EP2643629A2 - Facilities for offshore liquefied natural gas floating storage with jetty regasification unit - Google Patents

Facilities for offshore liquefied natural gas floating storage with jetty regasification unit

Info

Publication number
EP2643629A2
EP2643629A2 EP11852293.7A EP11852293A EP2643629A2 EP 2643629 A2 EP2643629 A2 EP 2643629A2 EP 11852293 A EP11852293 A EP 11852293A EP 2643629 A2 EP2643629 A2 EP 2643629A2
Authority
EP
European Patent Office
Prior art keywords
unit
lng
jetty
regasification
facilities
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
Application number
EP11852293.7A
Other languages
German (de)
French (fr)
Other versions
EP2643629B1 (en
EP2643629A4 (en
Inventor
Ki Ho Moon
Kwang Ho Wi
Jae Young Ahn
Ho Joon Shin
Jae In Lee
In Soo Kim
Young Jae Yoo
Hyuk Jin Kwon
Doo Hyeong Lee
Chang Soo Kim
Sung Uk Lee
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.)
Samsung C&T Corp
Original Assignee
Samsung C&T Corp
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 Samsung C&T Corp filed Critical Samsung C&T Corp
Priority to PL11852293T priority Critical patent/PL2643629T3/en
Publication of EP2643629A2 publication Critical patent/EP2643629A2/en
Publication of EP2643629A4 publication Critical patent/EP2643629A4/en
Application granted granted Critical
Publication of EP2643629B1 publication Critical patent/EP2643629B1/en
Active legal-status Critical Current
Anticipated expiration legal-status Critical

Links

Classifications

    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C5/00—Methods or apparatus for filling containers with liquefied, solidified, or compressed gases under pressures
    • F17C5/06—Methods or apparatus for filling containers with liquefied, solidified, or compressed gases under pressures for filling with compressed gases
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C9/00—Methods or apparatus for discharging liquefied or solidified gases from vessels not under pressure
    • F17C9/02—Methods or apparatus for discharging liquefied or solidified gases from vessels not under pressure with change of state, e.g. vaporisation
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2221/00—Handled fluid, in particular type of fluid
    • F17C2221/03—Mixtures
    • F17C2221/032—Hydrocarbons
    • F17C2221/033—Methane, e.g. natural gas, CNG, LNG, GNL, GNC, PLNG
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2223/00—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel
    • F17C2223/01—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel characterised by the phase
    • F17C2223/0146—Two-phase
    • F17C2223/0153—Liquefied gas, e.g. LPG, GPL
    • F17C2223/0161—Liquefied gas, e.g. LPG, GPL cryogenic, e.g. LNG, GNL, PLNG
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2223/00—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel
    • F17C2223/03—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel characterised by the pressure level
    • F17C2223/033—Small pressure, e.g. for liquefied gas
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2225/00—Handled fluid after transfer, i.e. state of fluid after transfer from the vessel
    • F17C2225/01—Handled fluid after transfer, i.e. state of fluid after transfer from the vessel characterised by the phase
    • F17C2225/0107—Single phase
    • F17C2225/0123—Single phase gaseous, e.g. CNG, GNC
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2225/00—Handled fluid after transfer, i.e. state of fluid after transfer from the vessel
    • F17C2225/03—Handled fluid after transfer, i.e. state of fluid after transfer from the vessel characterised by the pressure level
    • F17C2225/035—High pressure, i.e. between 10 and 80 bars
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2227/00—Transfer of fluids, i.e. method or means for transferring the fluid; Heat exchange with the fluid
    • F17C2227/03—Heat exchange with the fluid
    • F17C2227/0302—Heat exchange with the fluid by heating
    • F17C2227/0309—Heat exchange with the fluid by heating using another fluid
    • F17C2227/0316—Water heating
    • F17C2227/0318—Water heating using seawater
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2227/00—Transfer of fluids, i.e. method or means for transferring the fluid; Heat exchange with the fluid
    • F17C2227/03—Heat exchange with the fluid
    • F17C2227/0367—Localisation of heat exchange
    • F17C2227/0388—Localisation of heat exchange separate
    • F17C2227/0393—Localisation of heat exchange separate using a vaporiser
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2265/00—Effects achieved by gas storage or gas handling
    • F17C2265/05—Regasification
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2270/00—Applications
    • F17C2270/01—Applications for fluid transport or storage
    • F17C2270/0102—Applications for fluid transport or storage on or in the water
    • F17C2270/0118—Offshore
    • F17C2270/0121—Platforms
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2270/00—Applications
    • F17C2270/01—Applications for fluid transport or storage
    • F17C2270/0102—Applications for fluid transport or storage on or in the water
    • F17C2270/0118—Offshore
    • F17C2270/0123—Terminals

