EP2286056A2 - Installation de liaison fond-surface d'une conduite rigide avec une conduite flexible a flottabilite positive - Google Patents
Installation de liaison fond-surface d'une conduite rigide avec une conduite flexible a flottabilite positiveInfo
- Publication number
- EP2286056A2 EP2286056A2 EP09745928A EP09745928A EP2286056A2 EP 2286056 A2 EP2286056 A2 EP 2286056A2 EP 09745928 A EP09745928 A EP 09745928A EP 09745928 A EP09745928 A EP 09745928A EP 2286056 A2 EP2286056 A2 EP 2286056A2
- Authority
- EP
- European Patent Office
- Prior art keywords
- pipe
- base
- sea
- rigid
- riser
- 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.)
- Granted
Links
- 238000009434 installation Methods 0.000 title claims abstract description 43
- 238000005188 flotation Methods 0.000 title 1
- 238000007667 floating Methods 0.000 claims abstract description 34
- 230000000284 resting effect Effects 0.000 claims abstract description 33
- 230000007704 transition Effects 0.000 claims description 68
- 238000004873 anchoring Methods 0.000 claims description 56
- 239000000463 material Substances 0.000 claims description 41
- 230000003014 reinforcing effect Effects 0.000 claims description 25
- 229910000831 Steel Inorganic materials 0.000 claims description 17
- 239000010959 steel Substances 0.000 claims description 17
- 239000000945 filler Substances 0.000 claims description 15
- 230000002787 reinforcement Effects 0.000 claims description 13
- 229920002635 polyurethane Polymers 0.000 claims description 12
- 239000004814 polyurethane Substances 0.000 claims description 12
- 239000007787 solid Substances 0.000 claims description 11
- 238000000034 method Methods 0.000 claims description 9
- 239000011248 coating agent Substances 0.000 claims description 7
- 238000000576 coating method Methods 0.000 claims description 7
- 229920001971 elastomer Polymers 0.000 claims description 7
- 239000000806 elastomer Substances 0.000 claims description 6
- 239000004576 sand Substances 0.000 claims description 6
- 230000000295 complement effect Effects 0.000 claims description 5
- 238000005260 corrosion Methods 0.000 claims description 4
- 230000007797 corrosion Effects 0.000 claims description 4
- 239000011236 particulate material Substances 0.000 claims description 4
- 230000002093 peripheral effect Effects 0.000 claims description 4
- 239000004020 conductor Substances 0.000 claims description 3
- 239000013536 elastomeric material Substances 0.000 claims description 3
- 230000000712 assembly Effects 0.000 claims description 2
- 238000000429 assembly Methods 0.000 claims description 2
- 230000000630 rising effect Effects 0.000 abstract description 2
- 238000004519 manufacturing process Methods 0.000 description 16
- 239000006260 foam Substances 0.000 description 8
- 244000261422 Lysimachia clethroides Species 0.000 description 7
- 238000005452 bending Methods 0.000 description 6
- 230000008901 benefit Effects 0.000 description 4
- 230000000694 effects Effects 0.000 description 4
- 238000009413 insulation Methods 0.000 description 4
- 238000003860 storage Methods 0.000 description 4
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 4
- 241000196324 Embryophyta Species 0.000 description 3
- 239000004568 cement Substances 0.000 description 3
- 239000003921 oil Substances 0.000 description 3
- 230000002829 reductive effect Effects 0.000 description 3
- 239000000725 suspension Substances 0.000 description 3
- 210000002435 tendon Anatomy 0.000 description 3
- RTAQQCXQSZGOHL-UHFFFAOYSA-N Titanium Chemical compound [Ti] RTAQQCXQSZGOHL-UHFFFAOYSA-N 0.000 description 2
- 230000009471 action Effects 0.000 description 2
- 239000011230 binding agent Substances 0.000 description 2
- 239000010779 crude oil Substances 0.000 description 2
- 238000010586 diagram Methods 0.000 description 2
- 238000009472 formulation Methods 0.000 description 2
- 238000003754 machining Methods 0.000 description 2
- 239000000203 mixture Substances 0.000 description 2
- 230000008569 process Effects 0.000 description 2
- 230000003068 static effect Effects 0.000 description 2
- 229920001187 thermosetting polymer Polymers 0.000 description 2
- 239000010936 titanium Substances 0.000 description 2
- 229910052719 titanium Inorganic materials 0.000 description 2
- 238000003466 welding Methods 0.000 description 2
- 101100420946 Caenorhabditis elegans sea-2 gene Proteins 0.000 description 1
- 230000002411 adverse Effects 0.000 description 1
- 230000016571 aggressive behavior Effects 0.000 description 1
- 238000013459 approach Methods 0.000 description 1
- 230000015572 biosynthetic process Effects 0.000 description 1
- 238000005266 casting Methods 0.000 description 1
- 239000000470 constituent Substances 0.000 description 1
- 238000005520 cutting process Methods 0.000 description 1
- 230000003247 decreasing effect Effects 0.000 description 1
- 230000008021 deposition Effects 0.000 description 1
- 230000000994 depressogenic effect Effects 0.000 description 1
- 230000001627 detrimental effect Effects 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 238000009826 distribution Methods 0.000 description 1
- 238000000605 extraction Methods 0.000 description 1
- 230000005484 gravity Effects 0.000 description 1
- 150000004677 hydrates Chemical class 0.000 description 1
- 230000002706 hydrostatic effect Effects 0.000 description 1
- 229910052500 inorganic mineral Inorganic materials 0.000 description 1
- 238000003780 insertion Methods 0.000 description 1
- 230000037431 insertion Effects 0.000 description 1
- 239000011810 insulating material Substances 0.000 description 1
- 230000003993 interaction Effects 0.000 description 1
- 238000012423 maintenance Methods 0.000 description 1
- 238000007620 mathematical function Methods 0.000 description 1
- 229910052751 metal Inorganic materials 0.000 description 1
- 239000002184 metal Substances 0.000 description 1
- 239000011707 mineral Substances 0.000 description 1
- 239000012188 paraffin wax Substances 0.000 description 1
- 229920003023 plastic Polymers 0.000 description 1
- 239000004033 plastic Substances 0.000 description 1
- 229920005749 polyurethane resin Polymers 0.000 description 1
- 238000009417 prefabrication Methods 0.000 description 1
- 238000012545 processing Methods 0.000 description 1
- 230000009467 reduction Effects 0.000 description 1
- 229920005989 resin Polymers 0.000 description 1
- 239000011347 resin Substances 0.000 description 1
- 239000003351 stiffener Substances 0.000 description 1
- 229920001169 thermoplastic Polymers 0.000 description 1
- 239000004416 thermosoftening plastic Substances 0.000 description 1
- 238000012546 transfer Methods 0.000 description 1
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
- E21B17/015—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
- E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
- E21B17/01—Risers
- E21B17/017—Bend restrictors for limiting stress on risers
Definitions
- the present invention relates to a bottom-surface connection installation between a submarine pipe resting at the bottom of the sea and a floating support surface, comprising a hybrid tower consisting of a flexible pipe connected to a rigid pipe rising, or vertical riser , whose lower end comprises an inertial transition piece allowing it to be embedded in an anchoring device comprising a base resting at the bottom of the sea.
