EP1332260B1 - Plate-forme martime a bouees multiples articulees, dispositif et procede d'installation - Google Patents

Plate-forme martime a bouees multiples articulees, dispositif et procede d'installation Download PDF

Info

Publication number
EP1332260B1
EP1332260B1 EP01968663A EP01968663A EP1332260B1 EP 1332260 B1 EP1332260 B1 EP 1332260B1 EP 01968663 A EP01968663 A EP 01968663A EP 01968663 A EP01968663 A EP 01968663A EP 1332260 B1 EP1332260 B1 EP 1332260B1
Authority
EP
European Patent Office
Prior art keywords
platform
buoys
buoy
articulating
marine
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.)
Expired - Lifetime
Application number
EP01968663A
Other languages
German (de)
English (en)
Other versions
EP1332260A4 (fr
EP1332260A1 (fr
Inventor
Jon E. Khachaturian
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.)
Individual
Original Assignee
Individual
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
Priority claimed from US09/693,470 external-priority patent/US6425710B1/en
Application filed by Individual filed Critical Individual
Publication of EP1332260A1 publication Critical patent/EP1332260A1/fr
Publication of EP1332260A4 publication Critical patent/EP1332260A4/fr
Application granted granted Critical
Publication of EP1332260B1 publication Critical patent/EP1332260B1/fr
Anticipated expiration legal-status Critical
Expired - Lifetime legal-status Critical Current

Links

Images

Classifications

    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B63—SHIPS OR OTHER WATERBORNE VESSELS; RELATED EQUIPMENT
    • B63B—SHIPS OR OTHER WATERBORNE VESSELS; EQUIPMENT FOR SHIPPING 
    • B63B35/00—Vessels or similar floating structures specially adapted for specific purposes and not otherwise provided for
    • B63B35/44—Floating buildings, stores, drilling platforms, or workshops, e.g. carrying water-oil separating devices
    • B63B35/4413—Floating drilling platforms, e.g. carrying water-oil separating devices
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B63—SHIPS OR OTHER WATERBORNE VESSELS; RELATED EQUIPMENT
    • B63B—SHIPS OR OTHER WATERBORNE VESSELS; EQUIPMENT FOR SHIPPING 
    • B63B77/00—Transporting or installing offshore structures on site using buoyancy forces, e.g. using semi-submersible barges, ballasting the structure or transporting of oil-and-gas platforms
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B63—SHIPS OR OTHER WATERBORNE VESSELS; RELATED EQUIPMENT
    • B63B—SHIPS OR OTHER WATERBORNE VESSELS; EQUIPMENT FOR SHIPPING 
    • B63B1/00—Hydrodynamic or hydrostatic features of hulls or of hydrofoils
    • B63B1/02—Hydrodynamic or hydrostatic features of hulls or of hydrofoils deriving lift mainly from water displacement
    • B63B1/04—Hydrodynamic or hydrostatic features of hulls or of hydrofoils deriving lift mainly from water displacement with single hull
    • B63B1/048—Hydrodynamic or hydrostatic features of hulls or of hydrofoils deriving lift mainly from water displacement with single hull with hull extending principally vertically
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B63—SHIPS OR OTHER WATERBORNE VESSELS; RELATED EQUIPMENT
    • B63B—SHIPS OR OTHER WATERBORNE VESSELS; EQUIPMENT FOR SHIPPING 
    • B63B1/00—Hydrodynamic or hydrostatic features of hulls or of hydrofoils
    • B63B1/02—Hydrodynamic or hydrostatic features of hulls or of hydrofoils deriving lift mainly from water displacement
    • B63B1/10—Hydrodynamic or hydrostatic features of hulls or of hydrofoils deriving lift mainly from water displacement with multiple hulls
    • B63B1/107—Semi-submersibles; Small waterline area multiple hull vessels and the like, e.g. SWATH
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B63—SHIPS OR OTHER WATERBORNE VESSELS; RELATED EQUIPMENT
    • B63B—SHIPS OR OTHER WATERBORNE VESSELS; EQUIPMENT FOR SHIPPING 
    • B63B21/00—Tying-up; Shifting, towing, or pushing equipment; Anchoring
    • B63B21/50—Anchoring arrangements or methods for special vessels, e.g. for floating drilling platforms or dredgers
    • B63B2021/505—Methods for installation or mooring of floating offshore platforms on site
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B63—SHIPS OR OTHER WATERBORNE VESSELS; RELATED EQUIPMENT
    • B63B—SHIPS OR OTHER WATERBORNE VESSELS; EQUIPMENT FOR SHIPPING 
    • B63B35/00—Vessels or similar floating structures specially adapted for specific purposes and not otherwise provided for
    • B63B35/44—Floating buildings, stores, drilling platforms, or workshops, e.g. carrying water-oil separating devices
    • B63B2035/442—Spar-type semi-submersible structures, i.e. shaped as single slender, e.g. substantially cylindrical or trussed vertical bodies