Definitions

  • the present invention relates to facilities for offshore liquefied natural gas (LNG) floating storage with jetty regasification unit, and more particularly, to offshore facilities that have floating storage and regasification unit installed on jetty unit.
  • LNG offshore liquefied natural gas
  • this concept have been found to reduce installation, operating costs and construction time, and moreover increases stability of regasification performance of LNG.
  • the regasification facilities are used for regasification of LNG, i.e., to turn LNG back into natural gas.
  • LNG storage and regasification units are installed onshore
  • offshore facilities include a floating LNG storage unit, usually an LNG carrier or a gravity based structure (GBS), and a regasification unit installed on the floating structure, a shuttle regasification vessel (SRV) or a LNG regasification vessel (RV).
  • GGS gravity based structure
  • SRV shuttle regasification vessel
  • RV LNG regasification vessel
  • the SRV or the LNG RV is special purposed vessels that can navigate with regasification facilities.
  • the procedure starts by loading LNG from where it is produced and transports to an unloading location where then it is moored by submerged turret loading (STL) in offshore.
  • STL submerged turret loading
  • FSRU or SRV is moored to a jetty structure to withstand offshore weather and conditions.
  • LNG is supplied to FSRU from LNC carrier (LNGC) through a loading arm installed on a jetty where both FSRU and LNGC are moored side by side.
  • LNC carrier LNC carrier
  • high pressured natural gas (usually between 40 and 90 atm) is supplied to onshore through high pressure gas arm.
  • the loading arm and the high pressure gas arm have a large number of components which can absorb impact from the motions.
  • the present invention facilities for offshore LNG floating storage with jetty regasification unit, is designed for reduction of a construction time and cost, and enhances the stability for operation when compared to a newly constructed or converted FSRU and LNG RV.
  • a facilities for offshore liquefied natural gas (LNG) floating storage with jetty regasification unit comprising: a jetty unit of a steel structure or an iron concrete structure installed in offshore; a storage unit moored at the jetty unit providing a space for storing LNG; a regasification unit as a module which regasifies the LNG supplied from the storage unit, installed on a top portion of the jetty unit and is separable from the jetty unit; a utility unit comprising a power source and a sea water pump to supply power and sea water to the regasification unit; and a piping unit comprising unloading pipe for connecting the regasification unit and the storage unit and supplying pipe for carrying natural gas gasified by the regasification unit.
  • LNG offshore liquefied natural gas
  • the utility unit may be implemented as a module to be separable from the jetty unit.
  • the regasification unit may be used an open rack vaporizer (ORV) using sea water for heat exchanger.
  • ORV open rack vaporizer
  • the sea water pump of the utility unit and a ballast water pump disposed in the storage unit may be simultaneously used to supply sea water to the regasification unit.
  • a power facility, a steam generator, and a ballast water pump disposed in the storage unit may be used to supply power, steam, and sea water, respectively, which are necessary for the regasification unit.
  • the storage unit may be fixed to the jetty unit, loads LNG from a movable LNG carrier or a floating storage unit (FSU), and carries the LNG to the regasification unit.
  • FSU floating storage unit
  • the storage unit may be separable from the jetty unit and movable to load LNG.
  • the storage unit may be the LNG carrier or an FSU.
  • the present invention of offshore LNG floating storage with jetty regasification unit can provide a solution that can dramatically reduce the possibilities of high pressured natural gas leak into the atmosphere when compared to regasification on a floating structure.
  • FIG. 1 is a schematic diagram of a liquefied natural gas (LNG) regasification unit according to an embodiment of the present invention.
  • LNG liquefied natural gas
  • FIG. 1 is a schematic diagram of a liquefied natural gas (LNG) regasification unit according to an embodiment of the present invention.
  • LNG liquefied natural gas
  • the LNG regasification unit is used to regasify LNG in offshore and supply the regasified LNG, to gas users onshore.
  • this invention includes the jetty unit 10, a storage unit 20, a regasification unit 30, a piping unit 40, and a utility unit 50.
  • the jetty unit 10 is a fixed structure installed in sea bed with its legs, made of steel or iron concrete.
  • the term ‘jetty’ has various meanings, for example, a structure like a breakwater which distinguishes an inland and the sea, or a facility which is for anchoring vessels.
  • a site with certain depth of water, higher than a predetermined depth is required.
  • the jetty can be used for berthing in the way of stretching steeled structure from onshore to offshore or constructing a container terminal after dredging.
  • the jetty unit 10 is a semi-permanent structure that is installed to maintain a constant altitude above the sea level to withstand the changes of the wave by tidal current.
  • the shape of jetty unit 10 is not limited, it can be changed according to the locations and conditions thereof as long as the storage unit 20 can be anchored at.
  • a structure for anchoring the storage unit 20, such as a mooring dolphin or a fender, may be installed around the jetty unit 10, and is not shown in FIG. 1 for illustrative convenience (all the constituents are quite simply illustrated in FIG. 1).
  • the storage unit 20 provides a space for storing LNG once moored at the jetty unit 10.