- 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.
- a tour-hybrid link comprising: a vertical riser whose lower end is anchored to the bottom of the sea; the sea through a flexible joint, and connected to a said pipe resting at the bottom of the sea, and the upper end is stretched by a submerged submerged float to which it is connected, and
- a connecting pipe generally a flexible connecting pipe, between the upper end of said riser and a floating support on the surface, said flexible connecting pipe taking, if appropriate, by its own weight in the form of a curve in plunging chain, that is to say, descending widely below the float to then go up to this floating support.
- Such a catenary duct can go up to the floating support surface or only to a sub-surface float that tensions its upper end, which upper end is then connected to a floating support by a plunging flexible connecting pipe.
- WO 00/49267 it has been proposed as connecting pipe between the riser whose top is tensioned by a float immersed surface and the floating support, rigid pipes SCR type and installs the float at the head of the riser at a distance larger of the surface especially at least 300 m from the surface, preferably at least 500 m.
- WO 00/49267 of the applicant there has been described 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 end superior 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 passes a plurality of said risers vertical.
- Said base can be placed simply on the seabed and stay in place by its own weight, or remain anchored by means of batteries or any other device to keep it in place.
- the lower end of the vertical riser is adapted to be connected to the end of a bent sleeve, movable, between a high position and a low position, with respect to said base, to which this cuff is suspended and associated with a return means bringing it up 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 plurality of 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.
- crude oil travels a great distance over several kilometers, it must be provided with an extremely costly level of insulation to, on the one hand, minimize the increase in viscosity which would lead to a reduction in the hourly production of the wells. and on the other hand to avoid the blockage of the flow by paraffin deposition, or formation of hydrates when the temperature drops to around 30-
- bottom-surface links are of short lengths and thus for the bulk of the different links connected to the same floating support to be limited.
- the vertical riser is tensioned by a sub-surface float and the connection between the vertical riser and the floating support is made by a flexible pipe in a chain configuration.
- plunger whose end is connected to the upper end of said vertical riser by a gooseneck device.
- a vertical riser connected to a flexible pipe in a plunging chain configuration is described, the end of the flexible pipe connected to said riser has a curvature imposed by a vertically-shaped gutter of circular shape resting at the top. a toric-shaped float, said gutter serving gooseneck and avoiding too small radii of curvature that can lead to crushing of said flexible pipe.
- This embodiment does not prevent wear of the flexible pipe at its interaction with said channel, which affects the intrinsic reliability of the connection between the vertical riser and the flexible pipe in terms of mechanical strength over time .
- An object of the present invention is therefore to provide a bottom-surface link installation with hybrid towers, compact, simple to install and can be manufactured at sea from a pipe laying ship, but the system of anchoring is of great strength and low cost, and whose manufacturing processes and implementation of the various constituent elements are simplified and also low cost, and can be carried out at sea, also, from a ship deposit.
- Another purpose is to provide an installation that does not require the implementation of flexible joints, especially at the base of the vertical riser.
- Another object of the present invention is to provide a bottom-surface connection installation as described above, which requires the implementation of a single connecting element, in particular a single automatic connector, between the end bottom of the vertical riser and the end of the pipe resting at the bottom of the sea.
- the present invention provides a bottom-surface connection installation, particularly at a greater depth of more than 1000 m, comprising: a- at least one upright rigid pipe, substantially vertical, called vertical riser, attached to its lower end to an anchoring device on the seabed, and b- at least one flexible connecting pipe connecting a floating support and the upper end of said vertical riser, c- one end of said flexible pipe is directly connected, preferably by a system of flanges, at the upper end of said vertical riser, and d- the lower end of said vertical riser comprises a terminal pipe element forming an inertial transition piece whose variation of inertia is such that the inertia of said end pipe element at its upper end is substantially identical to that of the pipe element of the running part of the riser v ertical which it is connected, said inertia of the terminal pipe element gradually increasing to the lower end of said inertial transition piece, comprising a first fastening flange for embedding the lower end of said riser.
- vertical riser is used here to account for the 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 cone. angle ⁇ whose apex corresponds to the point of attachment of the lower end of the riser on said base.
- the upper end of said vertical riser may be slightly curved.
- the term “flexible pipe end portion is therefore substantially in alignment with the axis Z 1 Z ' ! said upper riser "that the end of the inverted chain curve of said flexible pipe is substantially tangent to the end of said vertical riser. In any case, in continuity of variation of curvature, that is to say without singular point, in the mathematical sense.
- inertia is meant here the moment of inertia of said inertial transition line element with respect to an axis perpendicular to the axis of said inertial transition conductor element, which reflects the bending stiffness in each planes perpendicular to the XX 'axis of symmetry of said driving element, this moment of inertia being proportional to the product of the section of material by the square of its distance from said axis of the driving element.
- the slope of the curve formed by the flexible pipe is such that the inclination of its tangent relative to the axis Z 1 T 1 of the upper part of said vertical riser increases continuously and progressively from the connection point between the upper end of the vertical riser and the end of said end portion of flexible pipe positive buoyancy, no inflection point and no inversion point of curvature.
- the installation according to the present invention therefore makes it possible to prevent the tensioning of the vertical riser by a surface or subsurface float, at which its upper end would be suspended, on the one hand, and, on the other hand, to avoid the connection to said plunging flexible pipe via a gooseneck device, as implemented in the prior art.
- This not only results in greater intrinsic reliability in terms of mechanical strength over time of the connection between the vertical riser and the flexible pipe, because the gooseneck devices are fragile.
- this type of installation confers increased stability in terms of angular variation (y) of the angle of excursion of the upper end of the vertical riser relative to a theoretical position of vertical rest, because this angular variation is reduced in practice to a maximum angle not exceeding 5 °, in practice of the order of 1 to 4 ° with the installation according to the invention, whereas, in the embodiments of the prior art, the angular excursion could reach 5 to 10 ° or more.
- Another advantage of the present invention is that, due to this small angular variation of the upper end of the vertical riser, it is possible to implement, at its lower end, a rigid recess on a base resting at the bottom of the sea, without having recourse to a part of transition of inertia of dimension too important and thus too expensive. It is therefore possible to avoid the implementation of a flexible joint, in particular of the spherical flexible ball type, provided that the junction between the lower end of the riser and said recess comprises an inertia transition piece.
