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WO2011018713A2 - Appareil à tube prolongateur et son procédé d'installation - Google Patents

Appareil à tube prolongateur et son procédé d'installation Download PDF

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Publication number
WO2011018713A2
WO2011018713A2 PCT/IB2010/002437 IB2010002437W WO2011018713A2 WO 2011018713 A2 WO2011018713 A2 WO 2011018713A2 IB 2010002437 W IB2010002437 W IB 2010002437W WO 2011018713 A2 WO2011018713 A2 WO 2011018713A2
Authority
WO
WIPO (PCT)
Prior art keywords
conduit
tensioned
suspended
marine riser
conduits
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.)
Ceased
Application number
PCT/IB2010/002437
Other languages
English (en)
Other versions
WO2011018713A3 (fr
Inventor
Jean-Luc Legras
Jean-Pierre Branchut
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.)
Acergy France SAS
Original Assignee
Acergy France SAS
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 Acergy France SAS filed Critical Acergy France SAS
Publication of WO2011018713A2 publication Critical patent/WO2011018713A2/fr
Publication of WO2011018713A3 publication Critical patent/WO2011018713A3/fr
Anticipated expiration legal-status Critical
Ceased legal-status Critical Current

Links

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
    • 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
    • E21B17/012—Risers with buoyancy elements
    • 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
    • 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
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/01—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations

Definitions

  • the present invention relates to a marine riser apparatus to facilitate hydrocarbon production at sea, and also to a method for installing such a riser apparatus at a production site at sea.
  • Hybrid Riser Towers are known and form part of the so-called hybrid riser, having an upper portion, typically known as a "flexible jumper", made of flexible conduit which are suitable for deep and ultra-deep water field development.
  • a flexible jumper made of flexible conduit which are suitable for deep and ultra-deep water field development.
  • HRT Hybrid Riser Tower
  • SLORs Single Line Offset Risers
  • US6082391 Another known solution is to use a number of Single Line Offset Risers (SLORs), as exemplified in US6082391 , being essentially monobore HRTs.
  • SLORs Single Line Offset Risers
  • a problem with these structures is that for a cluster of wells, a large number of these structures are required, one for each production line, each injection line and each gas line. This means that each structure needs to be placed too close to adjacent structures resulting in the increased risk of each structure getting in the way of or interfering with others, due to wake shielding and wake instability.
  • the aim of the present invention is to provide an alternative form of riser system in which some or all of the above mentioned problems are overcome or in the very least alleviated.
  • the novel system can be installed offshore using a conventional installation vessel. It should be cost-effective. It should also eliminate or at least reduce clashing of risers.
  • most of the riser installation operational steps can be performed before installation of the floating production unit to which the risers are to be connected.
  • a marine riser apparatus comprising at least one tensioned conduit extending from the seabed toward the surface, including a lower end attached to an anchoring point on the seabed and has an upper end supported by a buoyancy arrangement so as to maintain the conduit in tension with a substantially vertical orientation, and further including one or more further conduits suspended from an upper portion of said marine riser apparatus and which also extend towards the seabed, for attachment to a wellhead, or a suitable pipe termination module such as a pipeline end terminator (PLET).
  • the buoyancy arrangement takes the form of one or more buoyancy tanks, although other arrangements are feasible such as syntactic foam blocks that surround and extend along the primary conduit thereby placing it in tension and in a substantially vertically orientation.
  • At least some of said one or more suspended conduits may take a catenary configuration.
  • at least some of said one or more suspended conduits may comprise buoyancy so as to take a different configuration such as a modified catenary. Examples of different configurations include the Lazy Wave and similar configurations.
  • Said at least one tensioned conduit may comprise an anchoring device anchoring it to the seabed.
  • the tensioned conduit may be tethered to the anchoring device by a suitable tether such as a chain or cable, in an alternative embodiment the lower end of the tensioned conduit is attached directly to the foundation module provided on the seabed, thus removing the requirement for further connections between pipe and chain/cable thereby reducing the mass of the system as a whole, reducing cost and installation effort, and reducing failure modes.
  • Said at least one tensioned conduit may comprise an articulation at its bottom to change its direction at the seabed.
  • it may comprise rigid or flexible pipe forming a curve.
  • At least some of said one or more suspended conduits may be suspended from the tensioned conduit.
  • at least some of said one or more suspended conduits may be suspended from the at least one buoyancy device.
  • the device may comprise a support frame, wherein at least some of said one or more suspended conduits are suspended from said support frame.
  • the tensioned conduit may be a single pipeline or, alternatively, it may be made up of a plurality of tensioned conduits grouped so as to form a bundle of conduits, each of which is spaced in a fixed relationship with the other conduits in the bundle by a suitable supporting framework.
  • At least some of said one or more suspended conduits may be attached to said apparatus via at least one chain and/or an accessory, said accessory for attaching to a respective receptacle attached to said apparatus.
  • Said apparatus may comprise a plurality of said suspended conduits.
  • Said apparatus may comprise connectors at the top of each conduit for connection to a flexible pipeline, e.g. a 'jumper'. Said apparatus may further comprise said flexible lines for connection of each conduit to a surface facility.
  • one or more of the suspended conduits is provided with a respective buoyancy device at or near its upper end, such an arrangement reducing the loading on the part of the tensioned conduit to which the suspended conduits are mounted.
  • the additional buoyancy devices enable the support frame to be made more cost effectively since the loading it is required to support is reduced significantly by way of the buoyancy device, potentially resulting in neutral buoyancy of the combined suspended conduit and respective buoyancy device.
  • the tensioned conduit, and therefore the entire apparatus may be coupled to two or more separable buoyancy devices, which may have different volumes, and therefore different buoyancy potentials.
  • a smaller one of said buoyancy devices may be provided for providing buoyancy sufficient at least for suspending the tensioned conduit alone, whereby a second buoyancy device may be added during installation of the suspended conduits to counteract the additional weight.
  • Said tensioned conduit may be used solely for tensioning and not used for conveying fluid. Consequently it may not have any flow connections.
