JPH09183989A - Apparatus and method for re-liquefying boil-off gas in storage tank of liquefied natural gas - Google Patents
Apparatus and method for re-liquefying boil-off gas in storage tank of liquefied natural gasInfo
- Publication number
- JPH09183989A JPH09183989A JP34332195A JP34332195A JPH09183989A JP H09183989 A JPH09183989 A JP H09183989A JP 34332195 A JP34332195 A JP 34332195A JP 34332195 A JP34332195 A JP 34332195A JP H09183989 A JPH09183989 A JP H09183989A
- Authority
- JP
- Japan
- Prior art keywords
- liquefied natural
- lng
- natural gas
- bog
- gas
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Granted
Links
Landscapes
- Filling Or Discharging Of Gas Storage Vessels (AREA)
- Pipeline Systems (AREA)
Abstract
Description
【０００１】[0001]
【発明の属する技術分野】本発明は、液化天然ガス貯槽
の蒸発ガス再液化装置及び方法に関し、詳しくは、液化
天然ガスの貯蔵・圧送設備における液化天然ガス貯槽の
蒸発ガスを再液化するための装置及び方法に関する。BACKGROUND OF THE INVENTION 1. Field of the Invention The present invention relates to an apparatus and a method for reliquefying evaporated gas in a liquefied natural gas storage tank, and more particularly to reliquefying evaporated gas in a liquefied natural gas storage tank in a liquefied natural gas storage and pumping facility. An apparatus and a method.
【０００２】[0002]
【従来の技術】図３は、従来の液化天然ガス貯蔵・圧送
設備の一例を示す系統図であって、液化天然ガス（ＬＮ
Ｇ）を貯蔵するＬＮＧ貯槽１には、ＬＮＧ圧送ポンプ２
及びＬＮＧ気化器３を有するＬＮＧ送出系統４と、蒸発
ガス（ＢＯＧ；ＢｏｉｌｉｎｇＯｆｆ Ｇａｓ）圧縮機
５を有するＢＯＧ圧送系統６と、フレアスタック７を有
するＢＯＧ放出系統８とが設けられており、ＬＮＧ送出
系統４とＢＯＧ圧送系統６とは、カロリー調整装置９を
有する天然ガス（ＮＧ）圧送系統１０に合流し、所定圧
力，所定流量，所定カロリーの天然ガスを需要先に送出
する。2. Description of the Related Art FIG. 3 is a system diagram showing an example of a conventional liquefied natural gas storage and pumping facility.
LNG storage pump 1 for storing G) has LNG pressure feed pump 2
And a LNG delivery system 4 having an LNG vaporizer 3, a BOG pressure delivery system 6 having an evaporative gas (BOG; Boiling Off Gas) compressor 5, and a BOG release system 8 having a flare stack 7 are provided. The system 4 and the BOG pumping system 6 join a natural gas (NG) pumping system 10 having a calorie adjusting device 9 and deliver natural gas of a predetermined pressure, a predetermined flow rate and a predetermined calorie to a customer.
【０００３】ＬＮＧ貯槽１内のＬＮＧは、ＬＮＧ送出系
統４に導出され、ＬＮＧ圧送ポンプ２で必要な圧力まで
昇圧された後、海水や蒸気等を熱源としたＬＮＧ気化器
３で気化して天然ガスとなり、需要先の都市ガス用や発
電用燃料としてＮＧ圧送系統１０から送出される。需要
先の圧力が低い場合や、比較的に圧送量の少ないＬＮＧ
の地方用サテライト基地の場合等では、ＬＮＧ圧送ポン
プ２に代わり、ＬＮＧ貯槽１に設けられた加圧装置（図
示せず）により加圧され、自圧で圧送導出されることも
ある。The LNG in the LNG storage tank 1 is led to the LNG delivery system 4, boosted to the required pressure by the LNG pumping pump 2, and then vaporized by the LNG vaporizer 3 using seawater or steam as a heat source to naturally It becomes gas and is sent out from the NG pressure feeding system 10 as fuel for city gas or power generation at the demand destination. LNG when the pressure of the customer is low or the amount of pumping is relatively small
In the case of the local satellite base, etc., it may be pressurized by a pressurizing device (not shown) provided in the LNG storage tank 1 instead of the LNG pumping pump 2 and may be pumped out by its own pressure.
