[go: up one dir, main page]

WO2016083509A1 - Agencement d'amarrage de secours - Google Patents

Agencement d'amarrage de secours Download PDF

Info

Publication number
WO2016083509A1
WO2016083509A1 PCT/EP2015/077781 EP2015077781W WO2016083509A1 WO 2016083509 A1 WO2016083509 A1 WO 2016083509A1 EP 2015077781 W EP2015077781 W EP 2015077781W WO 2016083509 A1 WO2016083509 A1 WO 2016083509A1
Authority
WO
WIPO (PCT)
Prior art keywords
floating structure
positioning arrangement
mooring
accordance
auxiliary positioning
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Ceased
Application number
PCT/EP2015/077781
Other languages
English (en)
Inventor
Arne Smedal
Jan Vidar Aarsnes
Kåre SYVERTSEN
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.)
Cefront Technology AS
Original Assignee
Cefront Technology AS
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Cefront Technology AS filed Critical Cefront Technology AS
Priority to BR112017011149A priority Critical patent/BR112017011149A2/pt
Priority to EP15801156.9A priority patent/EP3224132B1/fr
Priority to CN201580064174.7A priority patent/CN107000817A/zh
Publication of WO2016083509A1 publication Critical patent/WO2016083509A1/fr
Anticipated expiration legal-status Critical
Ceased legal-status Critical Current

Links

Classifications

    • 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
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B63—SHIPS OR OTHER WATERBORNE VESSELS; RELATED EQUIPMENT
    • B63B—SHIPS OR OTHER WATERBORNE VESSELS; EQUIPMENT FOR SHIPPING 
    • B63B22/00—Buoys
    • B63B22/04—Fixations or other anchoring arrangements
    • 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
    • B63B21/16—Tying-up; Shifting, towing, or pushing equipment; Anchoring using winches
    • 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
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B63—SHIPS OR OTHER WATERBORNE VESSELS; RELATED EQUIPMENT
    • B63B—SHIPS OR OTHER WATERBORNE VESSELS; EQUIPMENT FOR SHIPPING 
    • B63B43/00—Improving safety of vessels, e.g. damage control, not otherwise provided for
    • B63B43/18—Improving safety of vessels, e.g. damage control, not otherwise provided for preventing collision or grounding; reducing collision damage
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B63—SHIPS OR OTHER WATERBORNE VESSELS; RELATED EQUIPMENT
    • B63H—MARINE PROPULSION OR STEERING
    • B63H25/00—Steering; Slowing-down otherwise than by use of propulsive elements; Dynamic anchoring, i.e. positioning vessels by means of main or auxiliary propulsive elements
    • B63H25/42—Steering or dynamic anchoring by propulsive elements; Steering or dynamic anchoring by propellers used therefor only; Steering or dynamic anchoring by rudders carrying propellers
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B63—SHIPS OR OTHER WATERBORNE VESSELS; RELATED EQUIPMENT
    • B63B—SHIPS OR OTHER WATERBORNE VESSELS; EQUIPMENT FOR SHIPPING 
    • B63B27/00—Arrangement of ship-based loading or unloading equipment for cargo or passengers
    • B63B27/14—Arrangement of ship-based loading or unloading equipment for cargo or passengers of ramps, gangways or outboard ladders ; Pilot lifts
    • B63B2027/141—Arrangement of ship-based loading or unloading equipment for cargo or passengers of ramps, gangways or outboard ladders ; Pilot lifts telescopically extendable
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B63—SHIPS OR OTHER WATERBORNE VESSELS; RELATED EQUIPMENT
    • B63B—SHIPS OR OTHER WATERBORNE VESSELS; EQUIPMENT FOR SHIPPING 
    • B63B27/00—Arrangement of ship-based loading or unloading equipment for cargo or passengers
    • B63B27/30—Arrangement of ship-based loading or unloading equipment for transfer at sea between ships or between ships and off-shore structures