Definitions

  • the present invention relates to floating marine platforms in deep water environments (e.g., over 1500 feet or 450 meters) and methods of installing same. More particularly, the present invention relates to a novel multiple buoy platform that supports a platform with a plurality of buoys and method of installing same.
  • the present invention relates to a method wherein multiple buoys can be used as part of an installation method to place a marine platform upon a single spar support.
  • the present invention relates to a novel specially configured multiple device support enabling replacement of one device while the other supports the platform.
  • Marine platforms typically take the form of either fixed platforms that include a large underwater support structure or "jacket" or a floating platform having a submersible support. Sometimes these platforms are called semi-submersible rigs.
  • Jack-up barges are another type of platform that can be used in an offshore marine environment for drilling/production. Jack-up barges have a barge with long legs that can be powered up for travel and powered down to elevate the barge above the water.
  • the present invention provides an improved offshore marine platform (and method of installation) that can be used for drilling for oil and/or gas or in the production of oil and gas from an offshore environment.
  • Such drilling and/or production facilities typically weigh between 500-100,000 tons (508,025 kg-101,605,000 kg), more commonly between 3,000-50,000 tons (508,025 kg-50,802,500 kg).
  • the apparatus of the present invention thus provides a marine platform that is comprised of a plurality of spaced apart buoys and a superstructure having a periphery that includes a plurality of attachment positions, one attachment position for each buoy.
  • An articulating connection joins each buoy to the platform superstructure.
  • the apparatus of the present invention uses articulating connections between the submerged portion of each buoy and the superstructure to minimize or reduce topside, wave induced motions during the structural life of the apparatus.
  • Each of the buoys will move due to current and/or wind and/or wave action or due to other dynamic marine environmental factors.
  • "Articulating connection” as used herein should be understood to mean any connection or joint that connects a buoy to the superstructure, transmits axial and shear forces, and allows the support buoy(s) to move relative to the superstructure without separation, and wherein the bending moment transferred to the superstructure from one of the so connected buoys or from multiple of the so connected buoys is reduced, minimized or substantially eliminated.
  • "Articulating connection” can also be a joint movably connecting a buoy to a superstructure wherein axial and tangential forces are substantially transmitted, however, transfer of bending moment is substantially reduced or minimized through the joint allowing relative movement between the buoy and the superstructure.
  • a connection (which can be an articulating connection) connects each buoy to the platform at a respective attachment position, the connection allowing for sea state induced buoy motions while minimizing effects on the platform.
  • the apparatus of the present invention provides a marine platform that can further comprise a mooring extending from a plurality of the buoys for holding the platform and buoys to a desired location.
  • the present invention provides a marine platform wherein each ofthe articulating connections includes corresponding concave and convex engaging portions.
  • a universal type joint is disclosed.
  • a marine platform has buoys with convex articulating portions and the platform has correspondingly shaped concave articulating portions.
  • each buoy can be provided with a concave articulating portion and the platform with a convex articulating portion.
  • each buoy has a height and a diameter. In another embodiment, the height is much greater than the diameter for each of the buoys.
  • each buoy is preferably between about 25 and 100 feet in diameter (7.62m and 30.48m).
  • the apparatus of the present invention preferably provides a plurality of buoys, wherein each buoy is between about 100 and 500 feet in height (30.48m and 152.4m).
  • the buoys can be of a generally uniform diameter along a majority of the buoy. However, in an alternative embodiment each buoy can have a variable diameter.
  • each buoy is generally cylindrically shaped.
  • each buoy can be provided with simply an upper end portion that is generally cylindrically shaped.
  • each articulated connection is preferably hemispherically shaped for the upper end portion of each buoy and there is a correspondingly concavely shaped receptacle on the platform that fits the surface of each hemispherically shaped upper end portion.
  • connection can also be in the form of a universal j oint.
  • connection can be in the form of first and second devices that provide "backup" or redundancy enabling one device to be serviced while the other supports the platform.
  • a first universal joint preferably carries load between the platform and each buoy over the long period of time.
  • a jacking arrangement loads the other device so that the first device does not carry load and can be removed.
  • the devices can include an inner device and an outer device.
  • the "devices" can be articulating devices such as universal joints.
  • the platform is comprised of a trussed deck.
  • the trussed deck preferably has lower horizontal members, upper horizontal members and a plurality of inclined members spanning between the upper and lower horizontal members, and wherein the attachment positions are next to the lower horizontal member.
  • the apparatus supports an oil and gas well drilling and/or production platform weighing between 500 and 100,000 tons (508,025 kg and 101,605,000 kg), more particularly, weighing between 3,000 tons and 50,000(3,048,150 kg and 50,802,500 kg).
  • An advantage of the present invention is that it enables smaller, multiple hull components to be used to support the superstructure when compared to a single column or single buoy floater.
  • An advantage of the present invention is that topside angular motion can be reduced when compared to the topside angular motion of a single column floater of comparable weight.
  • the present invention there is substantially no bending moment or minimum bending moment transferred between each buoy and the structure being supported.
  • the present invention thus minimizes or substantially eliminates moment transfer at the articulating connection that is formed between each buoy and the structure being supported.
  • the buoys are thus substantially free to move in any direction relative to the supported structure or load excepting motion that would separate a buoy from the supported structure.
  • the present invention has particular utility in the supporting of oil and gas well drilling facilities and oil and gas well drilling production facilities.
  • the apparatus of the present invention has particular utility in very deep water, for example, in excess of 1500 feet (4572m).
  • the present invention also has particular utility in tropical environments (for example West Africa and Brazil) wherein the environment produces long period swell action.
  • an oil and gas well facility such as a drilling facility or a production facility on a platform in an offshore deepwater marine environment.
  • deepwater as used herein means water depths of in excess of 1500 feet (4572m).
  • the method of the present invention contemplates the placement of a plurality of buoys at a selected offshore location, a portion of each of the buoys being underwater.
  • a superstructure extends above water and includes a platform having an oil and gas well facility. Such a facility can include oil well drilling, oil well production, or a combination of oil well drilling and production.
  • the platform and its facility can be floated to a selected location.
  • the platform includes a peripheral portion having a plurality of attachment positions, one attachment position for each buoy.
  • the platform is ballasted relative to the buoys until the buoys connect with the platform.
  • This connection can be achieved by either ballasting the platform downwardly (such as for example, using a ballasted transport barge), or by ballasting the buoys to a higher position so that they engage the supported platform.
  • the buoys can be elongated, cylindrically shaped buoys, each having a diameter of for example, 25 - 100 feet (7.62m - 30.48m) and a height of preferably between about 100 and 500 feet (30.48m and 152.4m).
  • Each of the buoys can have an upper, smaller diameter portion that includes a connector.
  • the connector can be convex in shape and articulate with a correspondingly shaped concave connector on the platform.
  • the platform can include a trussed deck that carries at or near its periphery or corners, connectors that enable a connection to be formed with the upper end portion of each buoy.
  • a trussed deck that carries at or near its periphery or corners, connectors that enable a connection to be formed with the upper end portion of each buoy.
  • each buoy can be any type of an articulating connection that forms an articulation with the trussed deck or a connector on the trussed deck. Examples include the ball and socket or concave/convex arrangement shown in the drawings ( Figures 1-12 ). Another example includes the universal joint shown in the drawings (see Figures 13-14 ).