【０００４】ＬＮＧ貯槽１においては、ＬＮＧ輸送船か
らＬＮＧを導入する時の導入設備（図示せず）での熱侵
入や減圧による気化及びＬＮＧ貯槽１自体の断熱層から
の熱侵入により、ＬＮＧの一部が気化してＬＮＧ貯槽１
の頂部にＢＯＧとして滞留する。[0004] In the LNG storage tank 1, the LNG is transferred from the LNG transport ship by heat intrusion in an introduction facility (not shown) or vaporization by depressurization and heat intrusion from the heat insulating layer of the LNG storage tank 1 itself. Partly vaporized and LNG storage tank 1
Stays as BOG at the top of the.
【０００５】このＢＯＧは、有効利用のためにＢＯＧ圧
縮機５でＮＧ圧送系統１０に相当する圧力まで圧縮さ
れ、ＢＯＧ圧送系統６を経てＮＧ圧送系統１０の天然ガ
スに混合して送出されるようになっている。しかし、Ｌ
ＮＧ輸送船からＬＮＧを導入するときなど、ＢＯＧが大
量に、かつ、流量が大きく変動しながら発生する場合に
は、ＢＯＧ圧縮機５で吸収処理することが困難である。
このような場合、ＢＯＧは、ＢＯＧ放出系統８に設けた
フレアスタック７から系外に放出される。また、ＮＧ圧
送系統１０の送出ガスの需要量がＢＯＧの発生量より少
ない場合にも、同様にフレアスタック７から系外に放出
される。This BOG is compressed by the BOG compressor 5 to a pressure corresponding to that of the NG pressure feeding system 10 for effective use, and is mixed with the natural gas of the NG pressure feeding system 10 through the BOG pressure feeding system 6 so as to be delivered. It has become. But L
When a large amount of BOG is generated and the flow rate fluctuates greatly when introducing LNG from an NG transport ship, it is difficult to perform absorption treatment by the BOG compressor 5.
In such a case, BOG is released outside the system from the flare stack 7 provided in the BOG release system 8. Further, when the demand amount of the delivery gas of the NG pressure delivery system 10 is smaller than the production amount of BOG, the flare stack 7 is similarly released to the outside of the system.
【０００６】このようなＬＮＧの貯蔵・圧送設備におい
ては、設備完成後に需要量が計画量より大幅に増減する
場合がある。需要量が増大した場合には、ＮＧ圧送系統
１０の配管設備が地下埋設等により敷設されていること
から、配管設備の交換が実質上不可能なため、既設配管
で増量対応ができるように、圧送設備、すなわち、ＬＮ
Ｇ圧送ポンプ２の吐出圧力を高めるとともに、これに応
じてＢＯＧ圧縮機５の吐出圧力も高め、ＮＧ圧送系統１
０全体の送ガス圧力を高めて送出ガス量を増大させる必
要がある。そして、ＬＮＧをガスタービン発電用の燃料
として使用する場合の送出ガス圧力は、都市ガス用とし
て使用する場合に比べて一般的に高圧が要求されるた
め、ＢＯＧの圧縮動力費が大きくなる。[0006] In such LNG storage / pumping equipment, the demand quantity may greatly increase or decrease after the completion of the equipment. When the demand amount increases, since the piping equipment of the NG pumping system 10 is laid by underground burying or the like, it is practically impossible to replace the piping equipment, so that it is possible to increase the quantity by using the existing piping. Pumping equipment, that is, LN
The discharge pressure of the G pressure pump 2 is increased, and the discharge pressure of the BOG compressor 5 is also increased accordingly.