  • the method may comprise the installation of an anchoring device to the seabed and attachment of said tensioned conduit to said anchoring device, either by way of a suitable tether such a cable or chain or, preferably, directly to the anchoring device without further intermediate components such as cables/chains.
  • the installation of the suspended conduits may comprise the steps of restraining a section of the suspended conduit on the seabed and moving the pipelay vessel so as to obtain a catenary configuration in the suspended conduit.
  • the attaching of the suspended conduit to the tensioned riser assembly may comprise lowering the suspended conduit on a line to its installation position and placing a male support, forming part of the upper riser assembly of the suspended conduit, into a female support (receptacle) forming part of the upper riser assembly of the tensioned riser assembly.
  • the step of attaching the buoyancy device may comprise attaching a first buoyancy device, the method further comprising the installation of a further buoyancy device to the tensioned riser assembly prior to the attachment of the at least one suspended conduit.
  • a floating production unit may be installed, followed by the installation of flexible pipelines so as to connect the conduits to said floating production unit.
  • the installation may take place in water deeper than 800m.
  • Figure 1 shows a cut away schematic view of a prior art seabed installation
  • Figure 2 shows another type of prior art seabed installation
  • Figure 3 shows a seabed installation according to a first embodiment of the invention
  • Figure 3a shows an alternative lower riser assembly for the seabed installation of Figure 3
  • Figure 4 shows detail of an arrangement near the top end of the riser, for a further embodiment of the invention
  • Figure 5 shows detail of one riser termination in the arrangement of figure 4.
  • Figure 6 shows an alternative form of riser termination, making a separate embodiment.
  • Figure 1 shows a cut-away schematic view of a seabed installation comprising a number of well heads, manifolds and other pipeline equipment 100 to 108. These are located in an oil field on the seabed 110.
  • Vertical riser towers are provided at 112 and 114 and perform the tasks of conveying production fluids, such as oil, from the seabed to the sea surface, and also of conveying lifting and exporting gas, injection water and treatment chemicals/gases such as methanol from the sea surface to the seabed.
  • the foot of each riser, 112, 114 is connected to a number of production well heads/injection sites 100 to 108 by horizontal pipelines 116.
  • the riser towers 112, 114 are pre-fabricated at a suitable on-shore manufacturing facility and towed to their operating location whereupon they are installed by anchoring their feet to the seabed and coupling their tops to a respective buoyancy device, which places the riser towers in tension.
  • a surface support 128 is for example a floating production and storage vessel (FPSO) moored by means not shown, or otherwise held in place at the surface.
  • FPSO 128 provides production processing facilities, storage and accommodation for handling production from the wells 100 to 108.
  • FPSO 128 is connected to the riser towers 112, 114 by flexible flow lines 132 (hereinafter 'flexible jumpers') that are arranged or 'hung' in a catenary.
  • the flexible jumpers 132 serve to transfer a variety of fluids between the FPSO 128 and the seabed via the riser towers 112, 114. Such flexible flow lines do not allow for straightforward disconnection in difficult meteorological conditions. Also, in such arrangements the FPSO 128 cannot be easily removed from its anchoring system.
  • each riser tower comprises only a single conduit.
  • the riser tower bundle may be a few metres in diameter, but is a very slender structure in view of its length (height) of for example 500m, or even 1 km or more.
  • Catenary risers made of rigid pipe (for example steel) or a flexible pipe are another form of riser that are increased used within the offshore oil and gas industry. They provide a fluid-conveying function between the seabed and a (moored) vessel that can be used for oil production, water injection, gas injection, and as service lines.
  • the connection of the riser to the vessel features a flexible joint which is attached to the side of the vessel's hull. Location of the flexible joint on hull side is mainly dictated by architectural considerations (structure and process), as well as installation considerations.
  • the departure angle of the SCR in the horizontal plane is generally restricted so that SCRs cannot head parallel to the hull side, to avoid collision with the hull.
  • Figure 2 shows the path of a catenary riser 200 connected to a surface support vessel 210.
  • the catenary riser 200 is made of a succession of steel tubular sections that are welded end-to-end, the upper end of which is coupled to the surface support vessel 210 by means of a top flexible joint 220.
  • the surface support vessel 210 may be, for example, a floating production and storage vessel (FSPO).
  • FSPO floating production and storage vessel
  • Figure 3 shows a marine riser arrangement according to an embodiment of the invention which comprises a first type of rigid conduit 300 in a first configuration similar to a Single Line Offset Riser (SLOR), which is essentially a monobore HRT.
  • the first, or 'primary' conduit includes a succession of steel pipe sections or 'joints' that are welded together end-to-end so as to form a rigid pipe string.
  • steel is the currently favoured material for the primary conduit due to its high strength, it is envisaged that other materials may also be suitable for example engineering plastics and composites of steel and plastics.
