JPS59216785A - Transportation system for lng - Google Patents

Transportation system for lng

Info

Publication number
JPS59216785A
JPS59216785A JP58091587A JP9158783A JPS59216785A JP S59216785 A JPS59216785 A JP S59216785A JP 58091587 A JP58091587 A JP 58091587A JP 9158783 A JP9158783 A JP 9158783A JP S59216785 A JPS59216785 A JP S59216785A
Authority
JP
Japan
Prior art keywords
lng
bog
gas
tank
transport
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.)
Pending
Application number
JP58091587A
Other languages
Japanese (ja)
Inventor
Ikuo Miki
郁雄 三木
Hiroshi Makihara
牧原　洋
Keijirou Yoshida
圭二郎 吉田
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.)
Mitsubishi Heavy Industries Ltd
Original Assignee
Mitsubishi Heavy Industries Ltd
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 Mitsubishi Heavy Industries Ltd filed Critical Mitsubishi Heavy Industries Ltd
Priority to JP58091587A priority Critical patent/JPS59216785A/en
Publication of JPS59216785A publication Critical patent/JPS59216785A/en
Pending legal-status Critical Current

Links

Classifications

    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J1/00—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
    • F25J1/0002—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures characterised by the fluid to be liquefied
    • F25J1/0022—Hydrocarbons, e.g. natural gas
    • F25J1/0025—Boil-off gases "BOG" from storages
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J1/00—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
    • F25J1/0002—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures characterised by the fluid to be liquefied
    • F25J1/0012—Primary atmospheric gases, e.g. air
    • F25J1/0015—Nitrogen
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J1/00—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
    • F25J1/003—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures characterised by the kind of cold generation within the liquefaction unit for compensating heat leaks and liquid production
    • F25J1/0032—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures characterised by the kind of cold generation within the liquefaction unit for compensating heat leaks and liquid production using the feed stream itself or separated fractions from it, i.e. "internal refrigeration"
    • F25J1/004—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures characterised by the kind of cold generation within the liquefaction unit for compensating heat leaks and liquid production using the feed stream itself or separated fractions from it, i.e. "internal refrigeration" by flash gas recovery
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J1/00—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
    • F25J1/02—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures requiring the use of refrigeration, e.g. of helium or hydrogen ; Details and kind of the refrigeration system used; Integration with other units or processes; Controlling aspects of the process
    • F25J1/0221—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures requiring the use of refrigeration, e.g. of helium or hydrogen ; Details and kind of the refrigeration system used; Integration with other units or processes; Controlling aspects of the process using the cold stored in an external cryogenic component in an open refrigeration loop
    • F25J1/0223—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures requiring the use of refrigeration, e.g. of helium or hydrogen ; Details and kind of the refrigeration system used; Integration with other units or processes; Controlling aspects of the process using the cold stored in an external cryogenic component in an open refrigeration loop in combination with the subsequent re-vaporisation of the originally liquefied gas at a second location to produce the external cryogenic component
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J1/00—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
    • F25J1/02—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures requiring the use of refrigeration, e.g. of helium or hydrogen ; Details and kind of the refrigeration system used; Integration with other units or processes; Controlling aspects of the process
    • F25J1/0221—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures requiring the use of refrigeration, e.g. of helium or hydrogen ; Details and kind of the refrigeration system used; Integration with other units or processes; Controlling aspects of the process using the cold stored in an external cryogenic component in an open refrigeration loop
    • F25J1/0224—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures requiring the use of refrigeration, e.g. of helium or hydrogen ; Details and kind of the refrigeration system used; Integration with other units or processes; Controlling aspects of the process using the cold stored in an external cryogenic component in an open refrigeration loop in combination with an internal quasi-closed refrigeration loop
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J1/00—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
    • F25J1/02—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures requiring the use of refrigeration, e.g. of helium or hydrogen ; Details and kind of the refrigeration system used; Integration with other units or processes; Controlling aspects of the process
    • F25J1/0243—Start-up or control of the process; Details of the apparatus used; Details of the refrigerant compression system used
    • F25J1/0257—Construction and layout of liquefaction equipments, e.g. valves, machines
    • F25J1/0275—Construction and layout of liquefaction equipments, e.g. valves, machines adapted for special use of the liquefaction unit, e.g. portable or transportable devices
    • F25J1/0277—Offshore use, e.g. during shipping
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J1/00—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
    • F25J1/02—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures requiring the use of refrigeration, e.g. of helium or hydrogen ; Details and kind of the refrigeration system used; Integration with other units or processes; Controlling aspects of the process
    • F25J1/0243—Start-up or control of the process; Details of the apparatus used; Details of the refrigerant compression system used
    • F25J1/0279—Compression of refrigerant or internal recycle fluid, e.g. kind of compressor, accumulator, suction drum etc.
    • F25J1/0292—Refrigerant compression by cold or cryogenic suction of the refrigerant gas
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2210/00—Processes characterised by the type or other details of the feed stream
    • F25J2210/42—Nitrogen
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2210/00—Processes characterised by the type or other details of the feed stream
    • F25J2210/62—Liquefied natural gas [LNG]; Natural gas liquids [NGL]; Liquefied petroleum gas [LPG]
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2260/00—Coupling of processes or apparatus to other units; Integrated schemes
    • F25J2260/42—Integration in an installation using nitrogen, e.g. as utility gas, for inerting or purging purposes in IGCC, POX, GTL, PSA, float glass forming, incineration processes, for heat recovery or for enhanced oil recovery

Abstract

PURPOSE:To transport LNG safely by producing LN2 at an LNG receiving base by utilizing a coldness of LNG, loading LNG on the LNG vessel, reliquefying by exchanging heat of BOG produced during transportation by the LNG vessel, as well as utilizing N2 gas as an anti-explosion gas. CONSTITUTION:LN2 is produced by utilizing coldness of LNG at an LNG receiving base or consumption base and loaded on a tank 11 inside the LNG carrier through a loading mouth 16. During the transportation of the LNG, BOG produced in the LNG tank 10 is exhausted from a top part of the tank 10 and after compressed by a compressor 12, it is reliquefied by a heat exchanger 21 in the LN2 tank 11. LN2 becomes N2 gas but a part of it is stored and used ass an anti-explosion gas. This construction prevents a pressure rise due to BOG on the LNG carrier to reliquefy, while at the same time to obtain the anti-explosion gas to enable the safe transportation.