- the positive buoyancy of the riser and the flexible pipe can be made in known manner by coaxial peripheral floats surrounding said pipes, or, preferably, as regards the rigid pipe of the vertical riser, a positive buoyancy material coating. , preferably also constituting an insulating material, such as syntactic foam, in the form of a shell enclosing said pipe.
- Such buoyancy elements resistant to very high pressures that is to say at pressures of about 10M Pa per 1000m of water, are known to those skilled in the art and are available from the BALMORAL Company (UK).
- the positive buoyancy will be distributed regularly and uniformly over the entire length of said end portion 10a of the flexible pipe and at least said upper portion 9b of said rigid pipe.
- said end portion of the flexible pipe having a positive buoyancy extends over a length of 30 to 60% of the total length of the flexible pipe. preferably about half of the total length of said flexible pipe. More particularly, said flexible pipe has a positive buoyancy over a length corresponding to 30 to 60%, of its total length, preferably about half of its total length.
- the portion of plunging flexible pipe, that is to say, negative buoyancy may be even shorter than the anchoring of the floating support surface is steep.
- said positive buoyancy must allow to obtain a vertical resultant thrust of 50 to 150 kg / m, that is, said required buoyancy should correspond to the apparent weight of said rigid pipe and said flexible pipe end portion plus additional buoyancy of 50 to 150 kg / m.
- a bottom-surface connection plant comprises the following features, according to which:
- said vertical riser is connected at its lower end to at least one pipe resting at the bottom of the sea, and
- said anchoring device comprises a support and connection device fixed on a base placed and anchored at the bottom of the sea, and said pipe lying at the bottom of the sea comprises a first terminal rigid pipe element integral with said base resting at the bottom of the sea and said first terminal pipe element is and fixedly held relative to said base, with at its end a first connecting element part, preferably a male or female element of an automatic connector, and
- said first fastening flange at the lower end of said inertial transition piece is fixed to a second fastening flange at the end of a second rigid elbow pipe element secured to said fixed support and connection device; on said base and rigidly and rigidly supporting said second bent rigid pipe element, the other end of which comprises a second connecting element part complementary to and connected to said first connecting element part; when said support and connection member is attached to said base.
- the bottom-surface bonding plant has the characteristics that:
- said base is anchored to the bottom of the sea by a first tubular pile passing through a through orifice of said base, said first pile being driven into the ground at the bottom of the sea, and its upper part cooperating with the base so that to allow the anchoring of said base, and said support and connection device supporting said second bent rigid pipe element comprises a second tubular pile, called a tubular anchoring insert, inserted inside said first tubular anchoring pile of said base, said base comprising a locking device retaining said tubular anchoring insert within said first tubular pile in case of pulling said second tubular pile upwards.
- said first and second piles are assemblies of standard unitary elements of rigid pipes or unitary unit portions of rigid pipes, said second pile being shorter than said first pile.
- This anchoring system of the base and fixing said support device and connection, at the lower end of said inertial transition piece on said base, is particularly advantageous for the following reasons.
- the combination of the first pile and the tubular anchoring insert constitutes a guide system, which makes it possible to make said first connecting element parts and the second end connecting element part coincide with each other.
- the terminal pipe element of the sea-bottom pipe which is fixedly positioned with respect to said base, and, on the other hand, the end of said rigid pipe element fixedly positioned relative to said support device.
- tubular anchoring insert is positioned in the axis of said inertia transition piece and said second rigid pipe member supported by said support and connecting device is curved or bent so that said first automatic connector-type connection member portion is laterally disengaged from the remainder of said support and connection device, and said second connector-type connector element automatically at the end of said first rigid terminal conduit element of said pipe resting at the bottom of the sea, integral with said base, is also disengaged with respect to the orifice of said base and with respect to said support device and connection of which said anchoring insert is inserted inside said first anchor pile.
- said first end pipe member of said bottom-lying pipe may preferably also be bent to coincide with the end of said second bent rigid pipe member and allow easy connection by a underwater automaton type ROV at the bottom of the sea.
- said inertia transition duct element has a cylindro-conical shape of which: the thinner upper end of the transition piece has an inside diameter and a thickness substantially equal to the inside diameter and thickness of the lower end of said vertical riser, to which it is attached, and
- the lower end of the transition piece, on the side of said first fastening flange has an inside diameter substantially equal to that of the lower end of said vertical riser, but a thickness greater than, preferably equal to 3 to 10 times, that of the lower end of said vertical riser.
- Such inertial transition pipe members may be 15 to 50 m in length. More particularly, the cylindrical portion extending over a length of 3 to 5 m and the conical portion over a length of 10 to 47 m.
- These parts are very expensive to manufacture because they must be made using very thick pipes, but of varying thickness, assembled together, and then machined on a very large lathe to obtain the conical shape.
- Such parts are very expensive to achieve, because to obtain a good result, it is necessary that the pipe assembled by welding before machining is perfectly rectilinear, and moreover the turns capable of precisely machining parts of 20 to 30m in length are difficult to find and at a very high operational cost.
- the cylindro-conical transition pieces can not be made of steel, and require the use of titanium, which further increases the cost and complexity.
- said inertial transition terminal pipe element comprises a main rigid pipe element and at least one, preferably a plurality, of coaxial reinforcing pipe elements disposed coaxially with said element.
- said annular space is completely filled with the same solid filler material, preferably comprising an elastomer material, more preferably based on polyurethane, having a Shore hardness greater than or equal to A50, more preferably A50. at D70, and said inertial transition element is covered with a corrosion-resistant elastomeric cover material, preferably of polyurethane type, said inertia transition end-conductor element having a substantially cylindrical-conical shape through its coating by said covering material.
- the annular space is completely filled with the same filling material and the covering material imparts a cylindro-conical shape to the transition piece, a continuous variation of the cross-sectional diameter of the same is obtained.
- the piece and with the same filling material over the entire height of the transition piece which results in a gradual and continuous variation of inertia, that is to say without discontinuity of inertia.
- the implementation of an elastomeric cover material provides a corrosion protection guaranteeing greater longevity to said transition piece, which is subjected to a high mechanical stress and without this protection would have reduced longevity.
- said solid filler material must have a compressive strength so as to transfer the shear forces to the higher order reinforcing pipe member "i + 1" in a manner proportional to the deformation of a said element. coaxial it contains order "i” under the effect of a bending effort.
- the solid filler In practice the solid filler must have a Poisson's ratio of 0.3 to 0.49, preferably 0.4 to 0.45.
- This filler material may be an elastomer such as rubber or polyurethane alone or in combination with sand.
- said cover material and said filler material comprise the same elastomeric material, preferably based on polyurethane.
- said solid filler material comprises a polyurethane of Shore A90 or A95 hardness.
- the solid filler material comprises an elastomer loaded with particulate material, preferably sand.
- the solid filler material is in the form of a hydraulic binder such as cement, optionally filled with particulate material, preferably sand.
