EP1917416B1 - Anlage mit mindestens zwei meeresbodenflächensteckern für mindestens zwei auf dem meeresboden liegende unterwasserpipelines - Google Patents

Anlage mit mindestens zwei meeresbodenflächensteckern für mindestens zwei auf dem meeresboden liegende unterwasserpipelines Download PDF

Info

Publication number
EP1917416B1
EP1917416B1 EP06794362A EP06794362A EP1917416B1 EP 1917416 B1 EP1917416 B1 EP 1917416B1 EP 06794362 A EP06794362 A EP 06794362A EP 06794362 A EP06794362 A EP 06794362A EP 1917416 B1 EP1917416 B1 EP 1917416B1
Authority
EP
European Patent Office
Prior art keywords
pipe
float
floats
riser
sea
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
EP06794362A
Other languages
English (en)
French (fr)
Other versions
EP1917416A1 (de
Inventor
Floriano Casola
Henri-Jacques Wattez
Giuseppe Attanasio
Garry Mahoney
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.)
Saipem SA
Original Assignee
Saipem SA
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 Saipem SA filed Critical Saipem SA
Publication of EP1917416A1 publication Critical patent/EP1917416A1/de
Application granted granted Critical
Publication of EP1917416B1 publication Critical patent/EP1917416B1/de
Active legal-status Critical Current
Anticipated expiration legal-status Critical

Links

Images

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
    • 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
    • E21B43/0107—Connecting of flow lines to offshore structures