Description

【発明の詳細な説明】 本発りｊは［、ＮＧの転送システムに関するものである
。詳しくは、ＬＮＧをある基地から別の基地へ輸送する
除に不可縫的に発生するボイルオフガス（以下、ＢＯＧ
と呼称〕を容易にかつ安価に再液化することによって回
収し、安全の４１’ｔＭ保と大気汚染等の防止を可能と
するＬＮＧの輸送システムに胸するものである。DETAILED DESCRIPTION OF THE INVENTION The present invention relates to a transfer system of [, NG. In detail, boil-off gas (hereinafter referred to as BOG), which is irreparably generated while transporting LNG from one base to another,
We are excited about the development of an LNG transportation system that can easily and inexpensively recover LNG by reliquefying it, maintain a safe 41'tM, and prevent air pollution.

ＬＮＧは、他の多（のエネルギー源と比較すると硫黄、
窒素、メタル、灰分などを含まず、公害防止策の上から
も優れたエネルギー圀であるため、今後わが国の政策面
でもＬＮＧは産業用、民需用としてその用途が拡大され
る方向にある。Compared to other energy sources, LNG contains sulfur,
Since LNG does not contain nitrogen, metals, or ash, and is an excellent energy source in terms of pollution prevention measures, the use of LNG for industrial and private purposes is likely to be expanded in the future in terms of Japanese policy.

しかしながら、大量の可燃性の液化ガスを低温下で液化
貯蔵し、輸送するため、保安の確保が最も優先される必
をがある。However, since large amounts of flammable liquefied gas are liquefied and stored at low temperatures and transported, ensuring safety must be given top priority.

ＬＮＧの輸送は、天然ガスを題する井戸の近傍又はガス
パイプラインで連結された遠隔の地に建設される液化基
地からＬＮＧを受入れ、消費に回すまでのある期間、こ
れを貯蔵しておくところの受入基地に輸送する場合（海
上１次輸送〕と、上述の受入基地からさらに小分けして
個々の消費基地に輸送する場合（主として海上２次輸送
）の２つに分けられる。ＬＮＧは、重圧下の沸点が約−
１６２Ｃであり、容器の耐圧強度の問題があるため通當
常圧近傍で貯蔵され、輸送される。従って、上述の帖送
過程においても。LNG transportation involves receiving LNG from a liquefaction terminal built near a natural gas well or in a remote location connected by a gas pipeline, and storing it for a certain period of time before consumption. There are two types of transport: LNG is transported to a base (primary sea transport), and it is further divided from the above-mentioned receiving base and transported to individual consumption bases (mainly secondary sea transport). The boiling point is about -
162C, and because there is a problem with the pressure resistance of the container, it is usually stored and transported near normal pressure. Therefore, also in the above-mentioned shipping process.

ＬＨＯ）／ｆｉ、温と外部温度との差に由来Ｊ−る外部
からの入熱によつ゛（、ＢＯＧが発生する。比較的小輸
送量の海上２仄輸送では、ＢＯＧを処理する方法として
は大気放出が最も安易な方法であるが。BOG is generated due to heat input from the outside due to the difference between LHO)/fi and external temperature. BOG is generated as a method of processing BOG in 2-way sea transport with a relatively small transport volume. However, the easiest method is to release it into the atmosphere.

８０Ｇの大気放出は支全面や環境保全面から好ましくな
い。現にＬＮｃ−大型輸送船では、厳しい規制が設けら
れ、海難防止協会、学識経験者、海上保安庁、港湾′Ｗ
埋当局などが一体となって対策がとられており少なくと
も入港時にはＢＯＣＴの大気放出は禁じられている。Emission of 80G into the atmosphere is undesirable from the viewpoint of support and environmental protection. In fact, strict regulations are in place for LNc - large transport vessels, and the Maritime Accident Prevention Association, academic experts, the Japan Coast Guard, and ports'
The burial authorities and other authorities are working together to take measures, and the release of BOCT into the atmosphere is prohibited, at least when entering the port.

このよ５４７　ＢＯＧの大気放出は厳重につつしむべき
ことであるため、これに代る有効な方法として、仄の６
つの方式が考えられている。Since the release of 547 BOG into the atmosphere should be strictly respected, an effective alternative method is to
Two methods are being considered.

■蓄圧方式：　ＬＮＧ貯ｈｃ答器容器圧強度を高め、発
生するＢＯＧをある一定期間内刺 じ込める。■Pressure accumulation method: Increases the pressure strength of the LNG storage HC reactor container and stores the generated BOG within a certain period of time.

■推進用燃料化方式：　ＢＯＧを船舶推進用の燃料に使
用する。■Propulsion fuel method: BOG is used as fuel for ship propulsion.

■再液化方式：液化７リントを装備し、ＢＯＧを再び液
化してＬＮＣ＋貯蔵容器に戻 すＯ ところで、上記５つの方式はそれぞれ一長一短を有して
おり、すべてを満足するものではない。すなわち■の蓄
圧方式は容器の耐圧を高めると飛躍的に装置自体のコス
トが高くなることに加え、輸送船の可成効率が低下し、
輸送コストが増加することになる。■の燃料化方式は、
特に海上２次輸送用の比較的小型の船舶ではディーゼル
機関を使用しているためＢＯＧは燃料に不適当であるこ
と、またＢＯＧ発生モードと推進機運転モードが適合し
にくいなどの不都合がある。さらに、■の再液化方式は
、新たに再液化のためのプラントを装備する必要があり
、コスト高となる。また付言すれば、海上１次輸送と２
次輸送では、明らかに輸送するＬＮＧの危および距離（
すなわち時間ンに大きな差があるため、技術、経済、保
安の各面の要因を総合して判断すると、海上１次輸送で
は■の燃料化方式と■の再液化方式が適しており、一方
海上２次輸送では■の蓄圧方式が適していると一般的に
言える。■Re-liquefying method: Equipped with a 7-lint liquefaction unit to liquefy the BOG again and return it to the LNC+storage container O By the way, each of the above five methods has its advantages and disadvantages, and not all of them are satisfactory. In other words, with the pressure accumulation method (■), increasing the pressure resistance of the container dramatically increases the cost of the device itself, and also reduces the production efficiency of the transport ship.
This will increase transportation costs. ■The fuel conversion method is
In particular, relatively small ships for secondary marine transportation use diesel engines, so BOG is unsuitable as a fuel, and the BOG generation mode and propulsion engine operation mode are difficult to match. Furthermore, the reliquefaction method (2) requires the installation of a new reliquefaction plant, resulting in high costs. Also, I would like to add that primary maritime transport and secondary
In the next transport, it is clear that the danger and distance of the LNG to be transported (
In other words, since there is a large difference in the time taken, judging from a comprehensive consideration of technological, economic, and security factors, the fuel conversion method (2) and the reliquefaction method (2) are suitable for primary marine transport; It can generally be said that the pressure accumulation method (■) is suitable for secondary transportation.