- said solid filler material is in the form of a particulate material, preferably sand and / or a hydraulic binder such as cement:
- the annular space between two of said pipe elements is greater than or equal to the thickness of said pipe element of smaller thickness and less than or equal to twice the thickness of said pipe element of greater thickness delimiting said annular space;
- the length of said main pipe element is 10 to 50 m, preferably 20 to 30 m, and it comprises 2 or 3 of said coaxial reinforcing elements,
- said main pipe element and coaxial reinforcing pipe elements each consist of all or part of a standard unitary pipe element, in particular a standard underwater pipe made of steel, or each consisting of a plurality of standard pipe elements assembled end-to-end. end and preferably held coaxially by centering wedges evenly distributed along their longitudinal direction and on the circular section in their annular spaces.
- An important advantage of the bottom-surface connection plant of the present invention also lies in the simplicity of its installation at the bottom of the sea.
- the present invention therefore also provides a process for placing at the bottom of the sea a bottom-surface connection installation according to the invention, comprising the following successive steps in which:
- a method of setting up a bottom-surface connection installation comprises the following successive steps in which:
- said anchoring insert is locked inside said first tubular pile with the aid of a locking device
- This process according to the invention is particularly simple and therefore advantageous to set up.
- This simplicity results from the fact that the anchoring function on said base is filled by said anchoring insert, on the underside of said support and connection device, and that the bending moments experienced by the inertia transition piece are taken by the first anchoring pile driven to the bottom of the sea and not by said base, so that it is possible to implement a relatively low base weight and low volume.
- FIG. 1 is a side view of a bottom-surface connection installation 1 according to the invention comprising a rigid pipe 9 of the Riser type recessed at the bottom in a first pile 6 passing through a base 4 and connected to its upper end. 9b to a flexible pipe 10 floating on an end portion 10a of its length, the other end of the pipe being connected to a FPSO (Floating Production Storage Offloading) 12,
- FPSO Floating Production Storage Offloading
- FIG. 2A is a side view of the installation of the bottom-surface connection in its base being put in place from a work vessel 20,
- FIG. 2B is a side view of the installation of a said first anchoring pile 6 in a base supporting the end of an underwater pipe resting on the bottom of the sea
- FIG. 2C is a side view of the lower end of the riser 9 with an inertia transition piece 8 at its connection with a support and connection device 5 comprising a tubular anchoring insert 5e to the inside said anchoring pile 6,
- FIG. 3 is a side view of the installation of the bottom-surface connection, in the course of implementation, after engagement of the anchoring insert 5e in the anchoring pile 6,
- FIG. 3A and 3B show in side view and in section two base variants of the connection to a pipe resting at the bottom of the sea of a bottom-surface connection installation according to the invention
- FIG. 4 is a view in section and in side view of a massive conical steel transition piece 8 installed at the lower end of the riser 9,
- FIGS. 5A-5B-5C are cross-sectional side views of a preferred embodiment of a transition piece consisting of stacks of coaxial steel pipes, the interstices being filled with plastic materials on the FIGS. 5B and 5C,
- FIG. 6 is a diagram illustrating the variation of the inertia of the transition pieces according to FIG. 5C.
- FIG. 1 there is shown a bottom-surface connection facility 1 connecting an underwater line 2 resting on the seabed 3 to a floating support type FPSO 12 surface moored by anchor lines 12a.
- An installation according to the invention comprises from the support 12 on the surface to a base 4 at the bottom of the sea, the following elements: a) a flexible pipe 10 comprising a first concave portion 10b extending from the end 10e flexible pipe attached to the floating support 12 up to about half of the flexible pipe in the form of a plunging chain configuration by its negative buoyancy to a point of inflection in 1Od substantially half the length of the flexible pipe, the end portion 10a extending from the central point of inflection 1Od to the end 10c of the flexible pipe having a positive buoyancy by a plurality of floats 10f preferably regularly spaced along and around said end portion 10a of flexible pipe, and b) a rigid steel riser pipe 9 or "riser vertical" equipped with buoyancy means, not shown, such half-shells syntactic foam preferably distributed uniformly over all or part of the length of said rigid pipe, and comprising at its lower end an inertia transition piece 8 equipped with a first fastening flange 9a to
- the first fastening flange 9a is fixed on a second fastening flange 5a constituting the upper part of a support and connection device 5, itself anchored on the first pile 6 integral with the base 4 resting at the bottom of the sea, said support device and connection 5 for connecting the lower end of the riser 9 to a pipe 2 resting at the bottom of the sea, as explained below.
- the flexible pipe has a variation of continuous curvature, first concave in the part of a plunging chain configuration
- - x represents the distance in the horizontal direction between the point of horizontal tangency and a point M of the curve
- - y represents the altitude of the point M (x and y are therefore the abscissa and ordinate of a point M of the curve relative to an orthonormal coordinate system whose origin is at the point of tangency)
- R 0 represents the radius of curvature at said point of horizontal tangency.
- R represents the radius of curvature at the point M (x, y)
- the curvature varies along the chain from the surface (for a plunging chain) or from its end portion to the upper end of the riser (for an inverted chain) where its radius has a maximum value R max , up to point of horizontal tangency (which is the low point of the plunging chain 10b and the high point of the inverted chain 10a), where its radius has a minimum value R mn (or R 0 in the formula above).
- This flexible pipe is to allow its initial portion 10b plunging to dampen the excursions of the floating supports 12 so as to stabilize the end 10c of the flexible pipe connected to a rigid riser pipe of the vertical riser 1.
- the end of the portion of the floating end portion 10c of the flexible pipe carries a first fastening flange member 11 with the upper end of a rigid pipe extending from the seabed recessed at a base 4 resting at the bottom of the sea.
- the vertical riser 9 is "tensioned" on the one hand by the buoyancy of the end portion 10a of the flexible pipe, but on the other hand and above all by floats regularly distributed at least on the upper part 9b, preferably all along the rigid pipe, especially in the form of syntactic foam advantageously acting as both an insulation and buoyancy system.
- floats and this syntactic foam can be distributed along and around the rigid pipe over its entire length or, preferably, only on a portion of its upper part.
- the base 4 can be limited to coating the rigid pipe 1 of syntactic foam over a length of 1000 m from its upper end, which allows to implement a syntactic foam that must withstand less pressure than if it had to withstand pressures up to 2500 m, and therefore a radically reduced cost compared to a syntactic foam to withstand said depth of 2500 m.
- the rigid pipe 1 according to the invention is therefore “tensioned” without implementation of a float surface or sub-surface as in the prior art, which limits the effects of current and swell, and thus drastically reduces the excursion of the upper part of the vertical riser and therefore the efforts in the foot of riser at the level of the embedding.
