 assumes a Lazy wave configuration.
  • Movement of the floating unit is accommodated by the flexibility of the upper end pipe section, i.e. the metallic non-bonded flexible 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.
  • 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.
  • Lower end pipe section 24 may include a metal tapered stress joint if necessary.
  • Lower end pipe section 24 comprises non-bonded flexible pipe of a type described above. 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.
  • 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.
  • 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.
  • 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 composite conduit section 22 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).

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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)

Claims (15)

  1. Système de colonne montante hybride (10) pour connexion entre une unité flottante (12) et une unité sous-marine (14) qui est située au niveau du fond marin (18), le système comprenant :
    un conduit composite flexible (22) destiné à transporter un fluide entre lesdites unité flottante (12) et unité sous-marine (14) moyennant quoi ledit conduit composite comprend un tuyau lié possédant un chemisage interne (30) ;
    une section de tuyau d'extrémité (20) connectée au conduit composite, ladite section de tuyau d'extrémité (20) étant adaptée pour être connectée entre l'unité flottante (12) et le conduit composite ;
    et une section de tuyau d'extrémité supplémentaire (24) connectée au conduit composite, ladite section de tuyau d'extrémité (24) étant adaptée pour être connectée entre l'unité sous-marine (14) et le conduit composite (22), moyennant quoi lesdites sections de tuyau d'extrémité (20, 24) comprennent un tuyau flexible non-lié métallique, le tuyau flexible non-lié métallique comprenant une pluralité de couches métalliques, qui ne sont pas liées les unes aux autres et sont libres de se déplacer indépendamment les unes des autres, et dans lequel le système de colonne montante est adapté pour prendre une configuration flexible conforme une fois installé.
  2. Système de colonne montante selon la revendication 1, caractérisé en ce que lesdites sections de tuyau d'extrémité (20, 24) sont agencées pour avoir une flottabilité négative.
  3. Système de colonne montante selon la revendication 1 ou 2, caractérisé en ce que le conduit composite (22) est constitué d'un conduit composite unique, continu.
  4. Système de colonne montante selon l'une quelconque des revendications 1 à 3, caractérisé en ce que la section de conduit composite (22) a une flottabilité neutre ou négative.
  5. Système de colonne montante selon la revendication 1, caractérisé en ce que ladite configuration conforme est une configuration caténaire.
  6. Système de colonne montante selon la revendication 1, caractérisé en ce que ladite configuration conforme est une configuration Lazy S ou Lazy Wave.
  7. Système de colonne montante selon la revendication 1, caractérisé en ce que ladite configuration conforme est une configuration Steep S ou Steep Wave.
  8. Système de colonne montante selon l'une quelconque des revendications précédentes, caractérisé en ce que le conduit composite (22) comprend en outre une gaine de protection externe, et en option au moins une couche de renfort (32).
  9. Système de colonne montante selon l'une quelconque des revendications précédentes, caractérisé en ce que les extrémités supérieure et/ou inférieure de la section de conduit composite (22) sont terminées dans un connecteur d'interface composite- métallique (26).
  10. Système de colonne montante selon l'une quelconque des revendications précédentes, caractérisé en ce que le conduit composite (22) est suffisamment flexible pour être bobiné sur un touret ayant un rayon de moyeu d'environ 4500 à 8500 mm.
  11. Système de colonne montante selon l'une quelconque des revendications précédentes, caractérisé en ce que le conduit composite (22) et lesdites sections de tuyau d'extrémité (20, 24) ont un diamètre interne dans la plage d'environ 10 à 40 cm.
  12. Système de colonne montante selon l'une quelconque des revendications précédentes, caractérisé en ce que la longueur de la section de tuyau d'extrémité (20) qui est adapté pour être connecté entre l'unité flottante et le conduit composite (12) est approximativement 50 à 600 m.
  13. Système de colonne montante selon l'une quelconque des revendications précédentes, caractérisé en ce que la longueur de la section de tuyau d'extrémité (24) qui est adaptée pour être connectée entre l'unité sous-marine et le conduit composite est approximativement 50 à 100 m.
  14. Système de colonne montante selon l'une quelconque des revendications précédentes, caractérisé en ce que la longueur du conduit composite (22) est d'environ 1000 à 1500 m ou plus longue.
  15. Système de colonne montante selon l'une quelconque des revendications précédentes, caractérisé en ce que l'unité flottante (12) est une unité ou une plateforme ou un navire de production ou de stockage, et l'unité sous-marine (14) est une installation de puits sous-marin, dans lequel le système de colonne montante (10) est adapté pour le transport de fluides, en particulier d'hydrocarbures, tels que du pétrole et/ou gaz, ou des fluides d'injection, tels que du méthanol ou de l'eau, entre les unités flottante (12) et sous-marine (14).
EP05823765.2A 2004-12-01 2005-12-01 Systeme hybride de tube prolongateur Active EP1817475B1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US63224504P 2004-12-01 2004-12-01
PCT/IB2005/003638 WO2006059220A2 (fr) 2004-12-01 2005-12-01 Systeme hybride de tube prolongateur