本発明は、特に海上２次輸送において前述の・　ような
従来法の欠点を解消し、安価に容易にＢＯＧを再液化し
て回収することにより、ＢＯＧによる保安上、環境保全
上の問題を防止することを可能としたものである。すな
わち、ＬＮＧの一次受入基地又はＬＮＧ消１を基地のい
づれか一方、あるいはそれらの両者においてＬＮＧの保
有している冷熱を利用して窒気分離もしくは窒素ガスの
冷却を行なうことによって液体窒素（以下ＬＮ　　と呼
称ンを製造し、当該ＬＮ２の適当量をＬＮＧ輸送船にＬ
ＮＧとは別の貯槽に積載し、航海中に発生するＢＯＧを
ＡｉＪ記ＬＮ２と熱交換させることによって、ＢＯＧを
液化回収するものである。The present invention eliminates the drawbacks of the conventional methods described above, especially in secondary marine transportation, and prevents security and environmental conservation problems caused by BOG by easily reliquefying and recovering BOG at low cost. This made it possible to do so. In other words, liquid nitrogen (hereinafter referred to as LN A suitable amount of the LN2 is then transferred to an LNG transport ship.
The BOG will be liquefied and recovered by loading it into a storage tank separate from NG and exchanging heat with the AiJ LN2 generated during the voyage.

このとき、ＬＮ２とＢＯＧとの熱交換によって発生する
Ｎ２　　ガスは、甲板以下のＬＮＧ貯僧囲りの船倉部分
に送り込むことによって、万が−のＬＮＧ漏洩時の爆発
性雰囲気の形成を防止することに用いることができる。At this time, the N2 gas generated by heat exchange between LN2 and BOG is sent into the hold area surrounding the LNG storage below the deck to prevent the formation of an explosive atmosphere in the unlikely event of an LNG leak. It can be used for.

上述のように本発明は、ＢＯＧ回収のために本来ＬＮＧ
が保有している冷熱を陸上のプラントでＬＮ２の形に置
換し、これをＬＮＧ船による輸送時に蒸発させてその潜
熱でＢＯＧを液化するもので、船舶上の装置を極めて簡
易としたものである。以下に、本発明の有効性を実施の
態様に基づいて詳細に説明する。As mentioned above, the present invention originally uses LNG for BOG recovery.
This system converts the cold energy held by the BOG into LN2 at an onshore plant, evaporates it during transportation by an LNG ship, and uses the latent heat to liquefy the BOG, making the equipment on the ship extremely simple. . The effectiveness of the present invention will be explained in detail below based on embodiments.

第１図は、ＬＮＧの海上２次輸送の模様を図示したもの
である。第１図において、ＴはＬＮＧ受入基地でありＣ
１，Ｇ２．・・・顔はＴよりＬｔＪＧをもらい受けて消
費する基地である。１は海上１次輸送によって産ガス国
の液化基地から輸送されて（るＬＮＧで、これを受入基
地Ｔのタンクに貯蔵している。他方で消費基地０１．Ｃ
２・・・ＣＮ　　ではそれぞれ小口の消費者１−■、１
−■・・・、１−＠；２−■、２−■・・−２−＠；・
・・Ｎ−■、Ｎ−■°°・。Figure 1 illustrates the secondary maritime transportation of LNG. In Figure 1, T is the LNG receiving terminal and C
1, G2. ...The face is the base that receives and consumes LtJG from T. 1 is LNG transported from a liquefaction terminal in a gas-producing country by sea primary transportation, and is stored in a tank at a receiving terminal T.On the other hand, LNG is stored in a tank at a receiving terminal T.
2...CN, small consumers 1-■, 1, respectively.
-■..., 1-@;2-■, 2-■...-2-@;-
・・N−■, N−■°°・.

Ｎ−■をかかえ、ガスパイプライン９によってこれらの
小口消費者に天然ガスを供給している。The gas pipeline 9 supplies natural gas to these small consumers.

海上２次輸送とは、前述の受入基地Ｔと？ＦＶ費基地Ｃ
，，ａ２・・・籟　を結ぶ船舶Ｓによる輸送のことで、
特に日本のように周囲を海で囲まれた国では好都合な手
段である。一般に２次輸送手段としては陸上バイグライ
ン、タンクローリ−車小型船舶などがあるが、ＢＯＧが
問題となるのはタンクローリ−車小型船舶の場合である
。What is secondary maritime transport and the above-mentioned receiving base T? FV cost base C
,,a2... transport by ship S connecting the
This is especially convenient in a country like Japan, which is surrounded by the sea. In general, secondary transportation means include land big lines, tanker trucks, and small vessels, but BOG becomes a problem in the case of tanker trucks, small vessels, and the like.

第１図において受入基地Ｔと消費基地Ｃ１，Ｃ２・・・
ＯＮ　　を結ぶ船舶Ｓはルート２でＴから０１　　にＬ
）ＪＧを運び、消費基地ｃ１　　でＬＮＧを全量アンロ
ードしたあとルート５で古び受入基地Ｔに戻ることもあ
るし、ルート２．４．５で示すように何れかの消費基地
でアンロードしたあと再び受入基地Ｔに戻って１サイク
ルの航海を終えることもある。また受入基地Ｔは、これ
に近接した消費者があれば第１図に示すようにパイフリ
イン８を通じて小口消費者Ｔ−■、Ｔ−■、・・・Ｔ−
■に直接ガスを供給していても良い。本発明のシステム
を可能とするには、先ず、上述の受入基地Ｔ又は消費基
地Ｃ，，ａ２．・・・籟の少なくとも１箇所以上のとこ
ろで輸送中に生じるＢＯＧの液化に必要なＬＮ２の製造
を行なうことである。In Fig. 1, receiving base T and consumption bases C1, C2...
Vessel S connecting ON is route 2 from T to 01 to L
) After unloading the entire amount of LNG at the consumption base c1, it may return to the old receiving base T via route 5, or after unloading at any consumption base as shown in route 2.4.5. They may return to receiving base T again to complete one cycle of voyage. In addition, if there are consumers in the vicinity of the receiving base T, small-lot consumers T-■, T-■, . . . T-
■Gas may be supplied directly to. In order to enable the system of the present invention, first, the above-mentioned receiving base T or consuming base C,, a2. ...Production of LN2 necessary for liquefaction of BOG generated during transportation at at least one location on the rice grains.