- buoys 10f spaced from each other and regularly distributed over the portion 10a, each representing the equivalent of a few meters of the required thrust, for example for a spacing of 5 to 10 m the resulting thrust required for each float will be
- the overall buoyancy corresponds to what is commonly called the "Archimedes thrust” or “Apparent Weight” on each of the parts of the bottom-surface connection: corresponding on the one hand to the buoyancy required for counterbalance the respective apparent weight of the rigid pipe and the flexible pipe, and secondly to the additional buoyancy necessary for tensioning which thus provides a resultant vertical thrust of 50 to 150 kg / m as previously described.
- the fastening flange system 11 between the upper end of the vertical riser 9 and the flexible pipe 10, and the connection of the fastening flanges 9a, 5a between the lower end to the inertia transition piece 8 and the device of FIG. connection support 5, provide sealed connections between the relevant conduits.
- the base 4 resting at the bottom of the sea supports a first curved or curved terminal pipe element 2a of said pipe resting at the bottom of the sea 2.
- This first curved or curved end pipe element 2a comprises at its end a first male or female part of an automatic connector 7b, which is released laterally. relative to a through hole 4a of said base, but positioned fixedly and determined with respect to the axis ZZ 'of said orifice.
- the support and connection device 5 supports a second rigid elbow pipe element 5b having at its upper end said second attachment flange 5a and at its lower end a second female or male part of an automatic connector 7a, complementary to Part 7b.
- a first tubular anchoring pile 6 is lowered from an installation vessel 20 on the surface, then depressed, preferably beaten in known manner, through an orifice 4a vertically traversing from one end to the base 4 until a peripheral protuberance 6a at the upper end of said first pile 6 comes to cooperate with a complementary shape 4c in the upper part of said orifice 4a of the base.
- the orifice 4a is slightly larger than the first pile 6 to let it slide freely. And when the threshing of said first pile is completed, the base 4 is thus nailed to the ground without being able to move laterally or pivot around any horizontal axis.
- a plurality of orifices and said first piles 6 are provided.
- the first step consists in descending to the bottom of the sea from the surface, said base equipped with said first terminal pipe element 2a of the resting pipe. at the bottom of the sea.
- anchoring of the transition piece 8 is carried out at the lower end of the vertical riser by fixing on the support and connection device 5, itself anchored on said base, thus forming a rigid recess of the lower end of the vertical riser.
- the support and connection device 5 consists of elements of rigid structure and stiffener 5c supporting said second fastening flange 5a and said second curved rigid pipe element 5b, said rigid structure elements 5c also ensuring the connection between said second flange fixing 5a and a lower plate 5d supporting on the underside a second tubular pile 5e called tubular anchoring insert.
- the various bottom-surface connection elements including the assembly of the trains consist of a plurality of standard pipe elements, which are gradually lowered.
- said device 5 is connected in a sealed manner to the lower end of the vertical riser 9 via the conical transition piece 8, then the entire vertical riser equipped with its buoyancy elements, and finally the flexible connecting pipe equipped with its buoyancy elements fixed in direct continuity with the upper end of the vertical riser 9.
- the assembly and the laying of the rigid pipe 9 are conventionally made from the ship 20 by assembling unit pipe elements or reams of unitary elements stored on the surface vessel 20, and descended as and when a technique known to those skilled in the art and described in particular in previous patent applications in the name of the applicant, from a laying ship in J.
- the rigid steel pipe 9 may be in known manner a Pipe-in-Pipe type pipe comprising an insulation system in the annular space between the two coaxial pipes constituting the riser 9 and furthermore a pipe system. insulation such as syntactic foam acting as a buoyancy system as described above.
- tubular anchoring insert 5e When the lower end of the tubular anchoring insert 5e, preferably having a slightly conical shape 5f is positioned close to and in line with the orifice 4a of the base 4, it is advantageous to direct said tubular insert anchoring 5th, more precisely thanks to an automatic submarine or "ROV" 20a piloted from the surface. Said tubular insert 5e of length 10 to 15 m then returns naturally by its own weight in said first tubular anchoring pile driven to the bottom of the sea to a depth of 30 to 70 m.
- ROV automatic submarine or
- the external diameter of the tubular anchoring insert 5e may be slightly smaller than the internal diameter of the first pile 6, for example less than 5 cm, which facilitates guiding the tubular insert 5 inside said first pile 6 while preventing transverse movements in a horizontal plane once the tubular insert 5 is fully inserted as shown in FIG. 3.
- a latch 4b shown in the retracted position in FIG. 2A is moved in the engaged position as in FIGS. 1 and 3 so as to block the upper plate 5d of the tubular insert 5e, inside said first pile. 6, thus preventing any upward movement of the bottom-surface connection assembly 1 which is recessed via the connection support device 5 in the first pile 6 integral with said base 4.
- the untightening of the flexible pipe is completed as shown in FIG. 3 and the upper end of the flexible pipe is connected to a temporary sub-surface buoy 21, itself connected to a dead body 21b resting at the bottom of the sea by a cable 21a.
- the floating support 12 is positioned on the surface, the end 10e of the flexible pipe 10 is recovered, which is then connected to said floating support FPSO 12 as shown in FIG. 1, and the temporary buoy 21 is recovered. as well as its dead body 21b and its anchoring cable 21a.
- the tubular insert 5e transmits to said first tubular pile 6, the bending moments due to the cutting and transverse forces experienced at the recess of the part 8 on the device 5.
- the fixing system of the upper end of the rigid pipe 9 with the flexible pipe 10 and the tensioning of said pipes gives greater stability to the upper end of the rigid pipe 9 with an angular variation Y not exceeding in operation the 5 ° C.
- the lower end pipe element of the rigid pipe 9 comprises a conical transition piece 8 whose inertia in cross section increases progressively from a value substantially identical to the inertia of the pipe element of the riser 9 to which it is connected, in the tapered upper part of the transition piece 8, to a value 3 to 10 times greater than the level of its lower part connected to said first attachment flange 9a.
- inertia The coefficient of variation of inertia essentially depends on the bending moment that the vertical riser must bear at said transition piece, said moment being a function of the maximum excursion of the upper part of the rigid steel pipe 9, therefore of the angle Y.
- transition piece 8 To achieve this transition piece 8 is used high tensile steels and in extreme cases of stress, it may be necessary to manufacture titanium transition parts 8.
- FIG. 4 shows a cylindro-conical transition piece 8 having a variable thickness gradually increasing from the tapered upper part 81 to the thicker lower part 82 with a constant internal diameter corresponding to the internal diameter of a pipe standard rigid and in any event, the internal diameter of said second rigid pipe element 6.
- the transition piece 8 consists of a main steel pipe element 8a, preferably of internal diameter di identical to that of the current part of the pipe 9, and preferably of thickness equal to or slightly greater than that of said running portion of said pipe 9, and preferably of thickness equal to that of said second pipe element bent 5b.