Definitions

  • the subject of the present invention is an installation of multiple bottom-surface connections of at least two submarine pipes resting at the bottom of the sea, in particular installed at great depth, comprising at least one hybrid tower.
  • the technical field of the invention is more particularly the field of the manufacture and installation of production risers for the underwater extraction of oil, gas or other soluble or fusible material or a suspension of mineral material from wellhead immersed to a floating support, for the development of production fields installed offshore at sea.
  • the main and immediate application of the invention being in the field of oil production.
  • the floating support generally comprises anchoring means to remain in position despite the effects of currents, winds and waves. It also generally comprises oil storage and processing means as well as means of unloading to removal tankers, the latter being present at regular intervals to carry out the removal of the production.
  • the common name of these floating supports is the Anglo-Saxon term “Floating Production Storage Offloading” (meaning “floating medium of storage, production and unloading") which one uses the abbreviated term "FPSO" in the whole of the following description.
  • bottom-surface connections made by going up continuously to the subsurface of the resistant and rigid conduits consisting of tubular elements of thick steel welded or screwed together, in a chain configuration with a curvature continuously variable throughout their length in suspension, commonly called “Steel Catenary Riser” (SCRs) meaning “steel riser chain” and also commonly called “catenary type rigid pipe” or “SCR type riser”.
  • SCRs Steel Catenary Riser
  • Such a catenary duct may go up to the floating support surface or only to a subsurface float that tensions its upper end, which upper end is then connected to a floating support by a plunger flexible connecting pipe.
  • the installation is particularly unstable and would be animated by significant movements according to the swell and the currents, so that such an installation is only possible if the pipes are of flexible pipe type and not SCR type pipes who would present in the zone of the point of contact with the ground, the most constrained zone, fatigue phenomena totally incompatible with conditioning during a lifetime of 10 or even 30 years.
  • the 2 bottom-surface bonds and in particular the 2 floats are spaced from each other a great distance to avoid shocks between the movements of the 2 floats and 2 flexible pipes in their respective movements under the effect of displacements of the floating support and / or swell, wind and currents.
  • a multiple hybrid tower comprising an anchoring system with a vertical tendon consisting of either a cable or a metal bar, or a pipe stretched at its upper end by a float.
  • the lower end of the tendon is attached to a base resting at the bottom.
  • Said tendon comprises guiding means distributed over its entire length through which pass a plurality of said risers vertical.
  • Said base can be placed simply on the bottom of the sea and stay in place by its own weight, or remain anchored by means of batteries or any other device clean to keep it in place.
  • the lower end of the riser vertical is adapted to be connected to the end of a bend, movable cuff, between a high position and a low position, relative to said base, to which this cuff is suspended and associated with a return means bringing it back to the upper position in the absence of the riser:
  • This mobility of the bent sleeve makes it possible to absorb the length variations of the riser under the effects of temperature and pressure.
  • a stop device integral with it, comes to rest on the support guide installed at the head of the float and thus maintains the entire riser in suspension.
  • connection with the submarine pipe resting on the seabed is generally effected by a pig-shaped or S-shaped pipe portion, said S being then made in a vertical or horizontal plane, the connection with said underwater pipe being generally carried out via an automatic connector.
  • This embodiment comprising a multiplicity of vertical risers held by a central structure comprising guide means is relatively expensive and complex to install.
  • the installation must be prefabricated on the ground before being towed at sea, then once on site, cabane to be put in place.
  • its maintenance also requires relatively high operating costs.
  • multi-riser towers with vertical riser anchoring systems capable of receiving 2 risers side by side from the same anchor base, and whose floats at the head said risers are integral and fixed to each other by means of an articulated structure in the form of a parallelogram.
  • the two risers are also connected by means of tubular collars fixed on one of the risers and connected by rings sliding freely around the second riser, so that the two risers can follow substantially the same lateral movements while being relatively more independent in their vertical movements.
  • an object of the present invention is to provide a multi-pipe tower system that can be manufactured at sea from a fishing vessel. driving pose equipped with a laying tower.
  • the object of the present invention is to provide an installation comprising a multiplicity of bottom-surface connections whose manufacturing processes, pose and implement in terms of maintenance are improved and more particularly simplified.
  • Another problem posed according to the present invention is to be able to make and install such bottom-surface connections for submarine pipes at great depths, such as beyond 1,000 meters for example, and of type comprising a vertical hybrid tower and the transported fluid must be maintained above a minimum temperature until it reaches the surface, minimizing components subject to heat loss, avoiding the disadvantages created by the clean thermal expansion, or differential, of various components of said tower, so as to withstand extreme stresses and cumulative fatigue phenomena over the life of the structure, which currently exceeds 20 years.
  • Another problem of the present invention is also to provide a facility of multiple bottom-surface connections with hybrid towers whose anchoring system is of high strength and low cost, and whose manufacturing processes and implementation In place of the various constituent elements are simplified and also of low cost, and can be achieved at sea from a laying ship.
  • the installation according to the present invention has a reduced size and reduced movements and an increased stability compared to the bottom-surface connections comprising the association of 2 SCR type pipes as described in the prior art.
  • vertical riser is used here to account for the substantially vertical theoretical position of the riser when the riser is at rest, provided that the riser axis can know angular movements with respect to the vertical and move in a vertical direction.
  • corner cone ⁇ whose apex corresponds to the attachment point of the lower end of the riser on said base.
  • the installation of multiple bottom-surface links comprises a said second rigid pipe constituted by a second vertical riser whose lower end is fixed to a second base anchored to the bottom of the independent sea said first base and is connected to a said second underwater pipe resting at the bottom of the sea.
  • said second base is located at a distance of at most 50m, preferably 25 to 50m from said first base.
  • said first and second bases comprise suction anchors driven into the seabed.
  • the two bottom-surface links are connected to the upper level, but with different anchors and spaced from each other, so that, in case of differential expansion due to different temperatures in each of the vertical pipes, it This will result in a deformation of the triangle whose vertex is the set of floats and the base formed by the substantially horizontal line connecting the two bases.
  • the bottom-surface connection installation comprises a said second rigid pipe of the catenary type constituted by the end of a said second underwater pipe resting at the bottom of the sea going back up to in subsurface in a chain curve substantially in a continuously variable curvature, to said second float.
  • the point of support and ground contact substantially variable at the discretion of the movements of the upper part of said chain, from which said second catenary duct (or SCR) back in subsurface, stabilizes the base of said chain in a limited area and thus serves as a second base.
  • it is the vertical riser which stabilizes said second SCR type rigid pipe without requiring that the top of this SCR type pipe be stabilized by a cable or tie anchored to the seabed.
  • said first float is connected to the seabed to a third base anchored by at least a first link, said first base being positioned between said third base and said second rigid pipe
  • Said first link acts as a guy with respect to the hybrid riser tower to stabilize it by compensating the horizontal tension created by said second rigid pipe, the latter tending to move said first float floating support as explained further.