  • the multiple buoys can be used as part of an installation method to place the marine platform upon a single spar support.
  • FIGS 1-6 show a preferred embodiment of the apparatus of the present invention designated generally by the numeral 10 in Figures 1-4 .
  • floating marine platform apparatus 10 is shown in a marine environment or ocean 12 having a water surface 11.
  • the apparatus 10 includes a plurality of buoys 13-16, preferably four (optionally between three (3) and eight (8)), that support a superstructure defined by the combination of platform 17 and drilling and/or producing facilities 53.
  • Oil and gas well producing facility as used herein shall include a facility used for oil and gas well drilling or production, or a combination of drilling and production.
  • Buoys 13-16 can be any desired shape, including the alternate buoys shown in the drawings or buoys with configurations like those in the September 2000 issue of Offshore Magazine.
  • Platform 17 can be any desired platform or rig, such as a trussed deck constructed of a plurality of upper horizontal members 18, a plurality of lower horizontal members 19, a plurality of vertical members 20 and a plurality of diagonal members 21 to define a trussed deck or platform 17.
  • platform 17 can include any desired oil and gas drilling and/or production facility 53, such facilities (in combination with platform 17) defining a superstructure weighing between about 500 - 100,000 tons(508,025 kg - 101,605,000 kg), or between about 3,000 - 50,000 tons (3,048,150 kg - 50,802,500 kg). (See Figures 3 and 8 ).
  • Each buoy 13-16 has an upper end portion 22 that can be conically shaped at 23 (see Figures 5-6 ).
  • An attachment portion 24 provides a convex upper surface 25 that receives a correspondingly shaped concave surface 26 of connecting portion 27 of platform 17.
  • the concave surface 26 can be generally hemispherically shaped. However, the concave surface 26 is curved to articulate upon the surface 25. Surface 26 is preferably smaller than a full hemispherical surface, sized to articulate upon surface 25 even wherein there is an angular variation that can be as much as 30 degrees (or more) between the central longitudinal axis 28 of buoy 13 and a pure horizontal plane 29.
  • bearing materials may be used in the articulating connections. A preferred bearing material would be a graphite impregnated brass or bronze bushing.
  • each buoy 13-16 can be reinforced with a plurality of vertical plates 30 as shown in Figure 6 .
  • the connection portion 27 of platform 17 can be provided with a plurality of internal reinforcing plates 35.
  • the plates 35 extend between upper curved plate 36 and lower curved plate 37.
  • a conical plate 38 can be attached to (or can be integral with) upper curved plate 36 as shown in Figure 6 .
  • a square harness articulating connection (not shown) going around the primary articulating connection may also be used.
  • Platform apparatus 10 can be secured to the sea bed 51 using piling or anchors 52 and mooring lines 32, 41 ( Figures 1-4, 8 ).
  • one or more mooring lines 32 extend from each buoy 13-16 at an upper padeye 31 to the sea bed 51.
  • the mooring lines in Figures 1 , 2 , 3 and 4 extend between padeyes 31 and anchors 52 at sea bed 51.
  • a plurality of horizontal mooring lines 34 extend between lower padeyes 33 on two buoys 13, 14 as shown in Figure 1 . While the lower horizontal mooring lines 34 are shown connecting to buoys 13, 14, it should be understood that each pair of buoys (14-15, 15-16, 16-13) has a horizontal line 34 extending there between in the same configuration shown in Figure 1 .
  • Figure 7 shows a first alternate embodiment of the present invention, utilizing tensioned mooring lines 39 that extend between connection points (for example, padeyes) 40 on each of the buoys 13-16 and anchors (such as 52) embedded in the sea bed 51.
  • horizontal mooring lines 34 could optionally be provided between each pair of buoys such as 13 and 14, or 14 and 15, or 15 and 16, or 16 and 13.
  • Figure 8 shows an alternate arrangement wherein caternary mooring lines 41 extend between padeyes 31 and the anchors 52 that are anchored to the sea bed 51. In this embodiment, there are no horizontal lines connecting the buoys.
  • FIG. 2 The plan view of Figure 2 shows various orientations that could be used for either mooring lines 32 or mooring lines 41.
  • One arrangement provides a plurality of three mooring lines 32 or 41 attached to each buoy 13-16, the mooring lines 32 or 41 being spaced about 120 degrees apart as shown in hard lines.
  • phantom lines in Figure 2 another geometry for the mooring lines 32, 41 is shown, wherein there are two mooring lines for each buoy that are about 90 degrees apart.
  • the platform 17 is constructed of upper and lower sets of horizontal members 18, 19; vertical members 20; and diagonal members 21.
  • FIGS 9, 10 and 10A show an alternate construction for each of the buoys. It should be understood that a buoy such as one of those shown in Figures 9, 10 or 10A could be used to replace any one or all of the buoys 13-16 shown in Figures 1-4 and 5-6 .
  • Buoy 42 can be provided with a variable diameter having a smaller diameter cylindrical middle section 43, and a larger diameter lower section 44 which can be for example, either cylindrical (see Figure 10 ) or squared (see Figure 10A ).
  • the cylindrical lower section 44 is shown in Figures 9 and 10 , and the squared lower section 45 shown in Figure 10A .
  • FIG. 11 and 12 Another buoy construction is shown in Figures 11 and 12 . It should be understood that the buoy shown in Figures 11 and 12 could be used to replace any one or all of the plurality of buoys 13-16 of Figures 1-6 .
  • the buoy 46 has a cylindrical middle section 47, a conical upper section 48, and a trussed lower section 49. Padeyes 50 on the upper end portion of trussed lower section 49 can be used to support any of the earlier described mooring lines such as 32, 39, or 41.
  • each ofthe buoys 46 can have a similar construction and configuration at the upper end portion to that of a preferred embodiment shown in Figures 1-6 , providing a conical upper section 48 and an attachment portion 24.
  • FIGs 13 and 14 there can be seen an alternate articulating connection between platform 17 and a selected buoy 13 (or 14-16 or 42, or 46).
  • a gimble or universal joint 62 arrangement is shown in Figures 13 and 14 , providing a first pinned connection at 54 and a second pinned connection at 55.
  • the first pin 56 can be of a larger diameter, having a central opening 58 through which the second, smaller diameter pin 57 passes as shown.
  • the central longitudinal axes of the pins 54, 55 preferably intersect.
  • Arrow 59 in Figures 13-14 shows that a buoy can optionally be made to rotate relative to the gimbal connection shown.
  • Bearing plates 60, 61 can rotate relative to one another. To minimize frictional force transference and wear, both pins 56,57 can be mounted in bearings.
  • FIGs 15-25 show a fifth embodiment of the apparatus of the present invention, designated generally by the numeral 63 in Figure 15 .
  • Floating marine platform apparatus 63 is shown in Figure 15 as including a platform 17 that can include a structural deck, package, platform, trussed deck or the like which has been shown in phantom lines.
  • platform 17 shown in Figure 15 can include a structural deck 64 or any other structural frame that is known in the art for supporting an offshore oil and gas well drilling platform, and oil and gas well production facility, or an oil and gas well drilling and production facility 67.
  • Platform 17 can include a structural deck which is schematically illustrated using the numeral 64 in Figures 15-25 including a superstructure (e.g. with an oil drilling platform, oil production platform, crew quarters, heliport, vessels, and the like). A plurality of connections are shown, a connection interfacing between each buoy 13, 14, 15, 16 and the platform 17 to be supported.
  • a superstructure e.g. with an oil drilling platform, oil production platform, crew quarters, heliport, vessels, and the like.
  • connection that is positioned in between each buoy such as buoy 13 and platform 17 is preferably a connection that includes first and second connection devices and a load transfer mechanism that can transfer at least some of the platform load from one of the devices to the other device.
  • these devices preferably include an internal device 65 (see Figure 24 ) and an external device 66 (see Figure 25 ).
  • the internal 65 and external 66 devices are preferably articulating connections.
  • the devices 65, 66 are preferably each universal joint connections.
  • a load transfer mechanism enables load to be transferred from one of the devices 65 or 66 to the other device 65 or 66.
  • This load transfer mechanism is preferably a jacking system such as the plurality of hydraulic jacks 119 that are shown in the drawings.
  • a deck opening 68 is shown through which the internal device 65 can be removed for servicing.
  • the internal device 65 can be the device that typically carries a portion of the platform load for a majority of the time and transfers that load to its buoy such as buoy 13.
  • padeyes 69 are provided each having an opening 70 as shown in Figure 25 .
  • the details of construction of the internal device 65 are shown in Figure 24 .
  • the internal device 65 includes a lower section 71, and upper section 82, and pins 77, 90.