Definitions

  • the present invention relates to a system for avoiding collision between a first floating structure and a second structure as defined in the preamble of claim 1 and an installation using the inventive system.
  • patent publication GB2096963 which describes a solution in which tension lines extend with a maximum length between a vessel and dedicated mooring lines of a platform.
  • patent publication US 5 ' 1 9 ' 891 discloses a solution which enables a pull of a supply boat away from a floating platform by use of a set of mooring lines. The main purpose for the latter is to enable position adjustments without the need for re-setting any anchors.
  • the invention concerns a system for avoiding collision between a first floating structure and a second structure.
  • the system comprises a main positioning arrangement suitable for maintaining the first floating structure at a predetermined distance (/ c ) from the second structure.
  • the system is further characterized in that it comprises a back-up system or safety system comprising an auxiliary positioning arrangement suitable for mooring the first floating structure to an underlying seabed by for example an anchor.
  • This auxiliary positioning arrangement comprises a tensioning means mountable on the first floating structure and is configured to establish, in case of malfunctioning of the main positioning arrangement, a resultant force (F res ) acting at least indirectly on the first floating structure, which force has a magnitude and direction that ensures maintenance of a minimum distance ilmin) between the first floating structure and the second structure.
  • said minimum distance ilmin) may range from near zero, that is near direct impact, and up to a distance considered sufficiently safe for the intended purpose, for example within a range from 10 meters to 100 meters such as 10 meters, 20 meters, 30 meters, 40 meters, 50 meters, 60 meters, 70 meters, 80 meters, 90 meters, 100 meters or any distance within these distances.
  • the first floating structure may be a floating accommodation unit (FAU) and the second structure may be a hydrocarbon producing facility such as a floating production, storage and offloading (FPSO) unit.
  • FAU floating accommodation unit
  • FPSO floating production, storage and offloading
  • auxiliary positioning arrangement is arranged on the first floating structure facing away from the second structure during use.
  • the system comprises a tensioning means connected to a first end of the auxiliary positioning arrangement.
  • Said tensioning means for example one more winches, are suitable for providing controllable tensioning along the auxiliary positioning arrangement.
  • said tensioning means is preferably configured to enable control of the minimum distance ilmin) by regulating the tensioning along the auxiliary positioning arrangement.
  • the auxiliary positioning arrangement further comprises one or more mooring lines such as a chain, a cable, a rope, a wire, etc, or any combinations thereof.
  • the mooring line(s) is/are connectable at a first end to the first floating structure and connected at a second end to a seabed anchoring means.
  • the largest horizontal component of the mooring line or mooring lines during use is directed away from the second structure.
  • mooring line(s) may also be configured non-parallel to a straight line drawn through both the first floating structure and the second structure.
  • the resultant horizontal force should, in this particular embodiment, have a net force along this straight line that faces away from the second structure.
  • the mooring line, or at least one of the mooring lines, is preferably oriented parallel or near parallel to said straight line.
  • the auxiliary positioning arrangement comprises two or more mooring lines, where each of the mooring lines have its largest component oriented parallel to the underlying seabed and directed away from the second structure during use.
  • the horizontal component of the two mooring lines defines in this embodiment a plane parallel to the underlying seabed which has a mutual angle of less than 120°, preferably less than 90°, even more preferably less than 45°, even more preferably less than 25°, for example parallel or close to parallel.