  • the bottom-surface connection installation according to the invention comprises two said rigid ducts each consisting of a so-called catenary type pipe going back to the subsurface in a chain-like curve substantially in a continuously variable curvature, up to two so-called second floats, and at least one of said two second floats is attached to said first float, the other second float being attached to one of said first floats; or second floats.
  • the bottom-surface connection installation according to the invention comprises two sets each comprising a said hybrid-tower and a said second rigid pipe of the catenary type, the two assemblies being connected to the same floating support and disposed substantially symmetrically on either side of said floating support by a second substantially horizontal link.
  • the bottom-surface connection installation according to the invention comprises two sets each comprising two so-called tour-hybrids, the two sets being connected to the same floating support and arranged substantially symmetrically on either side said floating support by a second substantially horizontal link.
  • said floats are fixed together by fastening means located at 2 points on each float vertically distant so as to secure the respective movements of the 2 floats, preferably fastening means located at 2 points close to the upper and lower ends respectively of the cylindrical containers constituting said floats.
  • the at least two so-called floats fixed together are inserted inside a peripheral screen of hydrodynamic shape, preferably cylindrical.
  • the attachment points of said first flexible connection line and second flexible connection line to the upper ends respectively of said first rigid pipe and second rigid pipe are located at different heights and one of said first and second Flexible connecting lines are located below the other said flexible connection line, and preferably with greater length and curvature of the lower flexible connection line.
  • This configuration makes it possible to avoid shocks between the first and second flexible connecting lines when they are animated by movement under the effect of the swell, currents and / or the movement of the floating support.
  • the attachment points of said first and second flexible connection lines at the upper ends respectively of the vertical riser and SCR type rigid pipe are substantially at the same height and the two flexible pipes are of substantially the same length, of same curvature, and are connected to each other to be substantially integral with each other, so as to be subjected, if necessary, to synchronous movements and to avoid any interference and shock between the 2 flexible pipes in case of movement related to the swell, currents and / or movements of the floating support.
  • step 2) anchoring said second rigid pipe consisting of a vertical riser to a second independent base and spaced from said first base of at least 25 m
  • the subject of the present invention is a method for operating a petroleum field using at least one installation according to the invention in which fluids are transferred between a floating support and ducts under -marines resting at the bottom of the sea, fluids comprising oil, preferably a plurality of said installations, in particular from 3 to 20 said installations according to the invention connected to the same floating support.
  • connection elements including the type automatic connectors, comprising the lock between a male part and a complementary female part, this lock being designed to be very simply at the bottom of the sea using a ROV, robot controlled from the surface, without requiring direct manual intervention of personnel.
  • Said first and second bases 3a, 3b comprise suction anchors driven into the seabed and spaced at a distance L1 of about 40m.
  • Each of the hybrid risers comprises a flexible pipe 4a, 4b connected to the upper end of said riser via a device of the gooseneck type 7.
  • the FPSO 11 and the gooseneck 7 are not shown in the background, but are detailed in the side views on the figures 2b , 4 and 5 .
  • the riser 1a is installed at the bottom of the sea, the second riser 1b is being installed from a surface vessel 13 equipped with a J 13-1 laying tower.
  • the vertical pipe assembly 1b, chain 5 and second float 2b is lowered to the suction anchor 3b using the handling means of said surface vessel, and, simultaneously, a winch, not shown, is operated from the surface by the ROV 14, so as to tension the cable 19 and thus bring the lower end of the riser 1b to its base 3b where it will then be locked in a known manner, using said ROV.
  • This is facilitated by the fact that simultaneously the upper end of the pipe is stretched by a float in the axis thereof.
  • the floats have internal reinforcements, for example circular stiffeners, or solid or perforated internal partitions, located at the fastening means, so as to transmit between said two floats, all the forces generated by the swell, wind and currents acting on all components and on the FPSO.
  • Said fastening means are either platens assembled by bolts by divers, if the depth of water is sufficiently low, or preferably automatic connectors actuated by a ROV controlled from the surface
  • the two risers 1a, 1b are between them an angle ⁇ of 1 to 10 ° by the spacing of their bases 3a, 3b.
  • the two bottom-surface links having a point of attachment to the upper level, but different anchors and spaced from each other, in case of differential expansion due to different temperatures in each of the vertical pipes, it will result a deformation of the angle triangle at the apex ⁇ and whose base is constituted by the substantially horizontal line connecting the two bases.
  • the flexible connection pipes 4a, 4b, integral with the FPSO 11 are installed.
  • the assembly of the two risers is substantially in the vertical plane ZoX, but the flexible connection lines create a horizontal tension which stabilizes the assembly tending to bring the assembly of the two hybrid risers towards said FPSO, of a negative angle ⁇ in the plane ZoY, as represented on the figure 2b .
  • FIG 3 On the figure 3 is shown in side view the riser 1a of the hybrid tower on which a surface vessel 13 installs a rigid pipe SCR type 1b equipped with its own float 2b, said SCR type pipe passing through said float 2b and ending at its upper part by a gooseneck 7.
  • the two floats In the final phase of approaching said second float 2b on said first float 2a of the hybrid tower, the two floats are locked together at 6-1 in the upper part, and in 6-2 in the lower part.
  • the figure 3a is a section in top view according to the AA plan of the figure 3 , detailing the assembly of a SCR 1b on a single hybrid tower, a hydrodynamic profile screen 8, preferably of circular section surrounds all the floats, so as to minimize the hydrodynamic forces due to the current and the swell.
  • the figure 3b is a section in top view according to the AA plan of the figure 3 , detailing the assembly of two SCRs 1b1, 1b2 each equipped with its own float 2b1, 2b2, the two so-called SCRs being preferably arranged symmetrically in a plane forming a delta angle, for example 30 °, preferably symmetrical with respect to the plane vertical ZoY.
  • the SCRs 1b are disposed on the side of the riser 1a farthest from the FPSO 11 for obvious reasons related to congestion constraints, and said SCRs 1b create a large horizontal tension H which tends to separate the two floats 2a , 2b of the FPSO 11, and the hybrid lair or laths of the risers 1a then incline by a positive angle ⁇ .
  • a solid link 9-1 at its upper end of the main float 2a and at its lower end to a weight anchor or a suction anchor 3c, thus constituting a tie rod.
  • the bottom-surface connection installation comprises two sets each comprising a said hybrid tower with a single riser 1a and a so-called second rigid pipe catenary type 1b, the two sets being connected to the same floating support (11) and arranged substantially symmetrically on either side of said floating support by a second substantially horizontal link (9-2) thus constituting a tie rod horizontal to compensate said opposite horizontal forces H and H '.
  • the figure 6a is a section according to the AA plan of the figure 3 relating to the configuration of Figure 3b , detailing a circular cylindrical screen 8 consisting of two half-shells 8-1,8-2 assembled at 15, said half-shells being secured to said floats by elastomeric links 16.
  • This screen has a hydrodynamic profile extending advantageously over the entire height of the floats, themselves made of cylindrical drums, so as to minimize the effects of the swell and the current, which then considerably reduces the movements of the assembly, thereby reducing fatigue problems throughout the lifetime of the installation that exceeds 25-30 years or more.
  • the second 2 connecting lines or flexible pipes 4a, 4b - which arrive at their other end at the floating support substantially at the same height - form curves of different curvatures.
  • the first flexible pipe 4a always remains below the second flexible pipe 4b and the first flexible pipe 4a has a greater curvature, that is to say, plunges more than the second pipe 4b, the first flexible pipe 4a being longer than the second flexible pipe 4b.