- transition piece 8 comprising a first internal pipe element 8a and three element 8b-8c-8d coaxial reinforcement pipe of increasing diameter d 2 -d 3 -d 4 and lengths h 2 -h 3 -h 4 decreasing, each of said coaxial pipe elements being integral with its lower end of the same said first flange 9a.
- an elastomeric material 8e preferably such as a polyurethane, whose shore hardness is adjusted to obtain the desired stiffness variation, in particular a shore hardness of A50 to D70.
- the lower end of the first main pipe element 8a of greater length is welded to the flange 9a, and
- a coaxial first reinforcing pipe element 8b is inserted around said first main pipe element 8a, the lower end of which is welded to the same flange 9a, and
- a third reinforcing pipe element 8d of smaller height is inserted around the second reinforcing pipe element 8c, and its lower end is welded to the flange 9a, and
- thermoplastic or thermosetting material is injected between the various pipe elements, and, if necessary, their external surface is coated with a cylindro-conical mold to obtain rigidity and variation of inertia and protection against corrosion; sought.
- FIG. 6 shows the variation diagram of the inertia I on the ordinate between the flange 9 and the upper end of the transition piece 8 of FIGS. 5B and 5C.
- the dashed staircase 30 represents the variation of the steel section in the absence of roofing and filling material at each of the reinforcing pipe members.
- the curves 31-32-33 represent the variation of the inertia ( ⁇ EI) of the transition piece 8 of FIGS. 4 and 5C as a function of its length, according to the type of filling material.
- Curve 33, of parabolic shape is obtained with a polyurethane filling material of shore hardness A90 or A95, and is a preferred version of the invention.
- the curve 31 is obtained with a much stiffer material, such as a cement with very high performance, alone or in combination with a powdery load, such as sand.
- Intermediate curve 32 corresponds to the steel transition piece of FIG. 4.
- the space between the first pipe 8a and the first reinforcement 8b is 53.98mm, and the space between the second reinforcement and the first reinforcement is 70.2mm.
- FIG. 3A the invention is described with a base 4 placed at the same time as the underwater pipe resting on the bottom, said base being stabilized by a first pile 6 passing therethrough.
- a base 4 constituted by a suction anchor, having an orifice, preferably circular integrated in said suction anchor and playing the role of pile 6 and capable to receive the anchoring insert 5e.
- the support and connecting device 5 at the lower end of the bottom-surface connection is directly embedded in the suction anchor whose weight reaches 25 to 50 tons for a diameter of 3 to 5 m and a height of 20-25m.
- the sub driving Marine 2 is placed independently and therefore requires a connecting pipe 7 manufactured on demand after installation of the bottom-surface connection and the underwater pipe 2.
- Said connecting pipe 7 then requires two automatic connectors 7- 7ai, 7bi-7b, one at each of its ends, while the version described with reference to Figure 3A requires only one automatic connector 7a-7b.
- the invention has been described in a preferred version manufactured and simultaneously installed on site from a laying ship 20, but it remains in the spirit of the invention with a prefabrication of the complete set on a shipyard on land , the assembly then being towed substantially horizontally to the site, then finally cabin for the insertion of the anchoring insert 5e in the first tubular pile 6.
Landscapes
- 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)
- Laying Of Electric Cables Or Lines Outside (AREA)
- Sewage (AREA)
Abstract
Description
Claims
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
FR0852771A FR2930587A1 (fr) | 2008-04-24 | 2008-04-24 | Installation de liaison fond-surface d'une conduite rigide avec une conduite flexible a flottabilite positive et une piece de transition d'inertie |
PCT/FR2009/050684 WO2009138609A2 (fr) | 2008-04-24 | 2009-04-14 | Installation de liaison fond-surface d'une conduite rigide avec une conduite flexible a flottabilite positive |
Publications (2)
Publication Number | Publication Date |
---|---|
EP2286056A2 true EP2286056A2 (fr) | 2011-02-23 |
EP2286056B1 EP2286056B1 (fr) | 2012-07-25 |
Family
ID=39926529
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
EP09745928A Active EP2286056B1 (fr) | 2008-04-24 | 2009-04-14 | Installation de liaison fond-surface d'une conduite rigide avec une conduite flexible a flottabilite positive |
Country Status (5)
Country | Link |
---|---|
US (1) | US8430170B2 (fr) |
EP (1) | EP2286056B1 (fr) |
BR (1) | BRPI0911162B1 (fr) |
FR (1) | FR2930587A1 (fr) |
WO (1) | WO2009138609A2 (fr) |
Cited By (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US8905143B2 (en) | 2009-11-25 | 2014-12-09 | Subsea 7 Limited | Riser configuration |
Families Citing this family (20)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO2007108672A1 (fr) * | 2006-03-22 | 2007-09-27 | Itrec B.V. | Pré-assemblage d'une base sous-marine et d'un pipeline |
US20110017463A1 (en) * | 2009-07-23 | 2011-01-27 | Schlumberger Technology Corporation | Use of a spoolable compliant guide and coiled tubing to clean up a well |
FR2952671B1 (fr) * | 2009-11-17 | 2011-12-09 | Saipem Sa | Installation de liaisons fond-surface disposees en eventail |
US8657012B2 (en) * | 2010-11-01 | 2014-02-25 | Vetco Gray Inc. | Efficient open water riser deployment |
FR2971322B1 (fr) | 2011-02-03 | 2014-05-02 | Saipem Sa | Limiteur de courbure de ligne flexible sous-marine et installation de liaison fond-surface en comprenant |
FR2973473B1 (fr) | 2011-03-29 | 2014-06-13 | Saipem Sa | Materiau d'isolation thermique et/ou de flottabilite rigide pour conduite sous-marine |
US9334695B2 (en) * | 2011-04-18 | 2016-05-10 | Magma Global Limited | Hybrid riser system |
WO2013036915A2 (fr) * | 2011-09-09 | 2013-03-14 | Horton Wison Deepwater, Inc. | Limiteur de courbure d'un tube-conducteur |
US8863682B2 (en) | 2011-09-09 | 2014-10-21 | Horton Wison Deepwater, Inc. | Helical bend restrictor |
FR2988424B1 (fr) * | 2012-03-21 | 2014-04-25 | Saipem Sa | Installation de liaisons fond-surface de type tour hybride multi-risers comprenant des conduites flexibles a flottabilite positive |
US8919448B2 (en) * | 2012-04-13 | 2014-12-30 | Mitchell Z. Dziekonski | Modular stress joint and methods for compensating for forces applied to a subsea riser |
BR102013012413B1 (pt) * | 2013-05-20 | 2021-09-08 | Petróleo Brasileiro S.A. / Petrobras | Sistema de transferência híbrido reverso |
CN104329044A (zh) * | 2014-10-09 | 2015-02-04 | 中国海洋石油总公司 | 自由站立式立管底部连接结构 |
GB2563701A (en) * | 2015-12-21 | 2018-12-26 | Halliburton Energy Services Inc | In situ length expansion of a bend stiffener |
WO2017209914A1 (fr) * | 2016-06-01 | 2017-12-07 | Terves Inc. | Caoutchouc soluble |