  • the auxiliary positioning arrangement comprises a first elongated part such as a wire connectable at one end to the first floating structure and a second elongated part such as a chain connected between a seabed anchoring means and the other end of the first elongated part, wherein the weight and/or the stiffness of the second elongated part is higher than the first elongated part.
  • the length of the second elongated part is preferably less than the length of the first elongated part, more preferably less than 30 % of the length of the first elongated part, even more preferably less than 20 %, for example about 10 %.
  • the main positioning arrangement comprises a dynamic positioning system, for example a combined positioning arrangement comprising both a dynamic positioning system and a mooring line system.
  • the invention also concerns an installation such as an installation suitable for hydrocarbon production.
  • the installation comprises a first floating structure, a second structure and a system in accordance with any one of the above mentioned features.
  • the installation further comprises a bridge or gangway interconnecting the first floating structure and the second structure, preferably a disconnectable telescopic gangway.
  • Fig. l a and lb is a top view sketch and a side view sketch, respectively, of an installation using a system in accordance with one embodiment of the invention
  • FIG. 2 shows a mooring line profile of a 2500 m long, 90 mm thick mooring wire extending from sea level to a water depth of 300 m when being exposed for a line tensioning of 4000 kN
  • Figure 3 shows graphs presenting the dynamic behaviour in surge at different initial tensioning levels of the first floating structure as function of time after a main positioning arrangement failure, the first floating structure being anchored at 100 m depth by two 1500 m long wires of thickness 90 mm
  • Figure 4 shows graphs presenting the dynamic behaviour in surge of the first floating structure as function of time after a main positioning arrangement failure, in which one surge offset is set up by anchoring the first floating structure being at 100 m depth by two 1500 m long wires of thickness 90 mm and the other surge offset is set up by a first floating structure being anchored at 100 m depth by two 800 m long chains of thickness 84 mm,
  • Figure 5 shows graphs presenting the dynamic behaviour in surge of the first floating structure as function of time after a main positioning arrangement failure, in which a first surge offset is set up by anchoring the first floating structure at 300 m depth by two 1200 m long wires of thickness 90 mm, a second surge offset is set up by anchoring the first floating structure at 300 m depth by two 2500 m long wires of thickness 90 mm, and with an initial tensioning identical to the first surge offset, and a third surge offset is set up by anchoring the first floating structure at 300 m depth by two 2500 m long chains of thickness 90 mm, and with an initial tensioning higher than the first and second surge offsets and
  • Figure 6 shows graphs presenting the dynamic behaviour in surge of the first floating structure as function of time after a main positioning arrangement failure, in which a first surge offset is set up by anchoring the first floating structure at 300 m depth by two 1200 m long wires of thickness 90 mm, a second surge offset is set up by anchoring the first floating structure at 300 m depth by two 2500 m long wires of thickness 90 mm, and with an initial tensioning higher than the first surge offset, and a third surge offset is set up by anchoring the first floating structure at 300 m depth by two mooring lines comprising a bottom chain of length 200 m and thickness 180 mm and a top wire of length 450 m and thickness 90 mm, and with an initial tensioning lower than the first and second surge offsets, Detailed description of the invention
  • an auxiliary or back-up mooring arrangement 3 is proposed.
  • the main purpose is to avoid contact between a first floating structure 2 and a second structure 1 in case of any type of failure in a main mooring arrangement 4 of the first floating structure 2, which main mooring arrangement 4 is configured for controlling the position of the first floating structure 2 relative to the second structure 1.
  • the main mooring arrangement 4 may be a Dynamic Position (DP) system comprising one or more thrusters 4 and/or an essentially symmetrically distributed set of mooring lines extending from the first floating structure 2 to an underlying seabed 5.
  • DP Dynamic Position