Landscapes

  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • Physics & Mathematics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Mechanical Engineering (AREA)
  • Earth Drilling (AREA)
  • Laying Of Electric Cables Or Lines Outside (AREA)
  • Farming Of Fish And Shellfish (AREA)
  • Revetment (AREA)

Claims (16)

  1. Vorrichtung zur Boden-Oberflächen-Verbindung von wenigstens zwei Unterwasserleitungen (10a, 10b), die am Meeresboden, insbesondere in großer Tiefe, aufliegen, umfassend:
    1) einen ersten Hybridturm, umfassend:
    a) eine erste starre Leitung, die aus einem vertikalen Steigrohr (1a) besteht, dessen unteres Ende an einem ersten verankerten Sockel (3a) auf dem Meeresboden befestigt und mit einer ersten sogenannten Unterwasserleitung (10a) verbunden ist, die auf dem Meeresboden aufliegt und deren oberes Ende auf im wesentlichen vertikale Weise durch einen ersten Schwimmer (2a), mit dem sie verbunden ist, gespannt ist, der unter die Wasseroberfläche, bevorzugt auf wenigstens 100 m Tiefe eingetaucht ist, und
    b) eine erste Verbindungsleitung (4a), bevorzugt eine flexible Leitung, die die Verbindung zwischen einem schwimmenden Träger (11) und dem oberen Ende des Steigrohrs gewährleistet, und
    2) wenigstens eine zweite starre Leitung (1 b), die vom Meeresboden, auf dem sie aufliegt (10b), oder von einer zweiten Unterwasserleitung, die auf dem Meeresboden aufliegt, mit der ihr unteres Ende verbunden ist, bis unter die Wasseroberfläche aufsteigt, wo ihr oberes Ende mit wenigstens jeweils einer zweiten, bevorzugt flexiblen Verbindungsleitung (4b), verbunden ist, die die Verbindung mit einem gleichen schwimmenden Träger (11) gewährleistet,
    - wobei das untere Ende der zweiten starren Leitung(en) (1b) nicht an dem ersten Sockel (3a) verankert ist, und
    - wobei das obere Ende der zweiten starren Leitung(en) (1b) jeweils mit einem zweiten Schwimmer (2b) verbunden ist,
    dadurch gekennzeichnet, daß sich dieser zweite Schwimmer (2b) im wesentlichen in der gleichen Tiefe befindet wie der erste Schwimmer (2a) und an dem ersten Schwimmer, bevorzugt aneinander, starr befestigt ist.
  2. Vorrichtung zur Boden-Oberflächen-Verbindung nach Anspruch 1, dadurch gekennzeichnet, dass eine zweite starre Leitung (1b) durch ein zweites vertikales Steigrohr gebildet wird, dessen unteres Ende an einem zweiten verankerten Sockel (3b) am Meeresboden befestigt ist, der unabhängig von dem ersten Sockel (3a) ist, und mit einer zweiten Unterwasserleitung (10b) verbunden ist, die auf dem Meeresboden aufliegt.
  3. Vorrichtung zur Boden-Oberflächen-Verbindung nach Anspruch 2, dadurch gekennzeichnet, dass sich der zweite Sockel (3b) in einem Abstand von höchstens 50 m, bevorzugt 25 bis 50 m von dem ersten Sockel (3a) entfernt befindet.
  4. Vorrichtung zur Boden-Oberflächen-Verbindung nach Anspruch 2 oder 3, dadurch gekennzeichnet, dass der erste und der zweite Sockel (3a, 3b) Sauganker umfassen, die im Meeresboden versenkt sind.
  5. Vorrichtung zur Boden-Oberflächen-Verbindung nach Anspruch 1, dadurch gekennzeichnet, dass eine zweite starre Leitung (1 b) eine Leitung vom Typ "catenary riser" ist, die aus einem Ende einer zweiten Unterwasserleitung gebildet wird, die auf dem Meeresboden aufliegt, die bis unter die Wasseroberfläche entlang einer Kettenlinienkurve im wesentlichen mit einer kontinuierlich variablen Krümmung bis zum zweiten Schwimmer aufsteigt.
  6. Vorrichtung zur Boden-Oberflächen-Verbindung nach Anspruch 5, dadurch gekennzeichnet, dass der erste Schwimmer auf dem Meeresboden mit einem dritten verankerten Sockel (3c) durch wenigstens eine erste Bindung (9-1) verbunden ist, wobei der erste Sockel zwischen dem dritten Sockel und der zweiten starren Leitung (1 b) positioniert ist.
  7. Vorrichtung zur Boden-Oberflächen-Verbindung nach einem der Ansprüche 5 oder 6, dadurch gekennzeichnet, dass sie zwei starre Leitungen umfasst, die jeweils durch eine Leitung vom Typ "catenary riser" (1 b1, 1 b2) gebildet werden, die bis unter die Wasseroberfläche entlang einer Kettenlinienkurve im wesentlichen mit einer kontinuierlich variablen Krümmung, bis zu zwei zweiten Schwimmern aufsteigt, und dass wenigstens einer der beiden zweiten Schwimmer an dem ersten Schwimmer befestigt ist, wobei der andere zweite Schwimmer entweder an einem ersten oder zweiten Schwimmer befestigt ist.
  8. Vorrichtung zur Boden-Oberflächen-Verbindung nach einem der Ansprüche 1 bis 7, dadurch gekennzeichnet, dass sie zwei Baugruppen umfasst, die jeweils einen Hybridturm und eine zweite starre Leitung vom Typ "catenary riser" umfassen, wobei die beiden Baugruppen mit dem gleichen schwimmenden Träger (11) verbunden sind und im wesentlichen symmetrisch auf beiden Seiten des schwimmenden Trägers durch eine zweite im wesentlichen horizontale Bindung (9-2) angeordnet sind.