Publications (3)

Publication Number Publication Date
EP1817475A2 EP1817475A2 (fr) 2007-08-15
EP1817475A4 EP1817475A4 (fr) 2012-09-05
EP1817475B1 true EP1817475B1 (fr) 2019-05-08

Family

ID=36565407

Family Applications (1)

Application Number Title Priority Date Filing Date
EP05823765.2A Active EP1817475B1 (fr) 2004-12-01 2005-12-01 Systeme hybride de tube prolongateur

Country Status (6)

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

Families Citing this family (11)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2008125807A1 (fr) * 2007-04-17 2008-10-23 C.S. Technical Services Limited Conduite tubulaire
EP2328951B1 (fr) 2008-09-19 2018-07-11 Solvay Specialty Polymers USA, LLC. Tuyaux flexibles constitués d'une composition de poly(aryl-éther-cétone)/polymère perfluoré
GB0818500D0 (en) 2008-10-09 2008-11-19 Wellstream Int Ltd Flexible pipe
GB201005035D0 (en) 2010-03-25 2010-05-12 Victrex Mfg Ltd Pipe
DE102010003920A1 (de) * 2010-04-13 2011-10-13 Evonik Degussa Gmbh Flexibles Rohr mit höherer Temperaturbeständigkeit
DE102010003917A1 (de) * 2010-04-13 2011-10-13 Evonik Degussa Gmbh Flexibles Rohr mit Diffusionssperre
AU2013271027B2 (en) * 2012-06-06 2017-04-06 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
US11421486B2 (en) 2017-07-03 2022-08-23 Subsea 7 Norway As Offloading hydrocarbons from subsea fields
EP3898223B1 (fr) 2018-12-18 2023-01-25 ENI S.p.A. Élément tubulaire composite et procédé de fabrication pertinent
FR3124426B1 (fr) 2021-06-25 2023-06-09 Technip N Power Tuyau composite thermoplastique pour le transport de fluide et conduite flexible le comprenant

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Publication number Priority date Publication date Assignee Title
FR2507672A1 (fr) * 1981-06-12 1982-12-17 Inst Francais Du Petrole Colonne montante pour les grandes profondeurs d'eau
FR2616858B1 (fr) * 1987-06-18 1989-09-01 Inst Francais Du Petrole Element a raideur variable pour pied de colonne de transfert
NO981701D0 (no) * 1998-04-16 1998-04-16 Kvaerner Oilfield Prod As Sammensatt hybridstiger÷r
NO314958B1 (no) 1998-06-24 2003-06-16 Wellstream Int Ltd Fleksibelt, polymert, komposittror slik som et fleksibelt stigeror
FR2790814B1 (fr) * 1999-03-09 2001-04-20 Coflexip Conduite hybride pour grande profondeur
NO312483B1 (no) * 1999-05-14 2002-05-13 Offtech Invest As Fleksibelt, lettvekts komposittrör for höytrykks olje- og gassanvendelser

Non-Patent Citations (1)

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Title
None *

Also Published As

Publication number Publication date
DK1817475T3 (da) 2019-06-24
WO2006059220A2 (fr) 2006-06-08
WO2006059220A3 (fr) 2006-07-27
WO2006059220B1 (fr) 2006-10-12
BRPI0520284A2 (pt) 2009-04-28
NO20072611L (no) 2007-08-30
EP1817475A4 (fr) 2012-09-05
BRPI0520284B1 (pt) 2017-07-04
ES2729828T3 (es) 2019-11-06
EP1817475A2 (fr) 2007-08-15

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