  • first floating structure 2 is an FAU (floating accommodation unit).
  • second structure 1 may be an FPSO (floating production, storage and offloading) unit, an FPU (floating production unit) or an FSO (floating, storage and offloading) unit.
  • FPSO floating production, storage and offloading
  • FPU floating production unit
  • FSO floating, storage and offloading
  • An FAU 2 is attached to an FPSO 1 via a telescopic bridge 6.
  • the term telescopic bridge will hereinafter signify a bridge which may expand or retract in length in the direction between the FAU 2 and the FPSO 1 relative to a mean length IQ.
  • the relative position of the FAU 2 and the FPSO 1 is controlled by a plurality of DP-thrusters 4 distributed on the hull of the FAU 2.
  • the FAU 2 is further connected a back-up mooring arrangement 3 comprising two almost parallel oriented mooring lines 3a,3b extending from one or more mooring winches 7 positioned on the FAU 2 to an underlying seabed 5.
  • This or these winches 7 are in the embodiment situated at the side of the FAU 2 facing away from the bridge connected FPSO 1 and enables control of the pre-tensioning of each mooring line 3a,3b. Based on the above mentioned installation two different cases of a DP / thruster failure are assumed most critical:
  • DP drift-over scenario At a given time the DP system 4 give full thrust towards the FPSO 1 i.e. in the bridge direction. This extreme case will be analyzed below.
  • ⁇ Blackout scenario At a given time a complete loss of thrust occur.
  • the back-up mooring arrangement 3 shall keep the FAU 2 safely away from the FPSO 2 at zero control forces of the FAU 2 and perhaps highly unfavourable weather conditions.
  • lc represent the minimum clearance between the FAU 2 and FPSO 1 when the telescopic bridge 6 in its mean position and IM represents the distance from the FAU 2 to an anchor 8.
  • the mooring line(s) comprise(s) a wire based line.
  • a fully wire based line of length l wire 1500 m may be used.
  • the length l wire may be 2500 m.
  • At least one purpose for selecting the length of the mooring lines 3 a, 3b may be to reduce vertical forces at the anchor 8 well below the mooring line's 3a, 3b maximum allowed tension, for example half of the minimum breaking load (MBL) .
  • MBL minimum breaking load
  • Shorter line length may be used.
  • Anchors may, as an example, be of type drag embedment, high holding capacity anchors.
  • the mooring line profile (water depth as function of the horizontal distance from the FAU 2) for a mooring line system 3 with two mooring lines 3a,b, a maximum water depth of 300 m, a mean wire diameter of 90 mm and a pre-tension of 4000 kN is shown in figure 2.
  • the pre-tension of 4000 kN is a typical peak tension that may be experienced by the mooring line system shortly after a DP drift-over.
  • the mooring line(s) comprise(s) a chain based line.
  • the mooring line(s) comprise(s) a chain based line and wire based line, where the former is attached to its anchor 8.
  • the length of the chain should preferably be considerably shorter than the length of the wire.
  • the mooring line(s) 3a,b may comprise an anchor attached chain of grade R2 having a mean diameter of 180 mm and a length of 200 m and a wire attached between the chain and the FAU 2 having a diameter of 90 mm and a length of 450 m (outside fairlead 9).
  • a FPSO 1 a FAU 2
  • a telescopic bridge 6 interconnecting the FPSO 1 and the FAU 2
  • two mooring lines 3, 3 a, 3b connected between the FAU 2 and an underlying seabed 5 anchored to a properly dimensioned anchor 8 on the side of the FAU 2 facing away from the FPSO 1.
  • Due to the telescopic configuration of the bridge 6 the relative distance between the FAU 2 and the FPSO 1 may vary around a mean position FAU mean. This variation will hereinafter be referred to as a horizontal FAU offset or an FAU offset.
  • an FAU offset in the direction towards the FPSO 1 will be referred to as an FAU surge offset.
  • the DP system 4 is assumed to comprise four times 4.4 MB azimuth thrusters 4 providing a maximum open water thrust of approximately 810 kN each, giving a total of 3240 kN. Taking into account the thruster-hull interaction the total available thrust is considered to be around 3000 kN. Furthermore, the model used for the simulation of the dynamic offset of the FAU 2 as a function of time after the DP drift- over scenario is:
  • x is the horizontal acceleration of the FAU 2