  9. Vorrichtung zur Boden-Oberflächen-Verbindung nach einem der Ansprüche 2 bis 6, dadurch gekennzeichnet, dass sie zwei Baugruppen umfasst, die jeweils zwei Hybridtürme umfassen, wobei die beiden Baugruppen mit dem gleichen schwimmenden Träger (11) verbunden sind und im wesentlichen symmetrisch auf beiden Seiten des schwimmenden Trägers mittels einer zweiten im wesentlichen horizontalen Bindung (9-2) angeordnet sind.
  10. Vorrichtung zur Boden-Oberflächen-Verbindung nach einem der Ansprüche 1 bis 7, dadurch gekennzeichnet, dass sie eine Baugruppe umfasst, die umfasst:
    - zwei Hybridtürme mit zwei vertikalen Steigrohren (1a1, 1a2), deren erste Schwimmer (2a1, 2a2) aneinander befestigt sind, und
    - zwei zweite starre Leitungen vom Typ "catenary riser" (1b1, 1 b2) die bis unter die Wasseroberfläche entlang einer Kettenlinienkurve im wesentlichen mit einer kontinuierlich variablen Krümmung bis zu den beiden zweiten Schwimmern (2b1, 2b2) aufsteigen,
    - wobei die beiden zweiten Schwimmer (2b1, 2b2) jeweils an den zwei ersten Schwimmern (2a1, 2a2) befestigt sind.
  11. Vorrichtung zur Boden-Oberflächen-Verbindung nach einem der Ansprüche 1 bis 10, dadurch gekennzeichnet, dass die Schwimmer durch Befestigungsmittel (6-1, 6-2) aneinander befestigt sind, die sich in Höhe von zwei vertikal beabstandeten Punkten auf jedem Schwimmer befinden, um die jeweiligen Bewegungen der beiden Schwimmer zu solidarisieren, bevorzugt durch Befestigungsmittel (6-1, 6-2), die sich an zwei Punkten jeweils nahe den oberen und unteren Enden und der zylindrischen Kanister befinden, die die Schwimmer bilden.
  12. Vorrichtung zur Boden-Oberflächen-Verbindung nach einem der Ansprüche 1 bis 11, dadurch gekennzeichnet, dass die wenigstens zwei aneinander befestigten Schwimmer ins Innere einer peripheren Schutzvorrichtung mit hydrodynamischer, bevorzugt zylindrischer Form, eingefügt sind.
  13. Vorrichtung zur Boden-Oberflächen-Verbindung nach einem der Ansprüche 1 bis 12, dadurch gekennzeichnet, dass sich die Befestigungspunkte der ersten flexiblen Verbindungsleitung (4a) und der zweiten flexiblen Verbindungsleitung (4b) an den jeweiligen oberen Enden der ersten starren Leitung (1 a) und der zweiten starren Leitung (1 b) in unterschiedlichen Höhen befinden und sich die eine der ersten und zweiten flexiblen Verbindungsleitungen (4a, 4b) unter der anderen flexiblen Verbindungsleitung befindet und bevorzugt eine größere Länge und eine stärkere Krümmung als die weiter unten liegende flexible Verbindungsleitung besitzt.
  14. Verfahren zur Installation einer Vorrichtung nach einem der Ansprüche 1 bis 13 im Meer, dadurch gekennzeichnet, dass es die Schritte umfasst, in welchen:
    1) von einem Leitungsinstallationsschiff (13) aus an der Oberfläche ein vertikales Steigrohr (1 a) zusammengebaut wird, das versenkt und am Meeresboden an einem ersten Sockel (3a) verankert wird und oben durch einen ersten Schwimmer gespannt wird, der unter der Wasseroberfläche eingetaucht ist, und das untere Ende des Steigrohrs mit dem Ende einer ersten Unterwasserleitung (10a) verbunden wird, die auf dem Meeresboden aufliegt, und
    2) von einem Leitungsinstallationsschiff (13) aus an der Oberfläche eine zweite starre Leitung (1b) zusammengebaut wird, die oben durch einen zweiten Schwimmer gespannt wird, der unter der Wasseroberfläche eingetaucht ist, und gegebenenfalls, wenn die zweite starre Leitung ein vertikales Steigrohr ist, das untere Ende des Steigrohrs mit dem Ende einer zweiten Unterwasserleitung (10b) verbunden wird, die auf dem Meeresboden aufliegt, und
    3) der erste und zweite Schwimmer zusammengebracht und aneinander befestigt werden und
    4) der erste Schwimmer bevorzugt durch wenigstens eine erste und/oder zweite Bindung (9-1,9-2) stabilisiert wird und
    5) die Verbindungsleitungen (4a, 4b) zwischen dem Steigrohr und der zweiten starren Leitung einerseits und einem gleichen schwimmenden Träger andererseits installiert werden.
  15. Verfahren zur Erschließung eines Erdölfelds mit Hilfe wenigstens einer Vorrichtung nach einem der Ansprüche 1 bis 13, wobei Fluide zwischen einem schwimmenden Träger und Unterwasserleitungen transportiert werden, die auf dem Meeresboden aufliegen, wobei die Fluide Erdöl umfassen.
  16. Verfahren zur Erschließung nach Anspruch 15, dadurch gekennzeichnet, dass eine Vielzahl der genannten Vorrichtungen, bevorzugt 3 bis 20 der genannten Vorrichtungen, eingesetzt wird.
EP06794362A 2005-08-26 2006-08-25 Anlage mit mindestens zwei meeresbodenflächensteckern für mindestens zwei auf dem meeresboden liegende unterwasserpipelines Active EP1917416B1 (de)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
FR0508773A FR2890098B1 (fr) 2005-08-26 2005-08-26 Installation comprenant au moins deux liaisons fond-surface d'au moins deux conduites sous-marines reposant au fond de la mer
PCT/FR2006/001991 WO2007023233A1 (fr) 2005-08-26 2006-08-25 Installation comprenant au moins deux liaisons fond-surface d’au moins deux conduites sous-marines reposant au fond de la mer.