US11313179B2 (en) | 2018-03-26 | 2022-04-26 | Odebrecht Oleo E Gas S.A. | System for connecting between risers of composite material and flowlines, which can be used with a hybrid riser, and method for constructing same |
US11009151B2 (en) * | 2019-09-06 | 2021-05-18 | Trinity Bay Equipment Holdings, LLC | Vertical pipe deployment system and method |
US11459067B2 (en) | 2019-12-05 | 2022-10-04 | Sofec, Inc. | Systems and processes for recovering a condensate from a conduit |
US10899602B1 (en) * | 2019-12-05 | 2021-01-26 | Sofec, Inc. | Submarine hose configuration for transferring a gas from a buoy |
US10794539B1 (en) | 2019-12-05 | 2020-10-06 | Sofec, Inc. | Systems and processes for recovering a vapor from a vessel |
Family Cites Families (29)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3181612A (en) * | 1961-07-07 | 1965-05-04 | Dow Chemical Co | Selective plugging of subterranean formations to inhibit intrusion of water into oil-producing strata |
US3363683A (en) * | 1965-12-23 | 1968-01-16 | Exxon Production Research Co | Offshore apparatus and method |
US3602319A (en) * | 1969-09-26 | 1971-08-31 | Global Marine Inc | Structure with varying cross-sectional moment of inertia |
FR2397084A1 (fr) * | 1977-07-06 | 1979-02-02 | Inst Francais Du Petrole | Embout de ligne flexible a raideur determinee variable |
US4182584A (en) * | 1978-07-10 | 1980-01-08 | Mobil Oil Corporation | Marine production riser system and method of installing same |
FR2616858B1 (fr) * | 1987-06-18 | 1989-09-01 | Inst Francais Du Petrole | Element a raideur variable pour pied de colonne de transfert |
FR2627542A1 (fr) * | 1988-02-24 | 1989-08-25 | Coflexip | Dispositif de transfert de fluide entre le fond sous-marin et la surface |
US5526846A (en) * | 1990-12-26 | 1996-06-18 | Coflexip | Stiffener with reinforced structure |
US5320175A (en) * | 1993-01-29 | 1994-06-14 | Shell Oil Company | Subsea wellhead connections |
US5582252A (en) * | 1994-01-31 | 1996-12-10 | Shell Oil Company | Hydrocarbon transport system |
US5520422A (en) * | 1994-10-24 | 1996-05-28 | Ameron, Inc. | High-pressure fiber reinforced composite pipe joint |
FR2741696B1 (fr) * | 1995-11-29 | 1998-01-02 | Coflexip | Raidisseur pour une canalisation flexible a usage en milieu marin |
US5944448A (en) * | 1996-12-18 | 1999-08-31 | Brovig Offshore Asa | Oil field installation with mooring and flowline system |
US5873677A (en) * | 1997-08-21 | 1999-02-23 | Deep Oil Technology, Incorporated | Stress relieving joint for riser |
FR2768457B1 (fr) * | 1997-09-12 | 2000-05-05 | Stolt Comex Seaway | Dispositif de transport sous-marin de produits petroliers a colonne montante |
AU8950298A (en) * | 1997-10-27 | 1999-05-13 | Deep Oil Technology, Incorporated | Stress relief joint for risers |
GB9802421D0 (en) * | 1998-02-06 | 1998-04-01 | Head Philip | A riser system for sub sea wells and method of operation |
NO306826B1 (no) * | 1998-06-12 | 1999-12-27 | Norske Stats Oljeselskap | Anordning ved stigerör |
US7287598B2 (en) * | 2000-06-02 | 2007-10-30 | Allis-Chalmers Energy, Inc. | Apparatus for, and method of, landing items at a well location |
US6688930B2 (en) * | 2001-05-22 | 2004-02-10 | Fmc Technologies, Inc. | Hybrid buoyant riser/tension mooring system |
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 |
FR2839542B1 (fr) * | 2002-05-07 | 2004-11-19 | Bouygues Offshore | Installation de liaison fond-surface d'une conduite sous- marine comprenant un element de conduite coude maintenu par une embase |
AU2003270284A1 (en) * | 2002-10-10 | 2004-05-04 | Rockwater Limited | A riser and method of installing same |
FR2852677B1 (fr) * | 2003-03-18 | 2006-01-06 | Saipem Sa | Dispositif de rechauffage et d'isolation thermique d'au moins une conduite sous-marine |
US7096940B2 (en) * | 2003-10-20 | 2006-08-29 | Rti Energy Systems, Inc. | Centralizer system for insulated pipe |
US20070044972A1 (en) * | 2005-09-01 | 2007-03-01 | Roveri Francisco E | Self-supported riser system and method of installing same |
FR2911907B1 (fr) * | 2007-01-26 | 2009-03-06 | Technip France Sa | Installation de conduite montante flexible de transport d'hydrocarbures. |
US7628568B2 (en) * | 2007-01-29 | 2009-12-08 | Chevron U.S.A. Inc. | Hinge-over riser assembly |
WO2008144328A1 (fr) * | 2007-05-17 | 2008-11-27 | Chevron U.S.A. Inc. | Ensemble de terminaison de pipeline avec tige de raccordement et articulation basculante |
-
2008
- 2008-04-24 FR FR0852771A patent/FR2930587A1/fr active Pending
-
2009
- 2009-04-14 EP EP09745928A patent/EP2286056B1/fr active Active
- 2009-04-14 BR BRPI0911162A patent/BRPI0911162B1/pt active IP Right Grant
- 2009-04-14 WO PCT/FR2009/050684 patent/WO2009138609A2/fr active Application Filing
- 2009-04-14 US US12/988,775 patent/US8430170B2/en active Active
Non-Patent Citations (1)
Title |
---|
See references of WO2009138609A2 * |
Cited By (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US8905143B2 (en) | 2009-11-25 | 2014-12-09 | Subsea 7 Limited | Riser configuration |
Also Published As
Publication number | Publication date |
---|---|
BRPI0911162B1 (pt) | 2019-08-27 |
US20110042094A1 (en) | 2011-02-24 |
US8430170B2 (en) | 2013-04-30 |
WO2009138609A2 (fr) | 2009-11-19 |
WO2009138609A3 (fr) | 2010-05-20 |
BRPI0911162A2 (pt) | 2015-10-06 |
EP2286056B1 (fr) | 2012-07-25 |
FR2930587A1 (fr) | 2009-10-30 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
EP2286056B1 (fr) | Installation de liaison fond-surface d'une conduite rigide avec une conduite flexible a flottabilite positive | |
EP2844820B1 (fr) | Installation de liaisons fond-surface de type tour hybride multi-risers comprenant des conduites flexibles a flottabilite positive | |
EP1899219B1 (fr) | Dispositif de transfert de fluide entre deux supports flottants | |
EP1501999B1 (fr) | Installation de liaison fond-surface d'une conduite sous-marine reliee a un riser par un element de conduite soude maintenu par une embase | |
EP1917416B1 (fr) | Installation comprenant au moins deux liaisons fond-surface d au moins deux conduites sous-marines reposant au fond de la mer. | |
EP1073823B1 (fr) | Procede et dispositif de liaison fond-surface par conduite sous-marine installee a grande profondeur | |
EP2401468B1 (fr) | Installation de liaison fond-surface de type tour hybride multi-riser comprenant des modules de flottabilite coulissants | |
EP2501889B1 (fr) | Installation de liaisons fond-surface disposees en eventail | |
OA10874A (fr) | Dispositif de transport sous-marin de produits pétroliers à colonne montante | |
EP2268887B1 (fr) | Element de conduite de transition d'inertie notamment pour encastrement d'une conduite rigide sous-marine | |
EP2785952B1 (fr) | Installation de liaisons fond-surface flexibles multiples sur au moins deux niveaux | |
EP2571753B1 (fr) | Installation de liaison fond-surface comprenant une structure de guidage de conduite flexible | |
FR2938001A1 (fr) | Procede de montage d'une tour d'exploitation d'un fluide dans une etendue d'eau et tour d'exploitation associee. | |