  • the storage unit 20 can be converted from a second-handed LNG carrier or an existing LNG floating storage unit (FSU). Meanwhile, the storage unit 20 may be fixedly moored at the jetty unit 10 and separated from the jetty unit 10 on occasional demands.
  • Conventional operation involves supplying the LNG to the regasification unit 30 after receiving LNG from another LNG carrier.
  • the storage unit 20 may move to a location where LNG is produced or another FSU by itself, then receives LNG therefrom and supply the LNG to the regasification unit 30 again after being moored at the jetty unit 10.
  • another LNG carrier may supply LNG to the regasification unit 30, at the opposite side of the jetty unit 10.
  • Fixed or movable type of the storage unit 20 is determined according to circumstances or economical efficiency. For example, when a converted LNG carrier is used for the storage unit 20, storage type can be decided depending on the situation, as its mobility is already obtained.
  • the conversion process may require the vessel to operation both LNG loading pipe 21 and LNG unloading pipe 42 simultaneously, as general LNG carrier is designed not to proceed loading and unloading at the same time. Furthermore, if the storage unit 20 is expected to move, an appropriate facility for separating the unloading pipe 42 from the storage unit 20 is required as well.
  • the storage unit 20 includes a utility facility 22, such as a power facility, a steam generator, a ballast water pump P2, etc. which general LNG carriers and FSU are already equipped, thus no additional facility is needed when the second-handed LNG carrier or the FSU is converted.
  • a utility facility 22 such as a power facility, a steam generator, a ballast water pump P2, etc. which general LNG carriers and FSU are already equipped, thus no additional facility is needed when the second-handed LNG carrier or the FSU is converted.
  • the regasification unit 30 is a module for regasifying LNG which is supplied from the storage unit 20.
  • the regasification unit 30 is also separable from the jetty unit 10. Installment of the regasification unit 30 on the jetty unit 10, which is fixed on the sea bed, allows LNG to be regasified in offshore without the problems which commonly occurs in operation of conventional FSRU of LNG RV, a danger of leakage of natural gas due to an automatic piping separation in the operation or abrupt disconnection of a high pressure gas arm on the jetty unit 10 under the various offshore conditions. Since regasification work is performed on the hull 11 of the jetty unit 10, LNG can be transferred through the pipe between the storage unit 20 and the regasification unit 30. The stability of the hull 11 allows more safe transfer of LNG, regardless of the storage unit 20 movement due to the waves and tidal current.
  • a heat exchanger of the regasification unit 30 in the present invention is an open rack vaporizer (ORV) that utilizes sea water as a heat source. By contacting the heat exchanger, sea water absorbs the heat and vaporizes LNG into gas. ORV is strongly recommended due to its low investment and operating cost. However, if sea water is not uniformly coated on the vaporizer, the heat exchanger freezes and deteriorates its structure. That is why the ORV cannot be installed on FSRU of LNG RV. For the present invention, fixed structure of the jetty unit 10 guarantees safe operation of the ORV, which is a relatively inexpensive heat exchange system.
  • a sea water pump P1 in the utility unit 50 and the ballast water pump P2 of the utility facility 22 in the storage unit 20 are used to supply sea water to the ORV.
  • the sea water pump P1 and the ballast water pump P2 are designed to operate simultaneous as depicted in FIG1, it is not necessary to use both of them.
  • the sea water pump P1 acts as a main pump and the ballast water pump P2 as an auxiliary pump. Or, only the sea water pump P1 may be operated if the storage unit 20 is disconnected. How to supply the sea water to the ORV are subject to circumstances.
  • the piping unit 40 connecting the regasification unit 30 and the storage unit 20, includes unloading pipe 41 for supplying LNG from the storage unit 20 to the regasification unit 30 and supply pipe 42 for supplying gasified LNG from the regasification unit 30 to the end users in onshore. If required part of the piping unit 40 may be installed below a sea level.
  • the utility unit 50 (module) includes a power source, the sea water pump P1, and the steam generator for supplying power, sea water, and steam, respectively, to the regasification unit 30. Similar with the regasification unit 30, it is installed on the jetty unit 10, but also separable.
  • the utility unit 50 and the regasification unit 30 are connected by a power cable 51, sea water pipe 52, and steam pipe 53. They are respectively connected to the utility facilities in the storage unit 20 to be used simultaneously or complementarily in the present invention. Unlike shown in FIG.1, only the utility unit 50 may operate independently.
  • the piping unit 40, the power cable 51, the sea water pipe 52, and the steam pipe 53 are quite simply illustrated in FIG.1 for illustrative convenience, but the actual design is considerably complicated. Nevertheless, for the purpose of illustration, such simple diagram will be understood by those who have knowledge of this technology.
  • LNG stored in the storage unit 20 is supplied to the regasification unit 30 through the unloading pipe 41. Once regasified through the unit 30, regasified LNG is carried to the end users’ pipe line onshore through the supplying pipe 42.
  • the storage unit 20 can be fixed to the jetty unit 10 to load LNG from an LNG carrier (supplied through the loading pipe 21) or can be moved by itself to receive LNG from a neighboring FSU or a location where LNG is produced. If the storage unit 20 moves to different site, designated replacement should substitute for the previous storage unit 20, in order to supply LNG continuously.