Publications (2)

Publication Number Publication Date
EP1917416A1 EP1917416A1 (de) 2008-05-07
EP1917416B1 true EP1917416B1 (de) 2009-01-14

Family

ID=36337863

Family Applications (1)

Application Number Title Priority Date Filing Date
EP06794362A Active EP1917416B1 (de) 2005-08-26 2006-08-25 Anlage mit mindestens zwei meeresbodenflächensteckern für mindestens zwei auf dem meeresboden liegende unterwasserpipelines

Country Status (7)

Country Link
US (1) US7946790B2 (de)
EP (1) EP1917416B1 (de)
AT (1) ATE421026T1 (de)
BR (1) BRPI0615091B1 (de)
DE (1) DE602006004883D1 (de)
FR (1) FR2890098B1 (de)
WO (1) WO2007023233A1 (de)

Families Citing this family (14)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US7793726B2 (en) * 2006-12-06 2010-09-14 Chevron U.S.A. Inc. Marine riser system
US20090078425A1 (en) * 2007-09-25 2009-03-26 Seahorse Equipment Corp Flexible hang-off arrangement for a catenary riser
FR2933124B1 (fr) * 2008-06-27 2010-08-13 Technip France Procede d'installation d'une tour hybride dans une etendue d'eau, tour hybride et installation d'exploitation de fluides associee
FR2948144B1 (fr) * 2009-07-16 2011-06-24 Technip France Dispositif de suspension de conduite petroliere et methode d'installation
GB2472644A (en) * 2009-08-14 2011-02-16 Acergy France Sa Marine riser apparatus and method of installation
FR2952671B1 (fr) 2009-11-17 2011-12-09 Saipem Sa Installation de liaisons fond-surface disposees en eventail
US8960302B2 (en) * 2010-10-12 2015-02-24 Bp Corporation North America, Inc. Marine subsea free-standing riser systems and methods
FR2967451B1 (fr) * 2010-11-17 2012-12-28 Technip France Tour d'exploitation de fluide dans une etendue d'eau et procede d'installation associe.
GB2488828B (en) * 2011-03-10 2014-08-20 Subsea 7 Ltd Restraint systems for hybrid decoupled risers
WO2012143671A2 (en) * 2011-04-18 2012-10-26 Magma Global Limited Subsea conduit system
CN103105281B (zh) * 2013-01-05 2018-06-19 中国海洋大学 一种用于研究顶张力作用下海洋立管干涉规律的试验装置
CN104699132B (zh) * 2015-01-26 2017-02-22 华中科技大学 一种水下浮体的安装方法
FR3033358B1 (fr) 2015-03-06 2017-03-31 Saipem Sa Installation comprenant au moins deux liaisons fond-surface comprenant des risers verticaux relies par des barres articulees
EP3280868A4 (de) * 2015-04-07 2019-04-17 Ensco International Incorporated Steigleitungsablenkungsabschwächung