ＬＮＧの寒冷を利用するＬＮ２の製造法としては、後述
するように色々な方法が考えられるが、本　“発明のシ
ステムでは、特定の方法に限定されるものではな（、個
々の事情に応じて適当な方法を採用して良い。本発明の
システムでは、前述のようなＬＮＧのローディング、ア
ンローディングを含む船舶の航海サイクルにおいて、受
入基地Ｔ又は消費基地Ｃ１，Ｃ２・・・籟　に立ち寄っ
た際に１その後の航海中やｂＮａ　４７４載のままの待
機時間において発生が予想されるＢＯＧの量にさらに適
当な余裕を見込んで、これらのＢＯＧの液化に必要なＬ
Ｎ２をＬＮＧとは別の貯ｎＪ　Ｋ積載する。当該ＬＮＧ
輸送船におけるＢＯＧ再液化の方法を第２図に基づいて
より詳細に説明する。Various methods can be considered for producing LN2 using the refrigeration of LNG, as described below, but the system of the present invention is not limited to a specific method (depending on individual circumstances). Any suitable method may be adopted.In the system of the present invention, when stopping at receiving base T or consumption bases C1, C2... 1. Considering the amount of BOG that is expected to be generated during the subsequent voyage and waiting time while the bNa 474 is still on board, the L required for liquefaction of these BOG is calculated.
N2 is stored separately from LNG and loaded in nJK. The LNG concerned
The method of BOG reliquefaction in a transport ship will be explained in more detail based on FIG. 2.

第２図において、ＬＮＧ　１５は貯槽１０１／（貯えら
れる。この図示の例では、ＬＮＧ貯摺貯槽形であり、通
常のＬＮＧ輸送船では当該タンクを４基程度有している
。また本発明のシステムでは、さらにＬＮ２の貯槽１１
、圧縮機１２、熱交換器２１を装備する。この際、熱交
換器２１は第２図の例では、６１１述のＬＮ２貯槽の下
部にＬＮ２の液面下に没するように管群を配置ｆｆｆｉ
　してＬＮ２１４と圧縮後のＢＯＧと熱交換させている
が、ＬＮ２貯槽と熱交換器とは切り離して、独立の熱交
換器を設置し、配管等で連結しても良い。第２図のよう
な装置配齢によって、先ずＬＮＧ　Ｉｈ′槽１０で発生
するＢＯＧ　１５は、当該貯槽の頂部から抜き出され、
ライン１７を経て圧縮υを１２に運ばれ、ここで圧縮さ
れる。次ｋｃ　ＥＥ圧縮機ＢＯＧ　２２は、熱交換５２
１に送られ、ＬＮ２１４と熱交換して液化する。熱交換
器２１から出て来る冷却後のＢＯＧ　２４は、運転条件
によっては全量液化しない場合も考えられるため、必要
に応じて気液分離器２３に導びかれ、気液が分離された
のち、ＬＮＧ　１９は再び供給ノズル２５を通じて古び
ＬＮＧの貯槽１０に戻され、他方未凝縮のＢＯＧ２０は
ｉＴＴびライン１７に合流して圧＃＃機１２に送られる
。In FIG. 2, LNG 15 is stored in a storage tank 101/(.In this illustrated example, it is an LNG storage tank type, and a normal LNG transport ship has about four such tanks. The system also includes LN2 storage tank 11.
, a compressor 12, and a heat exchanger 21. At this time, in the example shown in FIG. 2, the heat exchanger 21 has a group of tubes arranged at the bottom of the LN2 storage tank described in 611 so as to be submerged below the liquid level of LN2.
Although the LN214 and the compressed BOG are exchanged with each other, the LN2 storage tank and the heat exchanger may be separated, an independent heat exchanger may be installed, and the LN2 storage tank and the heat exchanger may be connected to each other by piping or the like. According to the equipment arrangement as shown in FIG. 2, the BOG 15 generated in the LNG Ih' tank 10 is first extracted from the top of the storage tank.
Via line 17 the compressed υ is conveyed to 12 where it is compressed. Nextkc EE compressor BOG 22 heat exchanger 52
1, where it exchanges heat with LN214 and liquefies it. The cooled BOG 24 coming out of the heat exchanger 21 may not be completely liquefied depending on the operating conditions, so it is led to the gas-liquid separator 23 as necessary to separate the gas and liquid, and then The LNG 19 is again returned to the aged LNG storage tank 10 through the supply nozzle 25, while the uncondensed BOG 20 joins the iTT line 17 and is sent to the pressure machine 12.

一方ＬＮ２の挙動は次のように説明される。液化基地も
しくは消費基地において製造されたＬＮ２は、　ＬＮＧ
輸送船畜港時にローディングアームジヨイント１６から
２イン２６を通じてＬＮ２の貯槽１１に送り込まれる。On the other hand, the behavior of LN2 can be explained as follows. LN2 produced at a liquefaction terminal or consumption terminal is LNG
When the transport ship is brought to port, it is sent from the loading arm joint 16 to the LN2 storage tank 11 through the 2-in 26.

つぎに航海中を含めＬＮＧがその貯槽１ｏにある限り、
洛に発生しているＢＯＧを再液化するためｆＪｔｆ述の
ような操作がなされる際、熱交換器２１において圧縮後
のＢＯＧ　２２と熱交換することによってＬＮ２自身は
蒸発潜熱分を与えられることによって気化し、Ｎ２　　
ガス１８となりＬＮ２貯僧外に取り出される。Next, as long as LNG is in the storage tank 1o, including during the voyage,
When the operation described in fJtf is performed to reliquefy the BOG generated in the LN2, the LN2 itself is given latent heat of vaporization by exchanging heat with the compressed BOG 22 in the heat exchanger 21. vaporized, N2
It becomes gas 18 and is taken out of the LN2 reservoir.

第２図に示す例では当該Ｎ　ガス１８は甲板以下の空間
を満たすことに使用されている。甲板以下の臣間内の空
気をパージしてＮ２　　ガス封入することによって、万
が−のＬＮａｔ７ｆｔ洩時に発生する可能性がある天然
ガスの爆発性雰囲気の形成を防止することができる。ま
た、第２図に示すような本発明のシステムではＬＮ２に
よってＢＯＧの再液化が可能になるためには、当然のこ
となからＬＮ２の桿点よりもＢＯＧの露点の方が高（な
ければならないこと、また操作圧力も前に述べたように
耐圧の上昇に伴なう装置費の上昇を避けるには可能な限
り常圧に近いことが必要である。本発明のシステムでは
最も耐圧の面から容易な重圧近傍で操作しても、本発明
のシステムが機能すると言える。すなわち第６図ＫＢＯ
Ｇの露点、ＬＮ２の沸点のそれぞれにつき圧力との関係
を示すとおり、常圧下でのＢＯＧの露点は約−１６２Ｃ
であり、またＬＮ２（Ｄｔ３点は一１９６Ｃであり、そ
の差すなわち伝熱のドライビングフォースは約５４Ｃ程
度がとれることとなる。In the example shown in FIG. 2, the N gas 18 is used to fill the space below the deck. By purging the air in the cabin below deck and filling it with N2 gas, it is possible to prevent the formation of an explosive natural gas atmosphere that could occur in the unlikely event of a 7ft LNat leak. In addition, in the system of the present invention as shown in Fig. 2, in order for BOG to be reliquefied by LN2, the dew point of BOG must be higher than the rod point of LN2. In addition, as mentioned earlier, the operating pressure must be as close to normal pressure as possible in order to avoid an increase in equipment costs due to an increase in pressure resistance. It can be said that the system of the present invention functions even when operated near easy heavy pressure. That is, Fig. 6 KBO
As shown in the relationship between the dew point of G and the boiling point of LN2, the dew point of BOG under normal pressure is approximately -162C.
Also, LN2 (Dt3 points is -196C, and the difference between them, that is, the driving force of heat transfer, is about 54C.