Landscapes

  • Engineering & Computer Science (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Filling Or Discharging Of Gas Storage Vessels (AREA)

Abstract

Facilities for offshore liquefied natural gas (LNG) floating storage with jetty regasification unit, the facilities including: a jetty unit of a steel structure or an iron concrete structure installed in offshore; a storage unit moored at the jetty unit providing a space for storing LNG; a regasification unit as a module which regasifies the LNG supplied from the storage unit, installed on a top portion of the jetty unit and is separable from the jetty unit; a utility unit comprising a power source and a sea water pump to supply power and sea water to the regasification unit; and a piping unit comprising unloading pipe for connecting the regasification unit and the storage unit and supplying pipe for carrying natural gas gasified by the regasification unit.

Description

    FACILITIES FOR OFFSHORE LIQUEFIED NATURAL GAS FLOATING STORAGE WITH JETTY REGASIFICATION UNIT
  • The present invention relates to facilities for offshore liquefied natural gas (LNG) floating storage with jetty regasification unit, and more particularly, to offshore facilities that have floating storage and regasification unit installed on jetty unit. Compared to conventional regasification facility which is installed on LNG carriers or onshore LNG terminal, this concept have been found to reduce installation, operating costs and construction time, and moreover increases stability of regasification performance of LNG.
    •
  • The regasification facilities are used for regasification of LNG, i.e., to turn LNG back into natural gas. There facilities can be identified into two different types, onshore and offshore. In onshore facilities, LNG storage and regasification units are installed onshore, whereas offshore facilities include a floating LNG storage unit, usually an LNG carrier or a gravity based structure (GBS), and a regasification unit installed on the floating structure, a shuttle regasification vessel (SRV) or a LNG regasification vessel (RV).
  • The SRV or the LNG RV is special purposed vessels that can navigate with regasification facilities. The procedure starts by loading LNG from where it is produced and transports to an unloading location where then it is moored by submerged turret loading (STL) in offshore. These vessels have been widely used in the US, etc. for supplying natural gas and have been constructed by several Korean shipbuilding companies.
  • In light of growing of LNG demand, many attempts have been considered to construct new FSRU, but only several second-handed LNG carriers had been converted to FRSU due to economical reason and time constrains to deliver in Latin America and Asia, etc.
  • Construction of onshore facilities, however, faces more severe constrains. A large site has to be secured near facilities where LNG carriers are moored, and large scale construction incurs high cost, complex civil appeals of neighboring residents, and immobility of the facility once the construction is over. Thus, in many cases, offshore facilities are considered as a better solution for the fast tract of supplying natural gas.
  • Nevertheless, when newbuilding or conversion of FSRU is considered, the construction period expands to several years along with high capital costs. Also, when a second-handed LNG carrier conversion is considered, one has to account for the age of the vessel and cargo containment type, since it determines the conversion cost and period. With respect to the cargo containment type, LNG carriers with membrane cargo containment system have to go through a partial reinforcement on its membrane structure to support the regasification facilities on the upper deck; storage of LNG and operation of regasification facilities are restricted due to the risk of sloshing damage from frequent partial loading of LNG.
  • Meanwhile, FSRU or SRV is moored to a jetty structure to withstand offshore weather and conditions. LNG is supplied to FSRU from LNC carrier (LNGC) through a loading arm installed on a jetty where both FSRU and LNGC are moored side by side. Once regasified by FSRU or SRV, high pressured natural gas (usually between 40 and 90 atm) is supplied to onshore through high pressure gas arm. During this process, because floating facilities like FSRU or LNG RV are influenced by tidal currents and wind, directional and rotational motions are accompanied. Thus, the loading arm and the high pressure gas arm have a large number of components which can absorb impact from the motions. If the FSRU or the LNG carrier is disconnected from the jetty beyond an operational range, the pipe line will automatically disconnect from the jetty for the safety. Although general LNG carriers are designed to operate under several pressures while loading and unloading of LNG, FSRU and LNG RV are constantly exposed to high pressure natural gas leak which can cause a fire or an explosion.
  • The present invention, facilities for offshore LNG floating storage with jetty regasification unit, is designed for reduction of a construction time and cost, and enhances the stability for operation when compared to a newly constructed or converted FSRU and LNG RV.
  • According to an aspect of the present invention, there is provided a facilities for offshore liquefied natural gas (LNG) floating storage with jetty regasification unit, the facilities comprising: a jetty unit of a steel structure or an iron concrete structure installed in offshore; a storage unit moored at the jetty unit providing a space for storing LNG; a regasification unit as a module which regasifies the LNG supplied from the storage unit, installed on a top portion of the jetty unit and is separable from the jetty unit; a utility unit comprising a power source and a sea water pump to supply power and sea water to the regasification unit; and a piping unit comprising unloading pipe for connecting the regasification unit and the storage unit and supplying pipe for carrying natural gas gasified by the regasification unit.
  • The utility unit may be implemented as a module to be separable from the jetty unit.
  • The regasification unit may be used an open rack vaporizer (ORV) using sea water for heat exchanger.
  • The sea water pump of the utility unit and a ballast water pump disposed in the storage unit may be simultaneously used to supply sea water to the regasification unit.
  • A power facility, a steam generator, and a ballast water pump disposed in the storage unit may be used to supply power, steam, and sea water, respectively, which are necessary for the regasification unit.
  • The storage unit may be fixed to the jetty unit, loads LNG from a movable LNG carrier or a floating storage unit (FSU), and carries the LNG to the regasification unit.
  • The storage unit may be separable from the jetty unit and movable to load LNG.
  • The storage unit may be the LNG carrier or an FSU.
  • The present invention of offshore LNG floating storage with jetty regasification unit can provide a solution that can dramatically reduce the possibilities of high pressured natural gas leak into the atmosphere when compared to regasification on a floating structure.
  • FIG. 1 is a schematic diagram of a liquefied natural gas (LNG) regasification unit according to an embodiment of the present invention.
    •
  • Hereinafter, the detailed mode for carrying out the present invention will be described with reference to exemplary embodiments of the invention.
  • FIG. 1 is a schematic diagram of a liquefied natural gas (LNG) regasification unit according to an embodiment of the present invention.
  • The LNG regasification unit, according to the present invention, is used to regasify LNG in offshore and supply the regasified LNG, to gas users onshore. And this invention includes the jetty unit 10, a storage unit 20, a regasification unit 30, a piping unit 40, and a utility unit 50.