Family Cites Families (17)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
FR2199053B1 (de) * 1972-09-13 1975-06-13 Coflexip
ES8105437A1 (es) * 1980-05-20 1981-05-16 Fayren Jose Marco Instalacion para la perforacion y explotacion de yacimientospetroliferos marinos localizados en aguas profundas
US4423984A (en) * 1980-12-29 1984-01-03 Mobil Oil Corporation Marine compliant riser system
US4388022A (en) * 1980-12-29 1983-06-14 Mobil Oil Corporation Flexible flowline bundle for compliant riser
NL8402545A (nl) * 1984-08-20 1985-08-01 Shell Int Research Werkwijze en inrichting voor het installeren van een flexibele leiding tussen een platform en een onderwater gelegen boei.
FR2588926B1 (fr) * 1985-10-18 1988-08-26 Inst Francais Du Petrole Dispositif et methode de mise en place et de connexion a distance d'une extremite d'un element allonge a un connecteur
US4762180A (en) * 1987-02-05 1988-08-09 Conoco Inc. Modular near-surface completion system
WO2000008262A1 (en) * 1998-08-06 2000-02-17 Fmc Corporation Enhanced steel catenary riser system
FR2790054B1 (fr) * 1999-02-19 2001-05-25 Bouygues Offshore Procede et dispositif de liaison fond-surface par conduite sous marine installee a grande profondeur
FR2821143B1 (fr) * 2001-02-19 2003-05-02 Bouygues Offshore Installation de liaison fond-surface d'une conduite sous-marine installee a grande profondeur du type tour-hybride
FR2826051B1 (fr) * 2001-06-15 2003-09-19 Bouygues Offshore Installation de liaison fond-surface d'une conduite sous-marine reliee a un riser par au moins un element de conduite flexible maintenu par une embase
GB2380747B (en) * 2001-10-10 2005-12-21 Rockwater Ltd A riser and method of installing same
FR2840013B1 (fr) * 2002-05-22 2004-11-12 Technip Coflexip Systeme de colonne montante reliant deux installations sous-marines fixes a une unite de surface flottante
AU2003253616A1 (en) 2002-05-30 2003-12-19 Gray Eot, Inc. Drill pipe connecting and disconnecting apparatus
US7434624B2 (en) * 2002-10-03 2008-10-14 Exxonmobil Upstream Research Company Hybrid tension-leg riser
EP1551698B1 (de) * 2002-10-16 2006-05-17 Single Buoy Moorings Inc. Installationsschiff für ein steigrohr und verfahren zu dessen benutzung
US7191836B2 (en) * 2004-08-02 2007-03-20 Kellogg Brown & Root Llc Dry tree subsea well communications apparatus and method using variable tension large offset risers

Also Published As

Publication number Publication date
US7946790B2 (en) 2011-05-24
DE602006004883D1 (de) 2009-03-05
FR2890098B1 (fr) 2008-01-04
ATE421026T1 (de) 2009-01-15
BRPI0615091B1 (pt) 2018-02-06
US20090103985A1 (en) 2009-04-23
FR2890098A1 (fr) 2007-03-02
BRPI0615091A2 (pt) 2011-05-03
WO2007023233A1 (fr) 2007-03-01
EP1917416A1 (de) 2008-05-07

Similar Documents

Publication Publication Date Title
EP1917416B1 (de) Anlage mit mindestens zwei meeresbodenflächensteckern für mindestens zwei auf dem meeresboden liegende unterwasserpipelines
EP1395731B1 (de) Verbindungsanlage zwischen einer unterwasserleitung und einem unterwassersteigrohr
EP1501999B1 (de) Meeresboden/flächen-verbindungsinstallation für eine unterwasserrohrleitung, die durch mindestens ein durch eine basis gestütztes rohrkniestück mit einem steigrohr verbunden ist
EP1073823B1 (de) Verfahren und vorrichtung zur bildung einer verbindung zwischen meeresgrund und oberfläche mittels einer in grosser tiefe installierten unterwasserleitung
EP2501889B1 (de) Anlage aus fächerförmig angeordneten grund-oberflächen-verbindungen
EP2286056B1 (de) Boden-oberfläche-verbindung aus einem starren steigrohr mit flexiblem kanal mit positiver flotation
EP2844820B1 (de) Installation mit meeresboden-zu-oberfläche-verbindungen vom typ eines multi-riser-hybridturms mit flexiblen rohren mit positivem auftrieb
EP1362161A1 (de) Vorrichtung zur bildung einer verbindung zwischen meeresgrund und oberfläche, einer in grosser tiefe installierten unterwasserleitung
EP2401468B1 (de) Meeresgrund-oberflächen-verbindungsinstallation der mehrfachsteigrohrhybridturmart mit gleitenden auftriebsmodulen
EP2785952B1 (de) Vorrichtung für flexible und mannigfaltige verbindungen zwischen meeresgrund und oberfläche auf mindestens zwei ebenen
WO2016110617A1 (fr) Dispositifs de lestage et/ou de protection pour lignes subaquatiques
EP2997220B1 (de) Vorrichtung zur verankerung einer laufbahnhalterung in einer vom meeresgrund bis zur oberfläche reichenden anlage
WO2009138610A1 (fr) Element de conduite de transition d'inertie notamment pour encastrement d'une conduite rigide sous-marine
EP3265642B1 (de) Anlage mit mindestens zwei unterflächigen verbindungen mit durch balken verbundenen vertikalen steigrohren
OA18412A (fr) Installation comprenant au moins deux liaisons fond-surface comprenant des risers verticaux reliés par des barres
EP2689093B1 (de) Verfahren zur unterstützten installation eines unterwassersteigrohrs
OA16986A (rf) Installation de liaisons fond-surface flexibles multiples sur au moins deux niveaux.
OA17784A (fr) Dispositif d'ancrage d'un support de goulottes d'une installation fond-surface
OA17101A (en) Installation de liaisons fond-surface de type tour hybride multi-risers comprenant des conduites flexibles à flottabilité positive.