  • x is the displacement of the FAU 2
  • A is a surge added mass
  • F D is the damping force
  • F T is the horizontal component of the mooring line tension
  • F DP is the total force from the thrusters 4.
  • the thrust will give a damping contribution due to the velocity dependency of the thrust assumed (based on the thrust curve of the above mentioned 4.4 MW thrusters) to be
  • a wire based mooring system 3 is assumed comprising two 1500 m mooring lines 3a,b having a mean wire diameter of 90 mm anchored at a water depth of 100 m and exposed to pre-tensioning levels during normal operation of 75 kN and 135 kN, corresponding to horizontal tensions of 40 kN and 100 kN, respectively. Any contributions from waves are ignored.
  • the results are shown in figure 3 presenting the FAU surge offset (displacement of the FAU towards the FPSO 1) as function of time after DP failure. Stippled line shows the FAU surge offset with low pre-tensioning and full line shows the FAU surge offset with high pre-tensioning. A significant dynamic overshoot is seen for the FAU offset towards the FPSO (FAU surge offset).
  • the maximum offset towards the FPSO is seen to be approximately 42 m after about 75 second after failure.
  • the maximum offset is reduced to approx. 30 m.
  • a further reduction in maximum offset may be obtained by further increasing the pretension by controlling the mooring winch(es) 7.
  • the maximum line tension during the dynamic overshoot was found to be 3750 kN and 3450 kN for the lowest and highest pretension level, respectively.
  • the FAU surge offset of the wire-based system for pre-tensioning of 135 kN (100 kN in horizontal direction) is added for comparison (full line). Note that the pre-tensioning level for the chain-based system (325 kN) is considerably higher than for the above wire-based system (135 kN) due to the much higher weight of the chain. The maximum FAU surge offset is seen to be almost identical for the two mooring systems.
  • Wire based mooring system - water depth d 300 m
  • a wire based mooring system 3 is assumed comprising two 2500 m mooring lines 3 a, 3b having a mean wire diameter of 90 mm anchored at a water depth of 100 m and exposed to pre-tensioning levels during normal operation with horizontal components corresponding to 290 kN and 400 kN. Any contributions from waves are ignored.
  • the results are shown in figure 5 presenting the FAU surge offset (displacement of the FAU towards the FPSO 1) as function of time after DP failure. Stipled line shows the FAU surge offset with low pre-tensioning and full line shows the FAU surge offset with high pre-tensioning.
  • FIG. 5 also shows the FAU surge offset using a wire bares mooring system 3 of 1200 m mooring lines 3a,b (dash-dot line).
  • a maximum FAU surge offset of about 54 m and about 43 m for a pre -tensioning level along the horizontal direction of 290 kN and 400 kN, respectively.
  • a pre-tensioning level of 400 kN is considered favorable.
  • a further reduction in maximum FAU offset requires a further increase in pretension.
  • a FAU surge offset above 40 m is considered undesirable due to limitation in length of existing bride designs.
  • the maximum FAU surge offset was found to be around 42 m, that is significantly lower than for the mooring system with 2500 m length wire at identical pre-tensioning level (290 kN). However, in this case the maximum tension peak is significantly higher, almost 4500 kN. With a horizontal component of the pretension of 290 kN and 400 kN, the required thrust to compensate for the pretension will be 580 kN and 800 kN, respectively. A reduction of the mean diameter of the wire from 90 mm to 70 mm did not change the maximum FAU surge offset significantly.
  • Hs is the significant wave height
  • Tp is the peak period of the wave spectrum
  • Uw is the mean wind velocity for a period of one hour
  • Uc is the surface current velocity
  • a wire based mooring system 3 is assumed comprising two 1500 m mooring lines 3a,b having a mean wire diameter of 90 mm anchored at a water depth of 100 m and exposed to pre-tensioning levels during normal operation of 135 kN, corresponding to horizontal tensions of 100 kN.
  • a back-up mooring system comprising two mooring lines, each having top wire of length 450 m (outside fairlead) and a mean diameter of 90 mm and a bottom chain of length 200 m and a mean diameter of 180 mm.
  • the horizontal component of the pre-tensioning level is 125 kN.