また、ＢＯＧの圧縮機１２で圧縮する程度はＢＯＧを液
化後、再びＬＮＧ貯槽に送り届けるに必要な圧力損失分
を補な５だけでよいか、多少の余裕を見込んで圧縮して
も良い。例えば、常圧から２気圧（絶対圧）まで圧縮し
た場合にはＢＯＧの露点は一１５５Ｃとなり、他方ＬＭ
２は常圧で操作するとしてＬＮ２の沸点との差は４６Ｃ
となり、十分熱交換可能であり、さらＷ圧力に余裕があ
れば第２図に示すように気液分離器２３に入る手前で液
化後のＢＯＧ　２４を＃張弁２７で膨張さく１３　　Ｂ
ＯＧ　１　）７７時当り、ＢＯＧを酸化するために必要
なＬＮ２の量を求めてみる。１例として、ＢＯＧもＬＮ
２も共に常圧下で取り扱うものとし、ＢＯＧは圧縮後−
１００Ｃとなって熱交換器に入り、常圧下の飽和液（−
１６２Ｃ）で同熱交換器を去り、他方ＬＮ２は゛帛圧下
の飽和液（−１９６′Ｃ）から蒸発して−１２００の過
熱蒸気として同熱交換器を去るものとする。Further, the degree of compression by the BOG compressor 12 may be just 5 to compensate for the pressure loss required to send the BOG to the LNG storage tank again after liquefaction, or it may be compressed by allowing some margin. For example, when compressing from normal pressure to 2 atmospheres (absolute pressure), the dew point of BOG will be -155C, and the dew point of LM
Assuming that 2 is operated at normal pressure, the difference from the boiling point of LN2 is 46C.
If sufficient heat exchange is possible and there is a margin in the W pressure, the liquefied BOG 24 is expanded with the # expansion valve 27 before entering the gas-liquid separator 23 as shown in Figure 2.
OG1) Let's find the amount of LN2 required to oxidize BOG per 77 hours. As an example, BOG is also LN
2 shall be handled under normal pressure, and BOG shall be handled under normal pressure.
The temperature reaches 100C and enters the heat exchanger, and the saturated liquid (-
162C), while LN2 is evaporated from the saturated liquid (-196'C) under pressure and leaves the heat exchanger as superheated steam at -1200C.

ＢＯＧおよびＮ２　　のエンタルピ線図は、第４図に示
すようなものとなり、この図を参考にしてＢＯＧ　１　
）７７時を液化するのに必要！′、ｃＬＮ２の量をＷと
して熱収支をと９、Ｗについて解くと次のようになる。The enthalpy diagram of BOG and N2 is as shown in Figure 4, and with reference to this diagram, BOG 1
) Necessary to liquefy 77 o'clock! ', cIf the amount of LN2 is W, the heat balance is calculated as follows.

ＩＸ（１５０−２）＝Ｗ（７４−７） 、＝１５０−二’−＝２．２　）７７時　４−７ （２）つぎに、ＬＮＧの寒冷を利用してＬＮ２を装造す
る場合に、ＬＮＧの単位取収斌１トン／時当りどの程度
のＬＮ２が製造されるかを検討する。IX (150-2) = W (74-7) , = 150-2'- = 2.2 ) 77 hours 4-7 (2) Next, when building LN2 using the cold temperature of LNG, , consider how much LN2 is produced per 1 ton/hour of LNG unit collection.

第１表は、文献に公表されている５例についてまとめた
ものであるか、規模やプロセスの違いによって、ＬＮＧ
　１　）７７時当りのＬＮ２Ｈ＃Ｌ量は０．０５６〜０
．４８　）７７時の範囲にわたっている。ケースＡＳ−
Ｄは、ＬＮＧの顕熱、潜熱を合わせて利用し、必要とす
る圧縮動力等を外部から電力の形で補充しているのに対
し、ケースＥはＬＮＧを約５０　ａｔｍの加圧下で書ガ
ス化し約１０　ａｔｍの圧力まで膨張させてタービンを
回して動力を回収し、涼料窒気および窒素の圧縮動力を
すべてまかない、さらに余剰の電力を生み出しているの
で、ケースＥにおけるＬＮ２のＭ−ｉｉ、ｆｉｔが１桁
低い値となっている。Table 1 summarizes the five cases published in the literature, or
1) LN2H#L amount per 77 hours is 0.056 to 0
．． 48) over the range of 77 hours. Case AS-
In Case D, the sensible heat and latent heat of LNG are used together, and the necessary compression power is supplied externally in the form of electricity, whereas in Case E, LNG is converted into gas under a pressure of about 50 atm. The M-ii of LN2 in Case E is expanded to a pressure of about 10 atm, rotates a turbine, and recovers the power, which covers all the power for compressing the coolant nitrogen and nitrogen, and also generates surplus electricity. , fit is one digit lower.

〔５〕　　次に、ＬＮＧＩＦＩｌｉ送船舶におけるＢＯ
Ｇの発生量を検討する。第５図は、球形タンク方式のＬ
ＮＧ輸送船の場合の、プラスチック・７オームを断熱材
とした時の断熱拐の厚み忙対するＢＯＧ発生率を示した
ものである。この図よりタンクの答方１によってＢＯＧ
の発生率が異なることが判る。断熱材厚さを４００＋ｍ
とし、ＬＮＧ貯槽１基当りの容量２０００ｍとすると、
ＢＯＧ発生率は０．５％／日となる。[5] Next, BO on the LNGIFIli transport vessel
Consider the amount of G generated. Figure 5 shows the L of the spherical tank system.
This figure shows the BOG occurrence rate depending on the thickness of the insulation layer when plastic 7 ohm is used as the insulation material in the case of an NG transport ship. From this diagram, BOG by answer 1 for the tank.
It can be seen that the incidence rates are different. Insulation thickness 400+m
Assuming that the capacity of one LNG storage tank is 2000 m,
The BOG incidence is 0.5%/day.

本発明によるＬＮＧの輸送システムの有効性を以下の例
により詳しく説明する。The effectiveness of the LNG transportation system according to the present invention will be explained in detail by the following example.