FR3005484A1 (fr) | Dispositif d'ancrage d'un support de goulottes d'une installation fond-surface | |
EP2640923B1 (fr) | Tour d'exploitation de fluide dans une étendue d'eau et procédé d'installation associé. | |
OA17101A (en) | Installation de liaisons fond-surface de type tour hybride multi-risers comprenant des conduites flexibles à flottabilité positive. | |
FR3106644A1 (fr) | Conduite pour l’alimentation d’une unité de production d’énergie hydrothermique. |
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: 20101015 |
|
AK | Designated contracting states |
Kind code of ref document: A2 Designated state(s): AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HR HU IE IS IT LI LT LU LV MC MK MT NL NO PL PT RO SE SI SK TR |
|
AX | Request for extension of the european patent |
Extension state: AL BA RS |
|
DAX | Request for extension of the european patent (deleted) | ||
GRAP | Despatch of communication of intention to grant a patent |
Free format text: ORIGINAL CODE: EPIDOSNIGR1 |
|
GRAS | Grant fee paid |
Free format text: ORIGINAL CODE: EPIDOSNIGR3 |
|
GRAA | (expected) grant |
Free format text: ORIGINAL CODE: 0009210 |
|
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 HR HU IE IS IT LI LT LU LV MC MK MT NL NO 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: AT Ref legal event code: REF Ref document number: 567812 Country of ref document: AT Kind code of ref document: T Effective date: 20120815 Ref country code: IE Ref legal event code: FG4D Free format text: LANGUAGE OF EP DOCUMENT: FRENCH |
|
REG | Reference to a national code |
Ref country code: DE Ref legal event code: R096 Ref document number: 602009008525 Country of ref document: DE Effective date: 20120920 |
|
REG | Reference to a national code |
Ref country code: NL Ref legal event code: T3 |
|
REG | Reference to a national code |
Ref country code: AT Ref legal event code: MK05 Ref document number: 567812 Country of ref document: AT Kind code of ref document: T Effective date: 20120725 |
|
REG | Reference to a national code |
Ref country code: LT Ref legal event code: MG4D Effective date: 20120725 |
|
PG25 | Lapsed in a contracting state [announced via postgrant information from national office to epo] |
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: 20120725 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: 20120725 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: 20120725 Ref country code: HR 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: 20120725 Ref country code: NO 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: 20121025 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: 20121125 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: 20120725 |
|
PG25 | Lapsed in a contracting state [announced via postgrant information from national office to epo] |
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: 20120725 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: 20120725 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: 20121026 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: 20120725 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: 20121126 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: 20120725 |
|
PG25 | Lapsed in a contracting state [announced via postgrant information from national office to epo] |
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: 20120725 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: 20121105 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: 20120725 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: 20120725 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: 20120725 |
|
PG25 | Lapsed in a contracting state [announced via postgrant information from national office to epo] |
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: 20120725 Ref country code: IT 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: 20120725 |
|
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 |
|
26N | No opposition filed |
Effective date: 20130426 |
|
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: 20121025 |
|
REG | Reference to a national code |
Ref country code: DE Ref legal event code: R097 Ref document number: 602009008525 Country of ref document: DE Effective date: 20130426 |
|
BERE | Be: lapsed |
Owner name: SAIPEM SA Effective date: 20130430 |
|
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 FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20120725 |
|
REG | Reference to a national code |
Ref country code: CH Ref legal event code: PL |
|
REG | Reference to a national code |
Ref country code: IE Ref legal event code: MM4A |
|
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: 20130430 Ref country code: DE Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES Effective date: 20131101 Ref country code: LI Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES Effective date: 20130430 Ref country code: CH Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES Effective date: 20130430 |
|
REG | Reference to a national code |
Ref country code: DE Ref legal event code: R119 Ref document number: 602009008525 Country of ref document: DE Effective date: 20131101 |
|
PG25 | Lapsed in a contracting state [announced via postgrant information from national office to epo] |
Ref country code: IE Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES Effective date: 20130414 |
|
PG25 | Lapsed in a contracting state [announced via postgrant information from national office to epo] |
Ref country code: MT 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: 20120725 |
|
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: 20120725 |
|
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; INVALID AB INITIO Effective date: 20090414 Ref country code: LU Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES Effective date: 20130414 Ref country code: MK 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: 20120725 |
|
REG | Reference to a national code |
Ref country code: FR Ref legal event code: PLFP Year of fee payment: 8 |
|
REG | Reference to a national code |
Ref country code: FR Ref legal event code: PLFP Year of fee payment: 9 |
|
REG | Reference to a national code |
Ref country code: FR Ref legal event code: PLFP Year of fee payment: 10 |
|
P01 | Opt-out of the competence of the unified patent court (upc) registered |
Effective date: 20230517 |
|
PGFP | Annual fee paid to national office [announced via postgrant information from national office to epo] |
Ref country code: FR Payment date: 20230419 Year of fee payment: 15 |
|
PGFP | Annual fee paid to national office [announced via postgrant information from national office to epo] |
Ref country code: GB Payment date: 20230424 Year of fee payment: 15 |
|
PGFP | Annual fee paid to national office [announced via postgrant information from national office to epo] |
Ref country code: NL Payment date: 20240325 Year of fee payment: 16 |