Landscapes

  • Chemical & Material Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Combustion & Propulsion (AREA)
  • Mechanical Engineering (AREA)
  • Ocean & Marine Engineering (AREA)
  • Public Health (AREA)
  • Health & Medical Sciences (AREA)
  • Laying Of Electric Cables Or Lines Outside (AREA)
  • Position Fixing By Use Of Radio Waves (AREA)
  • Foundations (AREA)
  • Other Liquid Machine Or Engine Such As Wave Power Use (AREA)
  • Investigation Of Foundation Soil And Reinforcement Of Foundation Soil By Compacting Or Drainage (AREA)
  • Control And Other Processes For Unpacking Of Materials (AREA)
  • Ultra Sonic Daignosis Equipment (AREA)

Abstract

Cette invention concerne un système d'amarrage d'une première structure flottante (2) à une seconde structure (1), par exemple une unité flottante de maintenance à une unité flottante de production, de stockage et d'expédition (FPSE). Ledit système comprend un agencement de positionnement principal (4) conçu pour maintenir la première structure flottante (2) à une distance prédéfinie (lc) de la seconde structure (1). Ledit système comprend en outre un agencement de positionnement auxiliaire (3, 3a, 3b) ou un système de secours pour l'amarrage de la première structure flottante (2) à un fond marin sous-jacent, par exemple, par une ancre. Ledit agencement de positionnement auxiliaire est conçu pour établir, en cas de dysfonctionnement de l'agencement de positionnement principal, une force résultante (Fres) agissant sur la première structure flottante (2), laquelle force présente une amplitude et une direction assurant le maintien d'une distance minimale (lmin) entre la première structure flottante (2) et la seconde structure (1). La force résultante est la force totale agissant sur la première structure flottante et implique, par exemple, une masse ajoutée de tangage, une force d'amortissement, une composante de force horizontale à partir de l'agencement de positionnement auxiliaire et une force totale à partir de l'agencement de positionnement principal.
PCT/EP2015/077781 2014-11-28 2015-11-26 Agencement d'amarrage de secours Ceased WO2016083509A1 (fr)

Priority Applications (3)

Application Number Priority Date Filing Date Title
BR112017011149A BR112017011149A2 (pt) 2014-11-28 2015-11-26 disposição de apoio de ancoragem
EP15801156.9A EP3224132B1 (fr) 2014-11-28 2015-11-26 Agencement d'amarrage de secours
CN201580064174.7A CN107000817A (zh) 2014-11-28 2015-11-26 支撑系泊设备

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
NO20141434 2014-11-28
NO20141434A NO338076B1 (no) 2014-11-28 2014-11-28 Back-up fortøyningsarrangement

Publications (1)

Publication Number Publication Date
WO2016083509A1 true WO2016083509A1 (fr) 2016-06-02

Family

ID=54705178

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/EP2015/077781 Ceased WO2016083509A1 (fr) 2014-11-28 2015-11-26 Agencement d'amarrage de secours

Country Status (5)

Country Link
EP (1) EP3224132B1 (fr)
CN (1) CN107000817A (fr)
BR (1) BR112017011149A2 (fr)
NO (1) NO338076B1 (fr)
WO (1) WO2016083509A1 (fr)

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2021242112A1 (fr) 2020-05-29 2021-12-02 Apl Norway As Système pour éviter l'endommagement de câbles d'alimentation vers et depuis et à l'intérieur d'un parc éolien en mer flottant
NO20230444A1 (en) * 2023-04-24 2024-10-25 Grant Prideco Inc Parallel mooring lines to same anchor

Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2919671A (en) * 1957-08-07 1960-01-05 Jersey Prod Res Co Mooring arrangement
US5390618A (en) * 1993-05-17 1995-02-21 Reading & Bates Development Co. Offshore mooring system
WO2009043383A1 (fr) * 2007-10-04 2009-04-09 Exmar N.V. Système flottant et son procédé de fonctionnement
WO2014032101A1 (fr) * 2012-09-03 2014-03-06 Seacaptaur Ip Litd Navire
WO2014073973A1 (fr) * 2012-11-07 2014-05-15 Sevan Marine Asa Dispositif et procédé pour interconnecter un navire-citerne et un terminal flottant

Family Cites Families (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
NO832362L (no) * 1982-07-14 1984-01-09 Conoco Inc Oppdrifts-fortoeyningskonstruksjon.
US5439324A (en) * 1993-03-01 1995-08-08 Shell Oil Company Bumper docking between offshore drilling vessels and compliant platforms
GB0321768D0 (en) * 2003-09-17 2003-10-15 Ocean Power Delivery Ltd Mooring system
NL2008207C2 (en) * 2012-01-31 2013-08-01 Sea Maester B V A method of providing access between a floating vessel and a marine structure.