例１ 世帯数約１７万を有する他方都市における民生用の都市
ガスをＬＮＧでまかなうことを想定する。この規模の都
市ではＬＮＧの年間使用量は約８０．０００　）７７年
であり、この値をさらに換算すると２１９トン７日とな
る。Example 1 It is assumed that city gas for civil use in another city with approximately 170,000 households will be supplied with LNG. In a city of this size, the annual consumption of LNG is approximately 80,000 tons per year, which is further converted to 219 tons per day.

上述の必要量のＬＮＧを、大規模なＬＮＧ受入基地から
当該地方都市の消費基地に輸送するに当り、球形タンク
方式の輸送船を使用することとし、さらに当該輸送船と
しては球形貯槽４基を有する総可載量２０００　ｍ５の
船を２隻用い、これらを通常時には交互に就航させるも
のとする。In order to transport the above-mentioned required amount of LNG from a large-scale LNG receiving terminal to a consumption base in the local city, a spherical tank type transport ship will be used, and the transport ship will also be equipped with four spherical storage tanks. Two ships with a total payload capacity of 2000 m5 will be used, and these will be put into service alternately during normal times.

ＬＮＧの比重は約０．４２であるから、当ＬＮＧ船１隻
当りの可載量は２０００Ｘ０．４２＝８４０）ンとなり
、したかってＭ＋Ｊ述の都市の必要分を８４０７２１９
＝５．８日はと゛まかなうことができる。したかつて当
該消費基地は約４日間に１回は、上記ＬＮＧ輸送船によ
るＬＮＧの補給を受ける必要があることになる。ＬＮＧ
を輸送するに当り、受入基地におけるローディングに１
日、受入基地から消費基地への航海に１日、さらに消費
基地におり−るアンローディングに１日、その後再び受
入基地に戻るために約１日すなわち、１サイクルの航海
に計４日を要するとする。したがって、年間ＬＮＧ船が
尚該消費基地のために稼動するのべ日数は次のようにな
る。Since the specific gravity of LNG is approximately 0.42, the carrying capacity per LNG ship is 2000 x 0.42 = 840), and therefore the required amount for the city described in M + J is 8407219
= 5.8 days can be covered. In the past, the consumption base would need to be resupplied with LNG by the LNG transport ship about once every four days. LNG
1 for loading at the receiving base when transporting
1 day for the voyage from the receiving base to the consuming base, 1 day for unloading at the consuming base, and approximately 1 day for returning to the receiving base, i.e., 4 days in total for one cycle of the voyage. Suppose then. Therefore, the total number of days that the LNG carrier is still operating for the consumption base per year is as follows.

ＬＮＧを積載していない状態でｒＦｊ費基地から受入基
地への帰路は、ＢＯＧ発生はないので、ＢＯＧ発生期間
は上記日数の％となる。（５）で述べたように第５図か
ら、断熱材厚さ４００日に対するＢＯＧ発生率を読みと
ると、０．５％／ｉであるから、年間のＢＯＧ発生量は
下記のようになる。Since no BOG occurs on the return trip from the rFj cost base to the receiving base without LNG being loaded, the BOG generation period is % of the above number of days. As mentioned in (5), from FIG. 5, the BOG generation rate for the insulation material thickness of 400 days is 0.5%/i, so the annual BOG generation amount is as follows.

　００ ＝０．１５８）ンーＢＯＧ／時 したがって、ＢＯＧの液化に必要なＬＮ２の量は、前述
の〔すの試算から、次のように算出される。00 = 0.158) -BOG/hour Therefore, the amount of LN2 required for liquefying BOG is calculated as follows from the above-mentioned trial calculation.

０．１５８Ｘ２．２＝０．３０　）７７時他方、ＬＮ２
をＬＮＧの消費基地で製造するとすれば、前述の（２」
の試算結果を利用して、ＬＮ２の製造量は次のように算
出される。0.158X2.2=0.30) At 77, on the other hand, LN2
If it is manufactured at an LNG consumption base, the above (2)
Using the trial calculation results, the production amount of LN2 is calculated as follows.

（９，１）ンーＬＮＧ／時）Ｘ（０，０５６〜０．４８
）＝０．５６〜４．４トン−すなわち、平約０．３３〜
４．４トン／時の割合でＬＭ２を製造することができる
。このＬＮ２Ｍ造量は１ｉｔＩ述（７）　ＢＯＧ　ノ再
液化に必要なＬＮ２７４０．５０トン／時を上回ってお
り、本発明によるＬＮＧの輸送システムは十分実現しう
るものであることが判る。上述の例からも判る通り、Ｌ
ＮＧ　輸送船におけるＢＯＧの発生量をいかに低く押え
るかが最も重要であるため、断熱材厚さを厚（するほか
、根本的に断熱方式を改善すればＢＯＧ発生率を上記例
に見る値の％とすることもそれほど困難ではな（、この
場合にはたちまち必要ＬＮ２量は％で済むこととなり、
このことは益々本発明の有効性を示すことになる。(9,1) - LNG/hour)X (0,056~0.48
)=0.56~4.4 tons - that is, about 0.33~
LM2 can be produced at a rate of 4.4 tons/hour. This LN2M production amount exceeds the LN2740.50 tons/hour required for BOG reliquefaction as described in 1itI (7), and it can be seen that the LNG transportation system according to the present invention can be fully realized. As can be seen from the above example, L
NG Since the most important thing is to keep the amount of BOG generated on a transport ship as low as possible, by increasing the thickness of the insulation material (in addition to fundamentally improving the insulation method, the BOG generation rate can be reduced by % of the value shown in the example above) It is not that difficult to do so (in this case, the required amount of LN2 can be reduced to %,
This further demonstrates the effectiveness of the present invention.

以上述べた通り、本発明はＬＮＧの受入基地および消費
基地の両方又はいづれか一方でＬＮＧ輸送船で導入した
ＬＮＧの寒冷を利用して液体窒素を製造し、当該液体蟹
素および輸送すべきＬＮＧヲＬＮＧ輸送船に積載し、ロ
ーディング、アンローディングおよび航海中を含めて当
該ＬＮＧ輸送ＬＮ２４船で発生するＢＯＧと前記液体窒
素と熱交換させることによって、当該ＢＯＧを再液化し
てＬＮＧ貯槽に戻すことにより、ＬＮＧ貯槽の圧力上昇
を防　　。As described above, the present invention utilizes the cooling of LNG introduced by an LNG transport ship to both an LNG receiving terminal and/or a consuming terminal to produce liquid nitrogen, and then removes the liquid nitrogen and the LNG to be transported. By loading the LNG transport ship and exchanging heat with the liquid nitrogen and the BOG generated on the LNG transport LN24 ship during loading, unloading, and voyage, the BOG is reliquefied and returned to the LNG storage tank. , prevent pressure rise in the LNG storage tank.