  • the lower section 71 has a bottom 72 that transfers load to the upper surface 124 of buoy 13.
  • a jacking mechanism such as the plurality of hydraulic jacks 119 lift the lower section 71 from upper surface 124 of buoy 13, as shown in figure 22 .
  • a gap 123 is then present in between the upper surface 124 of buoy 13 and the bottom 72 of lower section 71. In such a position (shown in Figure 22 ), pin 120 can be removed and the internal device 65 can be lifted upwardly and withdrawn through opening 68 in structural deck 64.
  • Lower section 71 has sides 73, a top 74 and a pair of padeyes 75 that are spaced apart and which extend from the top 74. Each padeye 75 has pin opening 76. A smaller pin 77 has enlarged head 78 and externally threaded section 79. Nut 80 provides an internally threaded section 81 that enables the nut 80 to be threadably engaged to the pin 77 at threads 79. Upper section 82 of internal device 65 provides sides 83 and payeyes 84 that extend downwardly as shown in Figure 24 , each padeye 84 providing a pin opening 85.
  • Upper section 82 provides a pair of spaced apart beams 86, each having end portions 87, 88. Each end portion 87, 88 provides a pin opening 97.
  • a larger pin 90 fits through openings 85 as indicated schematically by arrow 126 in Figure 24 .
  • Pin 90 has enlarged head 91, and externally threaded section 92. Larger pin 90 also provides an opening 93 that is positioned in between externally threaded section 92 and head 91 as shown in Figure 24 .
  • Nut 94 has internally threaded section 95 that enables the nut to be threadably engaged with the larger pin 90.
  • a gap 96 is provided in between the beams 86 so that padeyes 69 on structural deck 64 fit in between the spaced apart beams 86 in gap 96 as shown in the drawings (see Figures 16 and 18 ).
  • the openings 70 of padeyes 69 align with the openings 97 of beams 86.
  • Pins 120 can then be placed through the aligned openings 70, 97.
  • larger pin 90 is first passed through openings 85 of padeyes 84. Nut 94 is then threadably engaged with pin 90 at correspondingly engaging threaded portions 92, 95.
  • the pin 77 is then placed through one of the openings 76 of padeye 75, and then through opening 93 of larger pin 90 and then through the opposite opening 76 of padeye 75.
  • Nut 80 then retains smaller pin 77 by engaging the threaded portions 79, 81.
  • the internal device 65 defines a first universal joint (see Figure 23 ) that can be removed as shown by arrow 128 in figure 23 for servicing.
  • the devices 65, 66 can be universal joints as shown. Each of the universal joints each have multiple pins 77,90 (for device 65) and 110 (for device 66) with central longitudinal axes, the central axes of the pins 77, 90 and 110 of both universal joints occupying a common plane during use.
  • External device 66 When the internal device 65 is removed for servicing, the external device 66 carries a portion of the platform load between structural deck 64 and buoy 13.
  • the external device 66 is shown more particularly in Figure 25 .
  • External device 66 includes a pair of spaced apart lower supports 98, each having a pair of spaced apart padeyes 99, each of the padeyes 99 providing a pin opening 100.
  • a pair of lower beams 101 are provided, a beam 101 being pivotally attached to each lower support 98 as shown in Figure 25 .
  • Each lower beam 101 provides end portions 102, 103, each of the end portions 102, 103 providing an upper surface 104 that carries a hydraulic jack 119.
  • Each of the lower beams 101 provides a beam opening 105 that receives a pin 110 when the opening 105 aligns with openings 100 of padeyes 99.
  • the external device 66 includes a pair of spaced apart supports 115 that are connected (eg. welded or bolted) to the underside of structural deck 64 for transferring load from the external device 66 to structural deck 64.
  • Upper beams 106 are pivotally attached to upper supports 115 using pins 110.
  • Each of the upper supports 115 has a pair of spaced apart padeyes 116, each padeye 116 having an opening 117 for receiving a pin 110.
  • Each upper beam 106 provides end portions 107, 108 having a lower surface 109 that is engaged by an elevating portion 129 of hydraulic jack 119 when load is to be carried by the external device 66. It should be understood that the hydraulic jacks 119 are commercially available such as from Enerpac.
  • Each pin 110 has an enlarged head 111 and an externally threaded section 112. Pins 110 are retained in position using nuts 113. Each nut 113 has an internally threaded section 114 that engages the externally threaded section 112 ofpin 110. Each ofthe upper beams 106 has a beam opening 118 that receives pin 110. In order to effect the pivotal connection between upper supports 115 and upper beams 106, pins 110 are passed through the openings 117 of padeyes 116 and the beam openings 118. The pins 110 are then secured by fastening a nut 113 to threaded section 112.
  • the internal device 65 carry load between a buoy (for example 13), and structural deck 64 a majority ofthe time. Therefore, there is typically a small gap between the elevating portion 129 of each jack 119 and the undersurface 109 of beam ends 107, 108. In such a situation, the bottom 72 of lower section 71 of internal device 65 bears against the upper surface 124 of buoy 13. In order to service the internal device 65 (or to replace it), the hydraulic jacks 119 are actuated so that elevating portion 129 elevates until the elevating portion 129 engages lower surface 109 of each beam end 107, 108.
  • arrow 153 designates travel of a transport barge 163 toward a plurality of buoys 13, 14, 15, 16 that have been positioned at a desired location. Buoys 13, 14, 15, 16 are held in that position using for example, a plurality of anchor lines 32 as shown in Figures 26-30 .
  • Transport barge 163 provides an upper deck 164, a bottom 165, a port side 166 and a starboard side 167.
  • the barge 163 also has end portions 154, 155.
  • Transport barge 163 can be any suitable barge having a length, width, and depth that are suitable for transporting a multi-ton superstructure to a job site.
  • a superstructure 53 mounted upon platform 17 will be a multi-ton structure that is capable of performing oil and gas well drilling activities and/or oil and gas well production activities.
  • barge 163 has been positioned next to the plurality of buoys 13,14, 15, 16.
  • the transport barge 163 has been positioned so that the buoys 13, 16 are on the starboard side 167 of transport barge 163.
  • the buoys 14, 15 are positioned on the port side 166 of transport barge 163 as shown in Figures 26-28 and 30.
  • a ballasting operation moves the buoys 13, 14, 15, 16 into contact with the platform 17 so that a connection is perfected. More specifically, the attachment portions 24 of the respective buoys 13, 14, 15, 16 engage and form an articulating connection with the corresponding connecting portions 27 of platform 17 as shown in Figures 26-28 and in Figures 1-8 and 13-14 .
  • Ballasting can be achieved by initially adding water to the buoys 13, 14, 15, 16 so that they are at a lower position in the water as shown in Figures 26 and 29-30 .
  • the water can then be pumped from the interior of each of the buoys 13, 14, 15, 16 as indicated schematically by the numeral 60 in Figure 27 .
  • the water level 151 in each of the buoys 13-16 will drop and each of the buoys 13-16 will rise as indicated schematically by arrows 170 in Figure 27 .
  • Each of the buoys 13, 14, 15, 16 will be ballasted upwardly in the direction of arrows 170 until its attachment portion 24 forms a connection with the connecting portion 27 of platform 17.
  • the barge 163 can be positioned as shown in Figures 26 and 30 . The barge 163 can then be lowered so that the barge 163, platform 17 and drilling/production facility 53 lower with it until the connection portions 27 of platform 17 rest upon the attachment portions 24 of the buoys 13-16.
  • ballasting of barge 163 and buoys 13, 14, 15, 16 can be used to connect each of the attachment portions 24 of buoy 13, 14, 15, 16 to platform 17 so that the attachments shown in Figures 1 , 2 , 3 , 4 , 7 , 8 are achieved.
  • barge 163 can be lowered using ballasting while buoys 13, 14, 15, 16 are simultaneously elevated using ballasting.
  • ballasting arrangement can be provided wherein the pinned connections 54, 55 are added after the platform 17 and buoys 13, 14, 15, 16 are at the proper elevational positions relative to one another.
  • the superstructure that includes platform 17 and facility 53 is supported as shown in Figure 28 , the superstructure (platform 17 and facility 53) can be placed upon a single spar support 156 if desired using the apparatus 10 of the present invention as a transfer apparatus.
  • tow boats 159 can be used to tow each buoy 13, 14, 15, 16 to spar 156.
  • each boat 159 can provide a tow line 160 attached to a buoy 13, 14, 15 or 16, or to deck 17 at a provided attachment 161.
  • the boats 159 pull buoys 13, 14, 15, 16 to a position as shown that overlays platform 17 with upper end portion 157 of spar 156. Ballasting can then be used to either elevate spar 156 or lower buoys 13, 14, 15, 16 (or a combination of such ballasting can be used) to engage spar 156 upper end portion 157 with platform 17 as indicated by arrow 162 in Figure 34 .
  • ballasting separates each buoy 13, 14, 15,16 from platform 17 so that spar 156 alone supports platform 17 and its facility 53 (see Figure 35 ).