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2919671A (en) * 1957-08-07 1960-01-05 Jersey Prod Res Co Mooring arrangement
US5390618A (en) * 1993-05-17 1995-02-21 Reading & Bates Development Co. Offshore mooring system
WO2009043383A1 (fr) * 2007-10-04 2009-04-09 Exmar N.V. Système flottant et son procédé de fonctionnement
WO2014032101A1 (fr) * 2012-09-03 2014-03-06 Seacaptaur Ip Litd Navire
WO2014073973A1 (fr) * 2012-11-07 2014-05-15 Sevan Marine Asa Dispositif et procédé pour interconnecter un navire-citerne et un terminal flottant

Cited By (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2021242112A1 (fr) 2020-05-29 2021-12-02 Apl Norway As Système pour éviter l'endommagement de câbles d'alimentation vers et depuis et à l'intérieur d'un parc éolien en mer flottant
US12428112B2 (en) 2020-05-29 2025-09-30 Apl Norway As System for avoiding damage to power cables to and from and within a floating offshore wind power plant
NO20230444A1 (en) * 2023-04-24 2024-10-25 Grant Prideco Inc Parallel mooring lines to same anchor

Also Published As

Publication number Publication date
EP3224132B1 (fr) 2018-09-05
EP3224132A1 (fr) 2017-10-04
BR112017011149A2 (pt) 2017-12-26
CN107000817A (zh) 2017-08-01
NO20141434A1 (no) 2016-05-30
NO338076B1 (no) 2016-07-25

Similar Documents

Publication Publication Date Title
Hsu et al. Extreme mooring tensions due to snap loads on a floating offshore wind turbine system
Yuan et al. Numerical study on a hybrid mooring system with clump weights and buoys
US4793738A (en) Single leg tension leg platform
US5054415A (en) Mooring/support system for marine structures
US20140338581A1 (en) Load Compensating Mooring Hooks
US10507894B2 (en) Self-restoring motion compensating mooring system
KR20150021305A (ko) 슬라이딩 타입 부유식 발전 플랜트 계류 장치
WO2006058400A1 (fr) Systeme de positionnement hybride pour structure flottante
WO2005007978A1 (fr) Plate-forme de production semi-submersible possedant un systeme d'ancrage lateral et procedes servant a l'utiliser et a la monter
EP3224132B1 (fr) Agencement d'amarrage de secours
US8973514B2 (en) Floating support
US20100028086A1 (en) Guide arrangement
CN103241348A (zh) 一种浮式平台减摇装置
Nguyen et al. Control of marine riser end angles by position mooring
JPH08276891A (ja) 緊張係留とバラスト制御を併用した浮体装置
US20020162495A1 (en) Method for tendering
Duquesnay et al. Docking and undocking considerations for floatover analyses and operations
Kery Dynamic modeling of ship-to-ship and ship-to-pier mooring performance
Sablok et al. Development of Harsh Environment Field With Ice Loadings Using Concrete Spar: Variability of Options
KR101707412B1 (ko) 해저 브리지 시스템
US20070264086A1 (en) Tendon for tension leg platform
Souza Pinheiro da Silva et al. Survivability Analysis of a MODU Platform With Fibre Ropes and Automatic Thruster-Assisted Mooring: Intact and Damaged Conditions
US10421523B2 (en) Spread moored buoy and floating production system
JPH0234498A (ja) 浮遊式海洋構造物の多点係留方式
Aderouane Design of Stationkeeping Systems

Legal Events

Date Code Title Description
121 Ep: the epo has been informed by wipo that ep was designated in this application

Ref document number: 15801156

Country of ref document: EP

Kind code of ref document: A1

DPE1 Request for preliminary examination filed after expiration of 19th month from priority date (pct application filed from 20040101)
NENP Non-entry into the national phase

Ref country code: DE

REG Reference to national code

Ref country code: BR

Ref legal event code: B01A

Ref document number: 112017011149

Country of ref document: BR

REEP Request for entry into the european phase

Ref document number: 2015801156

Country of ref document: EP

ENP Entry into the national phase

Ref document number: 112017011149

Country of ref document: BR

Kind code of ref document: A2

Effective date: 20170526