止するところのＬＮＧ輸送船ならびに当該受入および消
費の基地から成るＬＮＧｒＭ送システムシステムAn LNGrM transport system consisting of a stopping LNG transport vessel and its receiving and consumption base.

【図面の簡単な説明】[Brief explanation of drawings]

第１図は、ＬＮＧの海上２次恰送を模式的に圧す図、第
２図は、本発明のシステムのうち、ＬＮＧ輸送船舶で実
施するシステムの態杼を示１図、第５図は、　　ＢＯＧ
の露点に対する飽和圧力と凝縮潜熱の関係、およびＬＮ
２のｖト点に対する外相圧力と蒸発潜熱との関係を図示
したもので、それぞれ実線がＢＯＧ　、点線がＬＮ２に
ついての右関を示し、第４図は、ＢＯＧおよびＮ２　　
の温度丸エンタルピーの関係を示す図であり、第５図は
球形タンク方式のＬＮＧ貯槽における断熱材厚さとＢＯ
Ｇ発生率の関係を示す図である。 復代理人　内　１）　　明 復代理人　萩　原　亮　− 第４図 ン男　度　（０Ｃ） 第５図 断熱君理さ　（ｍｔｎ）Fig. 1 is a diagram schematically showing the secondary pumping of LNG at sea, Fig. 2 is a diagram showing the structure of the system of the present invention, which is implemented on an LNG transport vessel, and Fig. 5 is , BOG
The relationship between saturation pressure and latent heat of condensation with respect to the dew point of LN
Figure 4 shows the relationship between the external phase pressure and the latent heat of vaporization for the v point of No.
Figure 5 shows the relationship between the temperature and round enthalpy of the temperature, and Figure 5 shows the relationship between the insulation material thickness and the BO
It is a figure showing the relationship of G incidence rate. Sub-agent 1) Meikoku agent Ryo Hagiwara - Figure 4 Male degree (0C) Figure 5 Adiabatic degree (mtn)

Claims (2)

【特許請求の範囲】[Claims] （１）　　ＬＮＧ輸送船によって導入した受入基地およ
び／または消費基地でのＬＮＧの寒冷を利用して液体窒
素を製造し、当該液体窒素をＬＮＧ輸送船に積載し、当
該恰送船において発生するＬＮＧのボイルオフガスを前
記液体窒素と熱交換させて当該ボイルオフガスを再液化
することにより、ＬＮＧ貯槽の圧力上昇を防止すること
を特徴とするＬＮＧの輸送システム。(1) Produce liquid nitrogen by utilizing the cooling of LNG introduced by an LNG transport ship at a receiving terminal and/or a consumption terminal, load the liquid nitrogen onto an LNG transport ship, and generate LNG on the transport ship. An LNG transportation system, characterized in that the boil-off gas is heat-exchanged with the liquid nitrogen to re-liquefy the boil-off gas, thereby preventing a pressure increase in an LNG storage tank. （２）　　ＬＮＧ輸送船に＠祇した液体窒素の蒸発によ
って発生する窒素ガスをＬＮＧ　ｆ（ｌｉ送船の甲板以
下の窒間内に封入することによって安全を確保すること
を特徴とする特許請求の範囲第一項のＬＮＧの輸送シス
テム。(2) A patent claim characterized in that safety is ensured by sealing nitrogen gas generated by the evaporation of liquid nitrogen stored in an LNG transport ship into the nitrogen chamber below the deck of the LNG transport ship. LNG transportation system in scope 1.
JP58091587A 1983-05-26 1983-05-26 Transportation system for lng Pending JPS59216785A (en)

Priority Applications (1)

Application Number Priority Date Filing Date Title
JP58091587A JPS59216785A (en) 1983-05-26 1983-05-26 Transportation system for lng

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
JP58091587A JPS59216785A (en) 1983-05-26 1983-05-26 Transportation system for lng

Publications (1)

Publication Number Publication Date
JPS59216785A true JPS59216785A (en) 1984-12-06

Family

ID=14030678

Family Applications (1)

Application Number Title Priority Date Filing Date
JP58091587A Pending JPS59216785A (en) 1983-05-26 1983-05-26 Transportation system for lng

Country Status (1)

Country Link
JP (1) JPS59216785A (en)

Cited By (24)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2002095285A1 (en) * 1999-11-05 2002-11-28 Osaka Gas Co., Ltd. Device and method for pressure control of cargo tank of liquefied natural gas carrier
KR100726292B1 (en) 2005-10-06 2007-06-11 삼성중공업 주식회사 LNG reliquefaction method and apparatus in LNG carrier
WO2017105680A1 (en) * 2015-12-14 2017-06-22 Exxonmobil Upstream Research Company Expander-based lng production processes enhanced with liquid nitrogen
JP2018538197A (en) * 2015-12-14 2018-12-27 エクソンモービル アップストリーム リサーチ カンパニー Method of natural gas liquefaction on an LNG carrier storing liquid nitrogen
US10480854B2 (en) 2015-07-15 2019-11-19 Exxonmobil Upstream Research Company Liquefied natural gas production system and method with greenhouse gas removal
US10488105B2 (en) 2015-12-14 2019-11-26 Exxonmobil Upstream Research Company Method and system for separating nitrogen from liquefied natural gas using liquefied nitrogen
US10578354B2 (en) 2015-07-10 2020-03-03 Exxonmobil Upstream Reseach Company Systems and methods for the production of liquefied nitrogen using liquefied natural gas
US10663115B2 (en) 2017-02-24 2020-05-26 Exxonmobil Upstream Research Company Method of purging a dual purpose LNG/LIN storage tank
US11060791B2 (en) 2015-07-15 2021-07-13 Exxonmobil Upstream Research Company Increasing efficiency in an LNG production system by pre-cooling a natural gas feed stream
US11083994B2 (en) 2019-09-20 2021-08-10 Exxonmobil Upstream Research Company Removal of acid gases from a gas stream, with O2 enrichment for acid gas capture and sequestration
US11215410B2 (en) 2018-11-20 2022-01-04 Exxonmobil Upstream Research Company Methods and apparatus for improving multi-plate scraped heat exchangers
US11326834B2 (en) 2018-08-14 2022-05-10 Exxonmobil Upstream Research Company Conserving mixed refrigerant in natural gas liquefaction facilities
US11415348B2 (en) 2019-01-30 2022-08-16 Exxonmobil Upstream Research Company Methods for removal of moisture from LNG refrigerant
US11465093B2 (en) 2019-08-19 2022-10-11 Exxonmobil Upstream Research Company Compliant composite heat exchangers
US11506454B2 (en) 2018-08-22 2022-11-22 Exxonmobile Upstream Research Company Heat exchanger configuration for a high pressure expander process and a method of natural gas liquefaction using the same
US11536510B2 (en) 2018-06-07 2022-12-27 Exxonmobil Upstream Research Company Pretreatment and pre-cooling of natural gas by high pressure compression and expansion
US11555651B2 (en) 2018-08-22 2023-01-17 Exxonmobil Upstream Research Company Managing make-up gas composition variation for a high pressure expander process
US11578545B2 (en) 2018-11-20 2023-02-14 Exxonmobil Upstream Research Company Poly refrigerated integrated cycle operation using solid-tolerant heat exchangers
US11635252B2 (en) 2018-08-22 2023-04-25 ExxonMobil Technology and Engineering Company Primary loop start-up method for a high pressure expander process
US11668524B2 (en) 2019-01-30 2023-06-06 Exxonmobil Upstream Research Company Methods for removal of moisture from LNG refrigerant
US11806639B2 (en) 2019-09-19 2023-11-07 ExxonMobil Technology and Engineering Company Pretreatment and pre-cooling of natural gas by high pressure compression and expansion
US11808411B2 (en) 2019-09-24 2023-11-07 ExxonMobil Technology and Engineering Company Cargo stripping features for dual-purpose cryogenic tanks on ships or floating storage units for LNG and liquid nitrogen
US11815308B2 (en) 2019-09-19 2023-11-14 ExxonMobil Technology and Engineering Company Pretreatment and pre-cooling of natural gas by high pressure compression and expansion
US11927391B2 (en) 2019-08-29 2024-03-12 ExxonMobil Technology and Engineering Company Liquefaction of production gas