  • The jetty unit 10 is a fixed structure installed in sea bed with its legs, made of steel or iron concrete. The term ‘jetty’ has various meanings, for example, a structure like a breakwater which distinguishes an inland and the sea, or a facility which is for anchoring vessels. To anchor large ships, such as container vessel, oil tankers, or LNG carriers, a site with certain depth of water, higher than a predetermined depth, is required.
  • And the jetty can be used for berthing in the way of stretching steeled structure from onshore to offshore or constructing a container terminal after dredging. In the present invention, the jetty unit 10 is a semi-permanent structure that is installed to maintain a constant altitude above the sea level to withstand the changes of the wave by tidal current. As the shape of jetty unit 10 is not limited, it can be changed according to the locations and conditions thereof as long as the storage unit 20 can be anchored at. A structure for anchoring the storage unit 20, such as a mooring dolphin or a fender, may be installed around the jetty unit 10, and is not shown in FIG. 1 for illustrative convenience (all the constituents are quite simply illustrated in FIG. 1).
  • The storage unit 20 provides a space for storing LNG once moored at the jetty unit 10. The storage unit 20 can be converted from a second-handed LNG carrier or an existing LNG floating storage unit (FSU). Meanwhile, the storage unit 20 may be fixedly moored at the jetty unit 10 and separated from the jetty unit 10 on occasional demands. Conventional operation involves supplying the LNG to the regasification unit 30 after receiving LNG from another LNG carrier. On an occasional demand, the storage unit 20 may move to a location where LNG is produced or another FSU by itself, then receives LNG therefrom and supply the LNG to the regasification unit 30 again after being moored at the jetty unit 10. In the latter case, for continuously regasification of LNG, another LNG carrier may supply LNG to the regasification unit 30, at the opposite side of the jetty unit 10.
  • Fixed or movable type of the storage unit 20 is determined according to circumstances or economical efficiency. For example, when a converted LNG carrier is used for the storage unit 20, storage type can be decided depending on the situation, as its mobility is already obtained.
  • Meanwhile, when a second-handed LNG vessel is used for the storage unit 20, the conversion process may require the vessel to operation both LNG loading pipe 21 and LNG unloading pipe 42 simultaneously, as general LNG carrier is designed not to proceed loading and unloading at the same time. Furthermore, if the storage unit 20 is expected to move, an appropriate facility for separating the unloading pipe 42 from the storage unit 20 is required as well.
  • The storage unit 20 includes a utility facility 22, such as a power facility, a steam generator, a ballast water pump P2, etc. which general LNG carriers and FSU are already equipped, thus no additional facility is needed when the second-handed LNG carrier or the FSU is converted.
  • The regasification unit 30 is a module for regasifying LNG which is supplied from the storage unit 20. The regasification unit 30 is also separable from the jetty unit 10. Installment of the regasification unit 30 on the jetty unit 10, which is fixed on the sea bed, allows LNG to be regasified in offshore without the problems which commonly occurs in operation of conventional FSRU of LNG RV, a danger of leakage of natural gas due to an automatic piping separation in the operation or abrupt disconnection of a high pressure gas arm on the jetty unit 10 under the various offshore conditions. Since regasification work is performed on the hull 11 of the jetty unit 10, LNG can be transferred through the pipe between the storage unit 20 and the regasification unit 30. The stability of the hull 11 allows more safe transfer of LNG, regardless of the storage unit 20 movement due to the waves and tidal current.
  • A heat exchanger of the regasification unit 30 in the present invention is an open rack vaporizer (ORV) that utilizes sea water as a heat source. By contacting the heat exchanger, sea water absorbs the heat and vaporizes LNG into gas. ORV is strongly recommended due to its low investment and operating cost. However, if sea water is not uniformly coated on the vaporizer, the heat exchanger freezes and deteriorates its structure. That is why the ORV cannot be installed on FSRU of LNG RV. For the present invention, fixed structure of the jetty unit 10 guarantees safe operation of the ORV, which is a relatively inexpensive heat exchange system.
  • A sea water pump P1 in the utility unit 50 and the ballast water pump P2 of the utility facility 22 in the storage unit 20 are used to supply sea water to the ORV. Although the sea water pump P1 and the ballast water pump P2 are designed to operate simultaneous as depicted in FIG1, it is not necessary to use both of them. The sea water pump P1 acts as a main pump and the ballast water pump P2 as an auxiliary pump. Or, only the sea water pump P1 may be operated if the storage unit 20 is disconnected. How to supply the sea water to the ORV are subject to circumstances.
  • The piping unit 40, connecting the regasification unit 30 and the storage unit 20, includes unloading pipe 41 for supplying LNG from the storage unit 20 to the regasification unit 30 and supply pipe 42 for supplying gasified LNG from the regasification unit 30 to the end users in onshore. If required part of the piping unit 40 may be installed below a sea level.
  • The utility unit 50 (module) includes a power source, the sea water pump P1, and the steam generator for supplying power, sea water, and steam, respectively, to the regasification unit 30. Similar with the regasification unit 30, it is installed on the jetty unit 10, but also separable. The utility unit 50 and the regasification unit 30 are connected by a power cable 51, sea water pipe 52, and steam pipe 53. They are respectively connected to the utility facilities in the storage unit 20 to be used simultaneously or complementarily in the present invention. Unlike shown in FIG.1, only the utility unit 50 may operate independently.
  • The piping unit 40, the power cable 51, the sea water pipe 52, and the steam pipe 53 are quite simply illustrated in FIG.1 for illustrative convenience, but the actual design is considerably complicated. Nevertheless, for the purpose of illustration, such simple diagram will be understood by those who have knowledge of this technology.
  • Now, functions and effects of regasification element will be described below with explanation of LNG regasification process.
  • LNG stored in the storage unit 20 is supplied to the regasification unit 30 through the unloading pipe 41. Once regasified through the unit 30, regasified LNG is carried to the end users’ pipe line onshore through the supplying pipe 42.
  • The storage unit 20 can be fixed to the jetty unit 10 to load LNG from an LNG carrier (supplied through the loading pipe 21) or can be moved by itself to receive LNG from a neighboring FSU or a location where LNG is produced. If the storage unit 20 moves to different site, designated replacement should substitute for the previous storage unit 20, in order to supply LNG continuously.
  • Power, sea water, and steam are supplied to the regasification unit 30 through the utility unit 50.
  • While the present invention has been particularly shown and described with reference to exemplary embodiments thereof, it will be understood that various changes in form and details may be possible in the technical range of this invention as defined by the following claims.
    •