It is necessary to increase the delivery gas pressure of the entire zero to increase the delivery gas amount. Further, when the LNG is used as a fuel for gas turbine power generation, the delivery gas pressure is generally required to be higher than when it is used for city gas, so the compression power cost of the BOG increases.
【０００７】また、ＢＯＧは、メタン，エタン，プロパ
ン，ブタン，エチレン，プロピレン等からなるＬＮＧ成
分の内、沸点が低くカロリーの低いメタン分を主成分と
するため、ＢＯＧを系外に放出し続けると、ＬＮＧ貯槽
１内のＬＮＧのカロリーが高くなりすぎるので、ガスを
送出する際には、ＮＧ圧送系統１０に窒素ガス等を用い
たカロリー調整装置９を設けて送出ガスのカロリーを調
整する必要がある。[0007] In addition, since BOG contains methane having a low boiling point and low calories as a main component among LNG components composed of methane, ethane, propane, butane, ethylene, propylene, etc., BOG is continuously released to the outside of the system. Since the calorific value of LNG in the LNG storage tank 1 becomes too high, it is necessary to adjust the calorie of the sent gas by providing the calorie adjusting device 9 using nitrogen gas or the like in the NG pressure feeding system 10 when sending the gas. There is.
【０００８】さらに、ＢＯＧを再液化する再液化器を設
けてＢＯＧの再液化を行う場合は、寒冷源として一般的
にＬＮＧ送出系統４のＬＮＧが使用されるが、ＢＯＧと
寒冷源のＬＮＧとの温度差が一般的に１００℃以上と大
きいこと、及び、ＢＯＧ，送出ＬＮＧ双方の流量が変動
し、特に需要先のＮＧ需要量は、季節や昼夜のみなら
ず、時間単位でも変動することにより、再液化器の熱交
伝熱表面温度が変動し、これにより再液化器に繰返し熱
応力が生じる。そして、この繰返し熱応力は、温度差が
大きいほど、流量の変動周期が短いほど、また、流量変
動量が多いほど大きくなる。Further, when a reliquefaction unit for reliquefying BOG is provided to reliquefy BOG, LNG of the LNG delivery system 4 is generally used as a cold source, but BOG and LNG of the cold source are used. In general, the temperature difference is as large as 100 ° C or more, and the flow rates of both the BOG and the sending LNG fluctuate, and in particular, the NG demand of the demand destination fluctuates not only in season or day and night, but also in hourly units. The heat transfer surface temperature of the heat exchanger of the reliquefaction device fluctuates, which causes repeated thermal stress in the reliquefaction device. The repeated thermal stress increases as the temperature difference increases, the flow rate fluctuation period decreases, and the flow rate fluctuation amount increases.
【０００９】この解決策としては、伝熱管外表面温度
を、可能な限り寒冷源のＬＮＧ温度に近接させる必要が
ある。このためには、伝熱管内に流すＬＮＧの流速を毎
秒５ｍ程度に高めて、伝熱管内境膜伝熱係数を高める必
要がある。すなわち、伝熱管本数を管内許容圧力損失範
囲以内で可能な限り減らすか、あるいは、伝熱管直径を
小さなものとし、伝熱面積確保のために伝熱管長を長く
した構造としなければならない。As a solution to this, it is necessary to make the outer surface temperature of the heat transfer tube as close as possible to the LNG temperature of the cold source. For this purpose, it is necessary to increase the flow rate of LNG flowing in the heat transfer tube to about 5 m / sec to increase the heat transfer coefficient inside the heat transfer tube. That is, the number of heat transfer tubes must be reduced as much as possible within the allowable pressure loss range in the tubes, or the diameter of the heat transfer tubes must be small, and the length of the heat transfer tubes must be long to secure the heat transfer area.