Legal Events

Date Code Title Description
PUAI Public reference made under article 153(3) epc to a published international application that has entered the european phase

Free format text: ORIGINAL CODE: 0009012

17P Request for examination filed

Effective date: 20080204

AK Designated contracting states

Kind code of ref document: A1

Designated state(s): AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HU IE IS IT LI LT LU LV MC NL PL PT RO SE SI SK TR

GRAC Information related to communication of intention to grant a patent modified

Free format text: ORIGINAL CODE: EPIDOSCIGR1

GRAP Despatch of communication of intention to grant a patent

Free format text: ORIGINAL CODE: EPIDOSNIGR1

RIN1 Information on inventor provided before grant (corrected)

Inventor name: WATTEZ, HENRI-JACQUES

Inventor name: ATTANASIO, GIUSEPPE

Inventor name: MAHONEY, GARRY

Inventor name: CASOLA, FLORIANO

GRAS Grant fee paid

Free format text: ORIGINAL CODE: EPIDOSNIGR3

GRAA (expected) grant

Free format text: ORIGINAL CODE: 0009210

17Q First examination report despatched

Effective date: 20081202

AK Designated contracting states

Kind code of ref document: B1

Designated state(s): AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HU IE IS IT LI LT LU LV MC NL PL PT RO SE SI SK TR

REG Reference to a national code

Ref country code: GB

Ref legal event code: FG4D

Free format text: NOT ENGLISH

REG Reference to a national code

Ref country code: CH

Ref legal event code: EP

REG Reference to a national code

Ref country code: IE

Ref legal event code: FG4D

Free format text: LANGUAGE OF EP DOCUMENT: FRENCH

REF Corresponds to:

Ref document number: 602006004883

Country of ref document: DE

Date of ref document: 20090305

Kind code of ref document: P

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: LT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20090114

Ref country code: ES

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20090425

Ref country code: FI

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20090114

Ref country code: SI

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20090114

REG Reference to a national code

Ref country code: IE

Ref legal event code: FD4D

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: PL

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20090114

Ref country code: LV

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20090114

Ref country code: AT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20090114

Ref country code: SE

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20090414

Ref country code: PT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20090615

Ref country code: IS

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20090514

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: EE

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20090114

Ref country code: CZ

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20090114

Ref country code: DK

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20090114

Ref country code: IE

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20090114

PLBE No opposition filed within time limit

Free format text: ORIGINAL CODE: 0009261

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: NO OPPOSITION FILED WITHIN TIME LIMIT

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: RO

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20090114

Ref country code: SK

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20090114

26N No opposition filed

Effective date: 20091015

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: BG

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20090414

BERE Be: lapsed

Owner name: SAIPEM S.A.

Effective date: 20090831

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: MC

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20090831

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: BE

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20090831

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: DE

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20100302

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: GR

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20090415

REG Reference to a national code

Ref country code: CH

Ref legal event code: PL

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: LU

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20090825

Ref country code: LI

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20100831

Ref country code: CH

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20100831

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: HU

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20090715

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: TR

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20090114

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: CY

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20090114

REG Reference to a national code

Ref country code: FR

Ref legal event code: PLFP

Year of fee payment: 11

REG Reference to a national code

Ref country code: FR

Ref legal event code: PLFP

Year of fee payment: 12

REG Reference to a national code

Ref country code: FR

Ref legal event code: PLFP

Year of fee payment: 13

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: NL

Payment date: 20220725

Year of fee payment: 17

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: IT

Payment date: 20220808

Year of fee payment: 17

Ref country code: GB

Payment date: 20220818

Year of fee payment: 17

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: FR

Payment date: 20220812

Year of fee payment: 17

REG Reference to a national code

Ref country code: NL

Ref legal event code: MM

Effective date: 20230901

GBPC Gb: european patent ceased through non-payment of renewal fee

Effective date: 20230825

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: NL

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20230901

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: NL

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20230901

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: GB

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20230825