Claims (8)

  1. Facilities for offshore liquefied natural gas (LNG) floating storage with jetty regasification unit, the facilities comprising:
    a jetty unit of a steel structure or an iron concrete structure installed in offshore;
    a storage unit moored at the jetty unit providing a space for storing LNG;
    a regasification unit as a module which regasifies the LNG supplied from the storage unit, installed on a top portion of the jetty unit and is separable from the jetty unit;
    a utility unit comprising a power source and a sea water pump to supply power and sea water to the regasification unit; and
    a piping unit comprising unloading pipe for connecting the regasification unit and the storage unit and supplying pipe for carrying natural gas gasified by the regasification unit.
  2. The facilities of claim 1, wherein the utility unit is implemented as a module to be separable from the jetty unit.
  3. The facilities of claim 1, wherein the regasification unit uses an open rack vaporizer (ORV) using sea water for heat exchanger.
  4. The facilities of claim 3, wherein the sea water pump of the utility unit and a ballast water pump disposed in the storage unit are simultaneously used to supply sea water to the regasification unit.
  5. The facilities of claim 1, wherein a power facility, a steam generator, and a ballast water pump disposed in the storage unit are used to supply power, steam, and sea water, respectively, which are necessary for the regasification unit.
  6. The facilities of claim 1, wherein the storage unit is fixed to the jetty unit, loads LNG from a movable LNG carrier or a floating storage unit (FSU), and carries the LNG to the regasification unit.
  7. The facilities of claim 1, wherein the storage unit is separable from the jetty unit and movable to load LNG.
  8. The facilities of claim 1, wherein the storage unit is the LNG carrier or an FSU.
EP11852293.7A 2010-12-30 2011-12-19 Facilities for offshore liquefied natural gas floating storage with jetty regasification unit Active EP2643629B1 (en)

Priority Applications (1)

Application Number Priority Date Filing Date Title
PL11852293T PL2643629T3 (en) 2010-12-30 2011-12-19 Facilities for offshore liquefied natural gas floating storage with jetty regasification unit

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
KR1020100139360A KR101018741B1 (en) 2010-12-30 2010-12-30 The facilities for offshore lng floating storage with jetty regasification unit
PCT/KR2011/009773 WO2012091337A2 (en) 2010-12-30 2011-12-19 Facilities for offshore liquefied natural gas floating storage with jetty regasification unit

Publications (3)