【００１０】上記した過酷な状態で使用されるＢＯＧの
再液化器として、従来から一般的な熱交換器として使用
されていたシェルアンドチューブ式やプレートフィン式
構造の熱交換器を採用すると、上記した解決策が十分と
は言えず、熱応力で再液化器が破損する危険性があっ
た。If a shell-and-tube type heat exchanger or a plate fin type heat exchanger, which has been used as a general heat exchanger in the past, is adopted as the BOG reliquefier used under the severe conditions described above, The solution taken was not sufficient and there was a risk that the reliquefier would be damaged by thermal stress.
【００１１】まず、シェルアンドチューブ式熱交換器
は、基本的な伝熱管形状として、直管形状とＵ字管形状
とがあり、一般的に、伝熱管の最大長さは、約６ｍ程度
である。また、熱交換器として要求される回収熱交換率
を高くするためには交流型が望ましく、ＢＯＧの再液化
にあっては、入口が常温のガスであるのに対し、出口で
はＢＯＧが液化するから、液化ガスを保有できる温度及
び形状にする必要があるため、直管形状に比べて熱応力
の吸収は容易ではあるが、Ｕ字管形状のものを用いるこ
とは困難であった。したがって、縦型で、かつ、直管式
の固定管板型又は遊動頭型の熱交換器を用いなければな
らないが、この形式では、伝熱管の熱伸縮により発生す
る熱応力を回避し難く、信頼性に欠ける。また、シェル
側流体となるＢＯＧは、入口温度が高いために圧力損失
が大きくなり易い。圧縮動力を低く抑えるためには、圧
力損失を小さくしなければならないので、邪魔板間隔を
広くすることになり、管束の支持スパンが長くなって流
体の流動による振動が発生し、破損に至るまでの寿命が
短くなる。First, the shell-and-tube type heat exchanger has a straight tube shape and a U-shaped tube as a basic heat transfer tube shape. Generally, the maximum length of the heat transfer tube is about 6 m. is there. Further, in order to increase the recovery heat exchange rate required as a heat exchanger, an AC type is desirable, and in the reliquefaction of BOG, the inlet is a room temperature gas, whereas the BOG is liquefied at the outlet. Therefore, since it is necessary to have a temperature and a shape that can hold the liquefied gas, it is easier to absorb the thermal stress as compared with the straight pipe shape, but it is difficult to use the U-shaped pipe. Therefore, it is necessary to use a vertical type and a straight tube type fixed tube plate type or floating head type heat exchanger, but in this type, it is difficult to avoid thermal stress generated by thermal expansion and contraction of the heat transfer tube, Unreliable. Further, BOG, which is the shell-side fluid, tends to have a large pressure loss because the inlet temperature is high. In order to keep the compression power low, it is necessary to reduce the pressure loss, so the spacing between the baffles must be widened, and the supporting span of the tube bundle becomes longer, causing vibration due to the fluid flow and leading to damage. Shortens the life of.
【００１２】次に、プレートフィン式熱交換器は、基本
的な構造がサイドバーという剛性を持つ額縁の中に薄型
の仕切り板を設け、この仕切り板を境にしてＬＮＧとＢ
ＯＧとが熱交換する形式であるから、温端部，冷端部あ
るいは熱交換器内の流体間の最大温度差が１００℃以上
になると，寒冷側流体のＬＮＧの流速を高くして仕切り
板温度をＬＮＧ温度に近似させたとしても、流体流路が
緻密なフィン流路であるため、温度差の大きなＢＯＧが
局部的に異なる温度の仕切り板を加熱する可能性があ
り、熱疲労破損を招く危険性が高い。さらに、プレート
フィン式熱交換器は、流体間温度差が１００℃以上とな
るような熱交換器として使用された実績はなく、したが
って、信頼性に乏しく、かつ、上記したような流量変動
が大きく変動周期の短い使用条件になるＢＯＧの再液化
器に採用すると、熱疲労破損の危険は更に高くなる。Next, in the plate fin type heat exchanger, a thin partition plate is provided in a frame whose basic structure is a side bar, which has rigidity, and LNG and B are separated by this partition plate.