  • the marine riser arrangement comprises a first rigid conduit 300 that includes an upper part that is suspended from a buoyancy device 340 that in this embodiment is a generally cylindrical metal tank as would be known to the skilled reader.
  • the conduit 300 extends downwardly towards the sea bed and is anchored a short distance above a foundation module 330 in the form of a suction pile by way of a suitable tether, for example a steel cable or chain.
  • a suitable tether for example a steel cable or chain.
  • the vertical portion of the conduit 300 continues or blends into a catenary portion 310 which diverges away from the axis of the vertical portion to extend horizontally across the sea bed to connect to a well head or alternatively a suitable pipeline end terminator (PLET) 315.
  • PLET pipeline end terminator
  • the catenary section of the conduit 300 could, optionally, be supported along its length by one or more buoyancy devices so that it adopts what is known in the art as a 'lazywave' configuration.
  • the catenary section of the conduit may be a separate rigid pipe that is linked to the vertical conduit 300 by a suitable rigid or a flexible pipe-to-pipe connector.
  • the support frame 350 provides support for two further or 'secondary' conduits 360 that are suspended from the support frame 350 in a catenary and which also extend to the seabed.
  • the support frame 350 includes the following major components:
  • Each end of the support frame 350 includes a suitable mounting/support means 355 for a further buoyancy device 395, two of which are shown in Figure 3, each one of the buoyancy devices 395 supporting a respective one of the secondary conduits 360.
  • the buoyancy devices 395 serve to reduce the load on the support frame 350 and their respective mountings 355.
  • the supports 355 may be rigid, but preferably articulated at least in two directions perpendicular to the first conduit 300.
  • Each one of the secondary conduits 360 and also the primary conduit 300 has a respective pipe connector 370, for example of the "gooseneck" type as would be known to the skilled reader, for connecting the conduits 300, 360 to a respective flexible jumper 380.
  • the flexible jumpers 380 are hung in a catenary and link each one of the conduits 300, 360 to a floating production unit 390, so as to convey fluid to it from the seabed. It should be noted that the flexible jumpers 380 may also connect to an alternative structure than a floating production unit 390 as shown in Figure 3.
  • the connectors 370 may be of a type that is mechanically or hydraulically activated by a Remotely Operated Vehicle (ROV).
  • ROV Remotely Operated Vehicle
  • Figure 3a shows a view of a lower part of an alternative riser assembly.
  • the vertical conduit 300 does not also include a catenary section as in the embodiment in Figure 3.
  • the vertical or 'primary' conduit 300 spans the entire distance between the buoyancy device 340 and the foundation module 330 and its free lower end is attached directly to the foundation module by way of a suitable articulated connector 375, such a device being known to the skilled reader.
  • a rigid spool 385 also known as a jumper, connects between the bottom end of the conduit 300 and a flowline/wellhead 386 such that a fluid link is established between the flowline/wellhead 386 and the conduit 300 via the rigid jumper 385. Therefore, the conduit 300 serves as a fluid carrying pipeline in this embodiment.
  • the primary riser conduit 300 does not serve as a fluid carrying pipeline, but only to fix the support frame 350 at a predetermined depth.
  • a pipeline as a tethering device for the support frame 350 avoids the use of cable or chain-based tethering systems which are required to have dual redundancy, at least, in order to ensure safety in the event of failure of a single cable/chain. Installing a tethering system including multiple cables and/or chains is a time-consuming operation since a remote vehicle must make multiple trips between the surface and the seabed. Also, it is a complex operation since the cables/chains must be tensioned carefully and in cooperation to ensure that the load is shared substantially equally between the cables/chains to guard against premature failure.
  • each one of the secondary conduits 360 has a lower part that rests on the seabed and extends across to a suitable device such as a well head or a pipeline end terminator (PLET) 315.
  • PLET pipeline end terminator
  • the secondary conduits 360 have upper ends that are suspended from the support frame 350 so that they adopt a catenary. Note, however, that the hanging section of the secondary conduits 360 may be supported at various points by buoyancy modules so as to be configured into a so-called lazy wave.
  • each of the secondary conduits is supported by a respective buoyancy device 395 which reduces the loading on the support frame 350.
  • This concept therefore combines two types of rigid risers that extend from the seabed to a water depth that minimises environmental effects such as current and wave movement. Depending on the depth of the seabed, the water depth at which environmental effects are minimised may range from 50m to 250m.
  • Figures 4 and 5 show in greater detail the arrangement near the top end of the primary conduit 300, for a particular embodiment of the invention. In this arrangement it can be seen that several secondary conduits 360 are individually attached to different parts of the first conduit 300, and also to the buoyancy device 340, rather than all being attached to a support frame 350 as in the embodiment of Figure 3.
  • Figure 4 shows several secondary conduits 360 that are secured to the primary conduit 300 in different ways.
  • one option is attach a secondary conduit 360 directly to the buoyancy device 340 by way of a basket and chain arrangement 400/420.
  • each basket and chain arrangement 400/420 or clamp member may support more than one secondary conduit 360 if desired.
  • the buoyancy tank 340 comprises two modules: a low volume tank 440 and a high volume tank 450.