Publication Number Publication Date
EP2643629A2 true EP2643629A2 (en) 2013-10-02
EP2643629A4 EP2643629A4 (en) 2017-04-19
EP2643629B1 EP2643629B1 (en) 2019-12-11

Family

ID=43938281

Family Applications (1)

Application Number Title Priority Date Filing Date
EP11852293.7A Active EP2643629B1 (en) 2010-12-30 2011-12-19 Facilities for offshore liquefied natural gas floating storage with jetty regasification unit

Country Status (9)

Country Link
EP (1) EP2643629B1 (en)
JP (1) JP5597773B2 (en)
KR (1) KR101018741B1 (en)
CN (1) CN103328879B (en)
BR (1) BR112013016676B1 (en)
CL (1) CL2013001923A1 (en)
PL (1) PL2643629T3 (en)
UY (1) UY33848A (en)
WO (1) WO2012091337A2 (en)

Families Citing this family (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
KR20150026674A (en) * 2013-08-29 2015-03-11 대우조선해양 주식회사 Arrangement Structure of Floating and Storage Gas Power Plant
KR101715061B1 (en) 2015-07-02 2017-03-13 주식회사 가스이즈 floatable legged platform structure, building and opperation method thereof
CN107228275A (en) * 2017-05-26 2017-10-03 惠生（南通）重工有限公司 It is a kind of can flexible combination and unattended floating LNG stocking systems
KR20210092198A (en) * 2018-12-03 2021-07-23 닛키 글로벌 가부시키가이샤 floating equipment

Citations (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2008073152A2 (en) 2006-09-11 2008-06-19 Exxonmobil Upstream Research Company Open-sea berth lng import terminal

Family Cites Families (13)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
FR2653462B1 (en) * 1989-10-24 1992-02-14 Technip Geoproduction INTEGRATED SUSPENSION AND HANDLING DEVICE FOR THE LEGS OF A SELF-LIFTING OIL PLATFORM.
US6546739B2 (en) * 2001-05-23 2003-04-15 Exmar Offshore Company Method and apparatus for offshore LNG regasification
JP2003014194A (en) * 2001-07-02 2003-01-15 Kobe Steel Ltd Vaporizer unit and vaporizer construction method
US6829901B2 (en) * 2001-12-12 2004-12-14 Exxonmobil Upstream Research Company Single point mooring regasification tower
NO330955B1 (en) * 2003-04-30 2011-08-22 Torp Tech As Unloading and cargo evaporation device for ships
US7360367B2 (en) * 2004-07-18 2008-04-22 Wood Group Advanced Parts Manufacture Apparatus for cryogenic fluids having floating liquefaction unit and floating regasification unit connected by shuttle vessel, and cryogenic fluid methods
US7080673B2 (en) * 2004-04-30 2006-07-25 Sbm-Imodco, Inc. Quick LNG offloading
WO2006052896A1 (en) * 2004-11-08 2006-05-18 Shell Internationale Research Maatschappij B.V. Liquefied natural gas floating storage regasification unit
KR100888339B1 (en) * 2007-07-25 2009-03-10 대우조선해양 주식회사 Method and system for treating fluid used in lng regasification on maine structure
US20090199591A1 (en) * 2008-02-11 2009-08-13 Daewoo Shipbuilding & Marine Engineering Co., Ltd. Liquefied natural gas with butane and method of storing and processing the same
US20090208294A1 (en) * 2008-02-19 2009-08-20 Yao Aifeng Apparatus for off-shore processing of a hydrocarbon stream
WO2009131543A1 (en) * 2008-04-25 2009-10-29 National University Of Singapore Offshore fuel storage facility
KR20100135354A (en) * 2009-06-17 2010-12-27 대우조선해양 주식회사 Topside load support structure of floating ocean construct

Patent Citations (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2008073152A2 (en) 2006-09-11 2008-06-19 Exxonmobil Upstream Research Company Open-sea berth lng import terminal

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
FRANKLIN D. ET AL: "Converting Existing LNG Carriers for Floating LNG Applications", OTC 20683, 3 May 2010 (2010-05-03) - 6 May 2010 (2010-05-06), pages 1 - 11, XP009144910

Also Published As

Publication number Publication date
EP2643629B1 (en) 2019-12-11
WO2012091337A3 (en) 2012-09-27
EP2643629A4 (en) 2017-04-19
KR101018741B1 (en) 2011-03-04
BR112013016676B1 (en) 2020-10-20
WO2012091337A2 (en) 2012-07-05
UY33848A (en) 2012-06-29
CL2013001923A1 (en) 2014-04-11
CN103328879B (en) 2014-12-17
BR112013016676A2 (en) 2016-10-04
JP5597773B2 (en) 2014-10-01
JP2014505842A (en) 2014-03-06
PL2643629T3 (en) 2020-06-15
CN103328879A (en) 2013-09-25