Landscapes

  • Engineering & Computer Science (AREA)
  • Combustion & Propulsion (AREA)
  • Ocean & Marine Engineering (AREA)
  • Mechanical Engineering (AREA)
  • Chemical & Material Sciences (AREA)
  • Structural Engineering (AREA)
  • Civil Engineering (AREA)
  • Architecture (AREA)
  • Transportation (AREA)
  • Earth Drilling (AREA)
  • Load-Engaging Elements For Cranes (AREA)
  • Cleaning Or Clearing Of The Surface Of Open Water (AREA)
  • Bridges Or Land Bridges (AREA)

Abstract

L'invention concerne une plate-forme maritime (17) et son procédé d'installation. La plate-forme (17), qui comporte plusieurs bouées (13-16), présente une partie périphérique à plusieurs positions d'amarrage (27) pour les différentes bouées, et une attache (24,27) pour chaque bouée, entre la bouée et la plate-forme, correspondant aux positions d'amarrage respectives ( 27), ce qui autorise les mouvements induits par la mer mais réduit au minimum l'effet de ces mouvements sur la plate-forme (17). Chaque attache (24,27) peut présenter des premier et second éléments (65,66) (ou appareils) et un mécanisme de transfert de charge entre les premier (65) et second (66) éléments permettant l'entretien de l'un des éléments (ou appareils). Selon une variante, l'invention concerne un procédé d'installation de la plate-forme (y compris pour le forage pétrolier et gazier et/ou pour l'exploitation d'unité de production) à proximité des bouées (13 -16). Un système de ballast permet de déplacer la plate-forme (17) et les bouées (13-16) en relation mutuelle jusqu'au réglage parfait des attaches (24,27) entre chaque bouée (13-16) et la plate-forme (17).