  • both buoyancy devices are generally cylindrical in nature having domed ends or 'heads' and have comparable diameters. Therefore, the low volume tank 440 is shorter than the high volume tank 450.
  • the double tank arrangement helps installation as the short tank 440 is sufficient to support and tension the primary conduit 300 by itself, allowing it to be installed first, along with the required frames and attachments 350, 355, 410.
  • the long tank 450 can then be coupled to the first tank 440 before attachment of the further conduits 360, which add very considerable weight.
  • the long tank 450 can therefore be ballasted as required to ensure that a predetermined depth is maintained throughout the installation process.
  • FIG. 4 Also shown in Figure 4 is the articulation and structural connector 410 between buoyancy element 340 and first conduit 300. Another articulation and structural connector 430 can be found between the short tank 440 and long tank 450. These structural connectors may be of the type marketed as Rotolatch (RTM). Installation of this riser arrangement is as follows:
  • the foundation module 330 (e.g. a suction pile or a driven pile) is lowered down to the seabed and driven into the seabed to the required penetration depth.
  • the first conduit 300 is constructed on an offshore installation vessel: The leading end of a first section of the primary conduit 300 is inserted in a lay tower, which handles the pipe string; and a next section of pipe is welded on this first section.
  • the pipe string, or column is completed by the addition of the upper riser assembly which includes goosenecks, connectors and supports for the flexible jumper 380 which completes the fluid link for conduit 300, a suitable support frame 350 for the secondary conduits 360, and the articulated connection 410 forming the structural link with the buoyancy device 440.
  • the first conduit 300 is transferred to a support on the vessel edge where it is supported by "outriggers".
  • the first buoyancy device 440 is taken by the crane on the installation vessel, upended and moved over the top of the conduit 300 for connection by means of the articulation.
  • the whole conduit assembly is connected to the foundation 330. This is achieved by attaching a cable to the lower end of the primary conduit 300 and running the cable through a sheave attached to the foundation whereby the cable is pulled from a service vessel, as by winching, to draw the lower end of the conduit 300 towards the foundation 330 whilst simultaneously lowering the conduit 300 into the water from the crane.
  • the second buoyancy device 450 is towed to the installation site and upended by ballasting the device 450.
  • a cable running in a sheave attached to the top of the first buoyancy device 440 is connected to the bottom of the second buoyancy device 450 and by pulling this cable from a service vessel, the second device is lowered and forced to make connection with the first device 440.
  • the tank of the second buoyancy device 450 is then de-ballasted by injection of nitrogen.
  • first further conduit 360 of the second type is initiated vertically from the lay tower. Construction proceeds by adding a section of pipe in the tower, welding it to the preceding section and lowering the string. When the lowermost pipe-section reaches the seabed, it is connected to a restraint placed on the seabed and a catenary configuration is obtained by moving the vessel and gradually releasing pipe.
  • the last pipe-section is added, which includes goosenecks and connectors and supports for the flexible jumper 380 making the fluid link for conduit 360, a chain 420 and articulation and male support to make the structural link with the basket (female) support on the first conduit 300.
  • the conduit 360 is lowered by a cable from the installation vessel and positioned so that the male part of the support system can be placed in the basket; the cable from the vessel is released and removed from the top of the conduit 360.
  • the other secondary conduits 360 are installed in the same fashion.
  • the flexible jumpers 380 are installed by connecting them between the conduits 300/360 and the floating production unit 390.
  • Figure 6 shows an alternative termination for the second conduit 360, in which a Y- shaped framework 600 is interposed between the catenary riser 360, the flexible jumper 380 and a supporting linkage 602, for example a chain or buoy.
  • This type of termination can be combined with that of Figure 5 in the same system, if desired.
  • a number of conduits are structurally linked (at least) at the top, reducing or eliminating the risk of clashing between these conduits under the effect of currents
  • the primary conduit 300 may in fact comprise more than one conduit, whether it be one or more conduits "piggybacked" to a main conduit, or conduits bundled together, with or without a central structural core.
  • the second conduits need not all have a simple caternary configuration. Modified catenary configuration such as the known 'Lazy Wave', 'Sleep Wave', 'Lazy S' and Sleep S' and 'Pliant Wave' variations are also known. These configurations, which are characterised by different forms of additional buoyancy devices carried on the riser conduit and/or separately anchored to the seabed, can be mixed and used on some or all of the second risers 360.
  • buoyancy arrangement for the primary conduit 300 is described as a single, or double buoyancy tank, other arrangements are possible within the scope of the claims.
  • the buoyancy arrangement may also be buoyancy means integrated with the primary conduit 300, for example syntactic foam blocks that are attached to and define a channel for the primary conduit.
  • Such a buoyancy arrangement would serve the same function of tensioning the primary conduit 300 into a substantially vertical orientation, although may be less desirable from an economic perspective.