Similar Documents

Publication Publication Date Title
WO2012091336A2 (en) Facilities for offshore liquefied natural gas floating storage with jack-up platform regasification unit
AU2016259407B2 (en) Floating LNG Plant
JP5009802B2 (en) Cryogenic fluid underwater transfer system
US6829901B2 (en) Single point mooring regasification tower
CA2663035C (en) Open-sea berth lng import terminal
BRPI0716258A2 (en) Method for Importing Liquefied Natural Gas, Fluid Conveying System, and Methods for Conveying Liquefied Natural Gas and for Conveying Fluid
WO2012091337A2 (en) Facilities for offshore liquefied natural gas floating storage with jetty regasification unit
WO2011098527A1 (en) Bow loading station with double deck for cryogenic fluid
WO2006088371A1 (en) System and method for offshore offloading and regasification of LNG
CA2994471C (en) A liquefied natural gas terminal
Lee et al. LNG regasification vessel-the first offshore LNG facility
Gervois et al. Offshore LNG Receiving Terminals: An Alternative To Onshore Terminal
ZA200403825B (en) Single point mooring regastification tower.

Legal Events

Date Code Title Description
TPAC Observations filed by third parties

Free format text: ORIGINAL CODE: EPIDOSNTIPA

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: 20130627

AK Designated contracting states

Kind code of ref document: A2

Designated state(s): AL 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 RS SE SI SK SM TR

DAX Request for extension of the european patent (deleted)
RAP1 Party data changed (applicant data changed or rights of an application transferred)

Owner name: SAMSUNG C&T CORPORATION

A4 Supplementary search report drawn up and despatched

Effective date: 20170322

RIC1 Information provided on ipc code assigned before grant

Ipc: F17C 7/04 20060101AFI20170316BHEP

Ipc: F17C 9/02 20060101ALI20170316BHEP

Ipc: B63B 25/16 20060101ALI20170316BHEP

Ipc: F17C 5/06 20060101ALI20170316BHEP

GRAP Despatch of communication of intention to grant a patent

Free format text: ORIGINAL CODE: EPIDOSNIGR1

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

Free format text: STATUS: GRANT OF PATENT IS INTENDED

INTG Intention to grant announced

Effective date: 20190702

GRAS Grant fee paid

Free format text: ORIGINAL CODE: EPIDOSNIGR3

GRAA (expected) grant

Free format text: ORIGINAL CODE: 0009210

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

Free format text: STATUS: THE PATENT HAS BEEN GRANTED

AK Designated contracting states

Kind code of ref document: B1

Designated state(s): AL 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 RS SE SI SK SM 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: AT

Ref legal event code: REF

Ref document number: 1212545

Country of ref document: AT

Kind code of ref document: T

Effective date: 20191215

REG Reference to a national code

Ref country code: DE

Ref legal event code: R096

Ref document number: 602011064011

Country of ref document: DE

REG Reference to a national code

Ref country code: IE

Ref legal event code: FG4D

REG Reference to a national code

Ref country code: NL

Ref legal event code: MP

Effective date: 20191211

REG Reference to a national code

Ref country code: LT

Ref legal event code: MG4D

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

Ref country code: LT

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

Effective date: 20191211

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: 20191211

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: 20200311

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: 20191211

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: 20191211

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: 20200311

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: 20191211

REG Reference to a national code

Ref country code: GR

Ref legal event code: EP

Ref document number: 20200400695

Country of ref document: GR

Effective date: 20200518

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

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: 20191211

Ref country code: RS

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: 20191211

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

Ref country code: AL

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: 20191211

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: 20191211

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: 20191211

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: 20191211

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: 20200506

Ref country code: NL

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: 20191211

REG Reference to a national code

Ref country code: CH

Ref legal event code: PL

REG Reference to a national code

Ref country code: BE

Ref legal event code: MM

Effective date: 20191231

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: 20191211

Ref country code: SM

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: 20191211

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: 20200411

REG Reference to a national code

Ref country code: DE

Ref legal event code: R097

Ref document number: 602011064011

Country of ref document: DE

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: 20191211

REG Reference to a national code

Ref country code: AT

Ref legal event code: MK05

Ref document number: 1212545

Country of ref document: AT

Kind code of ref document: T

Effective date: 20191211

PLBE No opposition filed within time limit

Free format text: ORIGINAL CODE: 0009261

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

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

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

Ref country code: 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: 20191211

Ref country code: LU

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

Effective date: 20191219

26N No opposition filed

Effective date: 20200914

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: 20191211

Ref country code: LI

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

Effective date: 20191231

Ref country code: CH

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

Effective date: 20191231

Ref country code: BE

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

Effective date: 20191231

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: 20191211

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: 20191211

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

Ref country code: CY

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

Effective date: 20191211

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: 20111219

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: 20191211

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

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: 20191211

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

Ref country code: GR

Payment date: 20231227

Year of fee payment: 13

Ref country code: GB

Payment date: 20231219

Year of fee payment: 13

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

Ref country code: IE

Payment date: 20231220

Year of fee payment: 13

Ref country code: FR

Payment date: 20231227

Year of fee payment: 13

Ref country code: DE

Payment date: 20231220

Year of fee payment: 13

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

Ref country code: PL

Payment date: 20231123

Year of fee payment: 13

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

Ref country code: TR

Payment date: 20231218

Year of fee payment: 13

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

Ref country code: AL

Payment date: 20231204

Year of fee payment: 13