Claims (19)

  1. Plateforme marine (10) comprenant :
    a) une pluralité de flotteurs (13, 14, 15, 16) ;
    b) une plateforme (17) ayant des installations de production de puits de pétrole et de gaz (53) et une partie périphérique (19) qui inclut une pluralité de positions de connexion, une position de connexion pour chaque flotteurs (13, 14, 15,16) ; et
    c) une pluralité de connexions d'articulation (27) chacune reliant l'un de la pluralité des flotteurs (13, 14, 15,16) à la plateforme (10) en une position respective de connexion, la pluralité des connexions (27) permettant le mouvement des flotteurs induit par le mouvement de la mer tout en réduisant l'effet du mouvement de la mer sur la plateforme (10) ;
    caractérisée en ce que chaque connexion d'articulation (27) permet le mouvement de chacun des flotteurs respectif (13, 14, 15,16,) par rapport à la plateforme (10) de façon que des forces axiales et tangentielles entre la plateforme (10) et chacun des flotteurs (13,14,15,16) soient transmis, tout en réduisant ou minimisant le transfert du mouvement de pliage ; et
    en ce que chacun des flotteurs (13, 14, 15,16) est sensiblement libre de se mouvoir dans toutes directions par rapport à la plateforme excepté le mouvement qui entraînerait une séparation du flotteur (13, 14,15,16) de la plateforme (10).
  2. Plateforme marine (10) selon la revendication 1, caractérisée en ce qu'elle comporte en outre une amarre (32) s'étendant à partir d'une pluralité de flotteurs (13,14,15,16) pour maintenir la plateforme (10) et les flotteurs (13,14,15,16) en un endroit donné.
  3. Plateforme marine (10) selon les revendications 1 ou 2, caractérisée en ce que les connexions d'articulation (27) sont des joints universels (62).
  4. Plateforme marine (10) selon les revendications 1 ou 2, caractérisée en ce que chacune des connexions (27) d'articulation inclut des parties d'engagement correspondantes concave (26) et convexe (25).
  5. Plateforme marine (10) selon la revendication 4, caractérisée en ce que le flotteur (13, 14, 15,16,) présente une partie d'articulation convexe (25) et la plateforme (10) présente une partie d'articulation concave (26).
  6. Plateforme marine (10) selon la revendication 4, caractérisée en ce que le flotteur (13, 14,15,16,) présente une partie d'articulation concave et la plateforme (10) présente une partie d'articulation convexe.
  7. Plateforme marine (10) selon l'une des revendications précédentes, caractérisée en ce qu'il est prévu au moins trois flotteurs (13, 14, 15,16) et au moins trois positions d'attachement.
  8. Plateforme marine (10) selon l'une des revendications précédentes, caractérisée en ce qu'il est prévu au moins quatre flotteurs (13, 14, 15,16) et au moins quatre positions d'attachement.
  9. Plateforme marine (10) selon l'une des revendications précédentes, caractérisée en ce que les flotteurs (13, 14, 15,16) supportent une plateforme (10) qui pèse entre 500 000 et 105 000 000 kg.
  10. Procédé d'installation d'une plateforme (10) de production ou de forage de puits de pétrole et de gaz dans un environnement marin profond off shore comprenant les étapes de :
    a) Placer une pluralité de flotteurs (13, 14, 15,16)
    b) Mettre en flottement dans l'environnement marin une plateforme (1) présentant des installations (53) de production ou de forage de puits de pétrole et de gaz, vers l'endroit des flotteurs (13, 14, 15,16), la plateforme (10) incluant une partie périphérique (19) qui inclut une pluralité de positions de connexion, une position de connexion pour chaque flotteur (13,14,15,16) ;
    c) Lester la plateforme (10) et les flotteurs (13, 14, 15,16) les uns par rapport aux autres jusqu'à ce que chaque flotteur (13,14,15,16) soit connecté avec la plateforme (10) et que sensiblemet tout le poids de la plateforme soit supporté par les flotteurs (13,14,15,16) ;
    caractérisé en ce que à chaque position de connexion une connexion d'articulation (27) est réalisée pour permettre le mouvement de chacun respectivement des flotteurs (13, 14, 15,16) par rapport à la plateforme (10) de façon que les forces axiales et tangentielles entre la plateforme (10) et chaque flotteur (13,14,15,16) soient transmises et tandis que le transfert de mouvement de pliage soit réduit ou minimisé ; et
    en ce que chacun des flotteurs (13, 14, 15,16) est sensiblement libre de se déplacer dans toutes directions par rapport à la plateforme (10), excepté les mouvements qui entraîneraient une séparation du flotteur (13, 14,15,16) de la plateforme (10).
  11. Procédé selon la revendication 10, caractérisé en ce qu'il comporte en outre l'étape de placer des amarres pour chaque flotteur (13, 14, 15,16) avec une ligne d'ancrage (32).
  12. Procédé selon l'une des revendications 10 ou 11, caractérisé en ce que chacune des connexions d'articulation inclut des parties d'engagement correspondantes, concave (26) et convexe (25).
  13. Procédé selon la revendication 12, caractérisé en ce que le flotteur (13,14,15,16) présente une partie d'articulation convexe (25) et la plateforme (10) présente une partie d'articulation (26) concave, et dans l'étape « c » la plateforme (10) et les flotteurs (13,14,15,16) sont lestés jusqu'à ce que les parties concaves (26) et convexes (25) s'engagent pour chaque flotteur (13,14,15,16) et la plateforme (10).
  14. Procédé selon la revendication 12, caractérisé en ce que le flotteur (13, 14, 15,16) présente une partie d'articulation (26) concave et la plateforme (10) présente une partie d'articulation convexe (25).
  15. Procédé selon l'une des revendication 10 à 14, caractérisé en ce que chaque flotteur (13, 14, 15,16) présente une hauteur et un diamètre, la hauteur étant supérieure au diamètre, et comporte en outre l'étape de mise en position de la plateforme (10) entre au moins deux flotteurs (13,14,15,16).
  16. Procédé selon l'une des revendication 10 à 15, caractérisé en ce qu'il est prévu au moins trois flotteurs (13, 14,15,16) et au moins trois positions d'attachement.
  17. Procédé selon l'une des revendication 10 à 15, caractérisé en ce qu'il est prévu au moins quatre flotteurs (13, 14,15,16).
  18. Procédé selon l'une des revendication 10 à 17, caractérisé en ce que la plateforme (10) comporte un pont attaché et en ce que les étapes « b » et « c » incluent la connexion de chaque flotteur (13,14,15,16) audit pont.
  19. Procédé selon la revendication 10, caractérisé en ce qu'elle comporte en outre les étapes de prévoir une bouée d'amarrage (156) unique et l'étape de transférer la plateforme (10) depuis les flotteurs (13,14,15,16) jusqu'à la bouée d'amarrage (156) unique.
EP01968663A 2000-10-20 2001-09-07 Plate-forme martime a bouees multiples articulees, dispositif et procede d'installation Expired - Lifetime EP1332260B1 (fr)