Citations (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
JPS4862184A (en) * 1971-11-17 1973-08-30
JPS4862814A (en) * 1971-11-22 1973-09-01

Patent Citations (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
JPS4862184A (en) * 1971-11-17 1973-08-30
JPS4862814A (en) * 1971-11-22 1973-09-01

Cited By (28)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6901762B2 (en) * 1999-11-05 2005-06-07 Osaka Gas Co., Ltd. Device and method for pressure control of cargo tank of liquefied natural gas carrier
WO2002095285A1 (en) * 1999-11-05 2002-11-28 Osaka Gas Co., Ltd. Device and method for pressure control of cargo tank of liquefied natural gas carrier
KR100726292B1 (en) 2005-10-06 2007-06-11 삼성중공업 주식회사 LNG reliquefaction method and apparatus in LNG carrier
US10578354B2 (en) 2015-07-10 2020-03-03 Exxonmobil Upstream Reseach Company Systems and methods for the production of liquefied nitrogen using liquefied natural gas
US10480854B2 (en) 2015-07-15 2019-11-19 Exxonmobil Upstream Research Company Liquefied natural gas production system and method with greenhouse gas removal
US11060791B2 (en) 2015-07-15 2021-07-13 Exxonmobil Upstream Research Company Increasing efficiency in an LNG production system by pre-cooling a natural gas feed stream
JP2018538197A (en) * 2015-12-14 2018-12-27 エクソンモービル アップストリーム リサーチ カンパニー Method of natural gas liquefaction on an LNG carrier storing liquid nitrogen
US10488105B2 (en) 2015-12-14 2019-11-26 Exxonmobil Upstream Research Company Method and system for separating nitrogen from liquefied natural gas using liquefied nitrogen
US10551117B2 (en) 2015-12-14 2020-02-04 Exxonmobil Upstream Research Company Method of natural gas liquefaction on LNG carriers storing liquid nitrogen
JP2019505755A (en) * 2015-12-14 2019-02-28 エクソンモービル アップストリーム リサーチ カンパニー Inflator-based LNG production process reinforced with liquid nitrogen
WO2017105680A1 (en) * 2015-12-14 2017-06-22 Exxonmobil Upstream Research Company Expander-based lng production processes enhanced with liquid nitrogen
US10663115B2 (en) 2017-02-24 2020-05-26 Exxonmobil Upstream Research Company Method of purging a dual purpose LNG/LIN storage tank
US10989358B2 (en) 2017-02-24 2021-04-27 Exxonmobil Upstream Research Company Method of purging a dual purpose LNG/LIN storage tank
US11536510B2 (en) 2018-06-07 2022-12-27 Exxonmobil Upstream Research Company Pretreatment and pre-cooling of natural gas by high pressure compression and expansion
US11326834B2 (en) 2018-08-14 2022-05-10 Exxonmobil Upstream Research Company Conserving mixed refrigerant in natural gas liquefaction facilities
US11506454B2 (en) 2018-08-22 2022-11-22 Exxonmobile Upstream Research Company Heat exchanger configuration for a high pressure expander process and a method of natural gas liquefaction using the same
US11635252B2 (en) 2018-08-22 2023-04-25 ExxonMobil Technology and Engineering Company Primary loop start-up method for a high pressure expander process
US11555651B2 (en) 2018-08-22 2023-01-17 Exxonmobil Upstream Research Company Managing make-up gas composition variation for a high pressure expander process
US11215410B2 (en) 2018-11-20 2022-01-04 Exxonmobil Upstream Research Company Methods and apparatus for improving multi-plate scraped heat exchangers
US11578545B2 (en) 2018-11-20 2023-02-14 Exxonmobil Upstream Research Company Poly refrigerated integrated cycle operation using solid-tolerant heat exchangers
US11415348B2 (en) 2019-01-30 2022-08-16 Exxonmobil Upstream Research Company Methods for removal of moisture from LNG refrigerant
US11668524B2 (en) 2019-01-30 2023-06-06 Exxonmobil Upstream Research Company Methods for removal of moisture from LNG refrigerant
US11465093B2 (en) 2019-08-19 2022-10-11 Exxonmobil Upstream Research Company Compliant composite heat exchangers
US11927391B2 (en) 2019-08-29 2024-03-12 ExxonMobil Technology and Engineering Company Liquefaction of production gas
US11806639B2 (en) 2019-09-19 2023-11-07 ExxonMobil Technology and Engineering Company Pretreatment and pre-cooling of natural gas by high pressure compression and expansion
US11815308B2 (en) 2019-09-19 2023-11-14 ExxonMobil Technology and Engineering Company Pretreatment and pre-cooling of natural gas by high pressure compression and expansion
US11083994B2 (en) 2019-09-20 2021-08-10 Exxonmobil Upstream Research Company Removal of acid gases from a gas stream, with O2 enrichment for acid gas capture and sequestration
US11808411B2 (en) 2019-09-24 2023-11-07 ExxonMobil Technology and Engineering Company Cargo stripping features for dual-purpose cryogenic tanks on ships or floating storage units for LNG and liquid nitrogen

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