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  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Mechanical Engineering (AREA)
  • Earth Drilling (AREA)
  • Underground Structures, Protecting, Testing And Restoring Foundations (AREA)

Abstract

La présente invention concerne un appareil à tube prolongateur comportant au moins un conduit sous tension s'étendant depuis la fond marin vers la surface, comprenant une extrémité inférieure fixée à un point d'ancrage sur le fond marin et une extrémité supérieure dont le support est assuré par au moins un dispositif de flottabilité afin de maintenir le conduit sous tension avec une orientation sensiblement verticale, et comprenant également un ou plusieurs autre(s) conduit(s) suspendus depuis une partie supérieure dudit appareil à tube prolongateur et qui s'étend/s'étendent également vers le fond marin. L'invention concerne également un procédé d'installation d'un tel appareil.
PCT/IB2010/002437 2009-08-14 2010-08-13 Appareil à tube prolongateur et son procédé d'installation Ceased WO2011018713A2 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
GB0914249A GB2472644A (en) 2009-08-14 2009-08-14 Marine riser apparatus and method of installation
GB0914249.8 2009-08-14

Publications (2)

Publication Number Publication Date
WO2011018713A2 true WO2011018713A2 (fr) 2011-02-17
WO2011018713A3 WO2011018713A3 (fr) 2011-06-23

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GB (1) GB2472644A (fr)
WO (1) WO2011018713A2 (fr)

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US8579034B2 (en) 2011-04-04 2013-11-12 The Technologies Alliance, Inc. Riser tensioner system

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FR3001491B1 (fr) * 2013-01-25 2017-12-01 Technip France Ensemble de connexion de conduites sous-marines

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US6082391A (en) 1997-09-12 2000-07-04 Stolt Comex Seaway Device for hybrid riser for the sub-sea transportation of petroleum products
WO2002053869A1 (fr) 2001-01-08 2002-07-11 Stolt Offshore S.A. Tourelle de colonne montante marine

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US6082391A (en) 1997-09-12 2000-07-04 Stolt Comex Seaway Device for hybrid riser for the sub-sea transportation of petroleum products
WO2002053869A1 (fr) 2001-01-08 2002-07-11 Stolt Offshore S.A. Tourelle de colonne montante marine

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Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US8579034B2 (en) 2011-04-04 2013-11-12 The Technologies Alliance, Inc. Riser tensioner system

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Publication number Publication date
WO2011018713A3 (fr) 2011-06-23
GB0914249D0 (en) 2009-09-30
GB2472644A (en) 2011-02-16

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