Applications Claiming Priority (7)

Application Number Priority Date Filing Date Title
US693470 1996-08-02
US09/693,470 US6425710B1 (en) 2000-06-21 2000-10-20 Articulated multiple buoy marine platform apparatus
US704998 2000-11-02
US09/704,998 US6435773B1 (en) 2000-06-21 2000-11-02 Articulated multiple buoy marine platform apparatus and method of installation
US09/727,343 US6435774B1 (en) 2000-06-21 2000-11-29 Articulated multiple buoy marine platform apparatus
US727343 2000-11-29
PCT/US2001/028098 WO2002035014A1 (fr) 2000-10-20 2001-09-07 Plate-forme martime a bouees multiples articulees, dispositif et procede d'installation

Publications (3)

Publication Number Publication Date
EP1332260A1 EP1332260A1 (fr) 2003-08-06
EP1332260A4 EP1332260A4 (fr) 2006-10-04
EP1332260B1 true EP1332260B1 (fr) 2011-02-23

Family

ID=27418579

Family Applications (1)

Application Number Title Priority Date Filing Date
EP01968663A Expired - Lifetime EP1332260B1 (fr) 2000-10-20 2001-09-07 Plate-forme martime a bouees multiples articulees, dispositif et procede d'installation

Country Status (7)

Country Link
EP (1) EP1332260B1 (fr)
AU (2) AU2001288897B2 (fr)
BR (1) BR0114997A (fr)
CA (1) CA2426308C (fr)
MX (1) MXPA03003496A (fr)
NO (1) NO334995B1 (fr)
WO (1) WO2002035014A1 (fr)

Families Citing this family (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6719495B2 (en) 2000-06-21 2004-04-13 Jon E. Khachaturian Articulated multiple buoy marine platform apparatus and method of installation
US6425710B1 (en) 2000-06-21 2002-07-30 Jon Khachaturian Articulated multiple buoy marine platform apparatus
NL1023320C2 (nl) * 2003-05-01 2004-11-02 Leenaars B V De uitvinding heeft betrekking op een methode voor fabricage, installatie en verwijderen van een offshore platform.
ES2572152B1 (es) * 2014-11-27 2017-03-17 Advance Intelligent Developments, S.L. Plataforma oceánica multimodular
NO342731B1 (no) * 2017-02-02 2018-08-06 Flexible Floating System As Rammestruktur for en flytende installasjon

Family Cites Families (24)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3736756A (en) * 1971-11-03 1973-06-05 Exxon Co Method and apparatus for assembling an offshore structure
FR2411956A1 (fr) * 1977-12-19 1979-07-13 Doris Dev Richesse Sous Marine Procede et dispositif pour l'exploitation de gisements subaquatiques
US4155670A (en) * 1978-03-29 1979-05-22 Chicago Bridge & Iron Company Ball and socket swivel with conduit therethrough and torque transfer capability
FR2496730A1 (fr) * 1980-12-23 1982-06-25 Bretagne Atel Chantiers Dispositif pour la mise en place d'une plate-forme marine sur sa structure support
DE3104570C2 (de) 1981-02-10 1986-02-06 M.A.N. Maschinenfabrik Augsburg-Nürnberg AG, 4200 Oberhausen Verankerung von im Meerwasser angeordneten Schwimmkörpern
US4714382A (en) * 1985-05-14 1987-12-22 Khachaturian Jon E Method and apparatus for the offshore installation of multi-ton prefabricated deck packages on partially submerged offshore jacket foundations
US4966495A (en) * 1988-07-19 1990-10-30 Goldman Jerome L Semisubmersible vessel with captured constant tension buoy
US4930924A (en) * 1989-02-03 1990-06-05 Dei Enterprises Low wear articulated buoy
US4913238A (en) * 1989-04-18 1990-04-03 Exxon Production Research Company Floating/tensioned production system with caisson
US4930938A (en) * 1989-06-02 1990-06-05 Exxon Production Research Company Offshore platform deck/jacket mating system and method
US5118221A (en) * 1991-03-28 1992-06-02 Copple Robert W Deep water platform with buoyant flexible piles
US5403124A (en) * 1993-07-26 1995-04-04 Mcdermott International, Inc. Semisubmersible vessel for transporting and installing heavy deck sections offshore using quick drop ballast system
US5799603A (en) * 1993-11-18 1998-09-01 Tellington; Wentworth J. Shock-absorbing system for floating platform
US5931602A (en) 1994-04-15 1999-08-03 Kvaerner Oil & Gas A.S Device for oil production at great depths at sea
US5542783A (en) * 1994-12-14 1996-08-06 Imodco, Inc. TLP and detachable derrick vessel
US5553977A (en) 1994-12-16 1996-09-10 Northrop Grumman Corporation Off-shore platform construction, and method for transferring loads
US6149350A (en) * 1995-03-15 2000-11-21 Khachaturian; Jon E. Method and apparatus for the offshore installation of multi-ton packages such as deck packages and jackets
US5706897A (en) 1995-11-29 1998-01-13 Deep Oil Technology, Incorporated Drilling, production, test, and oil storage caisson
US5722797A (en) 1996-02-21 1998-03-03 Deep Oil Technology, Inc. Floating caisson for offshore production and drilling
NL1004682C2 (nl) * 1996-12-03 1998-06-15 Allseas Group Sa Inrichting en werkwijze voor het lichten van een zeegaande constructie, bijvoorbeeld boorplatform.
US6027286A (en) 1997-06-19 2000-02-22 Imodco, Inc. Offshore spar production system and method for creating a controlled tilt of the caisson axis
US5846028A (en) * 1997-08-01 1998-12-08 Hydralift, Inc. Controlled pressure multi-cylinder riser tensioner and method
US6012873A (en) 1997-09-30 2000-01-11 Copple; Robert W. Buoyant leg platform with retractable gravity base and method of anchoring and relocating the same
US5924822A (en) 1997-10-15 1999-07-20 Deep Oil Technology, Incorporated Method for deck installation on an offshore substructure

Also Published As

Publication number Publication date
AU8889701A (en) 2002-05-06
BR0114997A (pt) 2004-02-17
NO334995B1 (no) 2014-08-18
NO20031783L (no) 2003-06-19
CA2426308A1 (fr) 2002-05-02
NO20031783D0 (no) 2003-04-22
AU2001288897B2 (en) 2006-11-16
EP1332260A4 (fr) 2006-10-04
MXPA03003496A (es) 2005-01-25
WO2002035014A1 (fr) 2002-05-02
EP1332260A1 (fr) 2003-08-06
CA2426308C (fr) 2011-08-09

Similar Documents

Publication Publication Date Title
US6435774B1 (en) Articulated multiple buoy marine platform apparatus
US9815531B2 (en) Articulated multiple buoy marine platform apparatus and method of installation
US6719495B2 (en) Articulated multiple buoy marine platform apparatus and method of installation
US6652192B1 (en) Heave suppressed offshore drilling and production platform and method of installation
CN103917439B (zh) 具有外置柱的离岸平台
US6523491B1 (en) Lift boat
MX2008010922A (es) Plataforma de patas de tension de columnas ataludadas.
US5762017A (en) Bearing, turning and locking system for use on a turret moored vessel
EP1332260B1 (fr) Plate-forme martime a bouees multiples articulees, dispositif et procede d'installation
AU2001288897A1 (en) Articulated multiple buoy marine platform apparatus and method of installing same
CA1284919C (fr) Ensemble a plate-forme flottante
US6648553B2 (en) Load transfer unit and method for removing off-shore platform from substructure
US20030072619A1 (en) Articulated multiple buoy marine platform apparatus and method of installation
EP1400442B1 (fr) Dispositif de mouillage
AU2006341561A1 (en) Floating production, storage and off-loading system with column buoy
NO337428B1 (no) Marin plattform
WO2004067375A1 (fr) Bateau equipe d'un systeme de levage
WO2011059918A1 (fr) Plateforme de type spar assistée par navire annexe

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: 20030519

AK Designated contracting states

Designated state(s): AT BE CH CY DE DK ES FI FR GB GR IE IT LI LU MC NL PT SE TR

AX Request for extension of the european patent

Extension state: AL LT LV MK RO SI

A4 Supplementary search report drawn up and despatched

Effective date: 20060901

17Q First examination report despatched

Effective date: 20081020

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 CH CY DE DK ES FI FR GB GR IE IT LI LU MC NL PT SE TR

REG Reference to a national code

Ref country code: GB

Ref legal event code: FG4D

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

REF Corresponds to:

Ref document number: 60144103

Country of ref document: DE

Date of ref document: 20110407

Kind code of ref document: P

REG Reference to a national code

Ref country code: DE

Ref legal event code: R096

Ref document number: 60144103

Country of ref document: DE

Effective date: 20110407

REG Reference to a national code

Ref country code: NL

Ref legal event code: T3

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: 20110524

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: 20110603

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: 20110223

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: 20110623

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: 20110223

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: 20110223

Ref country code: BE

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: 20110223

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: 20110223

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

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: 20110223

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: 20111124

REG Reference to a national code

Ref country code: DE

Ref legal event code: R097

Ref document number: 60144103

Country of ref document: DE

Effective date: 20111124

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: 20110930

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: 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: 20110223

REG Reference to a national code

Ref country code: IE

Ref legal event code: MM4A

REG Reference to a national code

Ref country code: DE

Ref legal event code: R119

Ref document number: 60144103

Country of ref document: DE

Effective date: 20120403

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: 20110907

Ref country code: LI

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

Effective date: 20110930

Ref country code: DE

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

Effective date: 20120403

Ref country code: CH

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

Effective date: 20110930

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: 20110907

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: 20110223

REG Reference to a national code

Ref country code: FR

Ref legal event code: PLFP

Year of fee payment: 16

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

Ref country code: NL

Payment date: 20160913

Year of fee payment: 16

Ref country code: GB

Payment date: 20160907

Year of fee payment: 16

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

Ref country code: FR

Payment date: 20160816

Year of fee payment: 16

REG Reference to a national code

Ref country code: GB

Ref legal event code: 732E

Free format text: REGISTERED BETWEEN 20180308 AND 20180314

REG Reference to a national code

Ref country code: FR

Ref legal event code: TP

Owner name: VERSABAR, INC., US

Effective date: 20180321

REG Reference to a national code

Ref country code: NL

Ref legal event code: MM

Effective date: 20171001

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

Effective date: 20170907

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: 20171001

REG Reference to a national code

Ref country code: FR

Ref legal event code: ST

Effective date: 20180531

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: 20170907

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

Ref country code: FR

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

Effective date: 20171002