Since the OG is a type of heat exchange, when the maximum temperature difference between the hot end, the cold end or the fluid in the heat exchanger is 100 ° C or more, the flow velocity of the LNG of the cold side fluid is increased and the partition plate Even if the temperature is approximated to the LNG temperature, since the fluid flow path is a dense fin flow path, the BOG with a large temperature difference may locally heat the partition plate at different temperatures, causing thermal fatigue damage. High risk of inviting. Further, the plate fin type heat exchanger has no history of being used as a heat exchanger having a fluid temperature difference of 100 ° C. or more, and is therefore unreliable and has a large flow rate variation as described above. If it is used in a BOG reliquefier that is subject to use conditions with a short fluctuation period, the risk of thermal fatigue damage becomes even higher.
【００１３】また、従来のＢＯＧの液化方法では、寒冷
源であるＬＮＧの液顕熱のみならず、蒸発潜熱まで使用
する方法が一般的であった。しかし、蒸発潜熱利用域で
は、寒冷源の沸騰を伴うので安定的な液化が行えず、Ｎ
Ｇ圧送系統１０、ＢＯＧ圧縮系統６の双方ともに圧力変
動が発生するという問題とともに、これに伴う配管系の
振動発生や熱応力発生について、これらを最少に抑える
という考慮がなされていなかった。Further, in the conventional liquefying method of BOG, it is general to use not only the sensible heat of LNG as a cold source but also the latent heat of vaporization. However, in the evaporation latent heat utilization region, stable liquefaction cannot be performed due to boiling of the cold source, and N
Along with the problem that pressure fluctuations occur in both the G pumping system 10 and the BOG compression system 6, it has not been taken into consideration that vibrations and thermal stresses in the piping system associated therewith are minimized.
【００１４】[0014]
【発明が解決しようとする課題】上記したように、従来
は、不定期に不定流量で発生するＢＯＧを有効に回収す
るためには、ＢＯＧ圧縮機５の吐出圧力をＮＧ圧送系統
１０の圧力まで高める必要があり、ＢＯＧのガス圧縮動
力が嵩むばかりでなく、ＢＯＧを系外に放出した場合
は、カロリー調整装置９を別途に設ける必要となる。ま
た、熱応力排除や安定運転等に関しても問題があった。As described above, conventionally, in order to effectively recover the BOG generated irregularly at an irregular flow rate, the discharge pressure of the BOG compressor 5 is reduced to the pressure of the NG pressure feeding system 10. It is necessary to increase the gas compression power of the BOG, and when the BOG is released to the outside of the system, the calorie adjusting device 9 needs to be additionally provided. In addition, there is a problem regarding elimination of thermal stress and stable operation.
【００１５】そこで本発明は、ＢＯＧ圧送動力費を低減
するとともに、ＢＯＧを安全かつ安定的に再液化できる
ＬＮＧ貯槽のＢＯＧ再液化装置及びＢＯＧの再液化方法
を提供することを目的としている。Therefore, an object of the present invention is to provide a BOG reliquefying apparatus for a LNG storage tank and a method for reliquefying BOG, which can reduce the power cost for pumping BOG and safely and stably reliquefy BOG.
【００１６】[0016]
【課題を解決するための手段】上記目的を達成するた
め、本発明の液化天然ガス貯槽の蒸発ガス再液化装置
は、液化天然ガス（ＬＮＧ）の貯蔵・圧送設備における
ＬＮＧ貯槽の蒸発ガス（ＢＯＧ）を再液化する装置であ
って、ＬＮＧを貯蔵するＬＮＧ貯槽と、該ＬＮＧ貯槽に
貯蔵したＬＮＧを所定圧力まで昇圧した後に気化して送
出するＬＮＧ圧送系統と、前記ＬＮＧ貯槽で発生したＢ
ＯＧを液化可能な圧力まで圧縮するＢＯＧ圧縮系統と、
前記ＬＮＧ圧送系統のＬＮＧと前記ＢＯＧ圧縮系統で圧
縮したＢＯＧとを熱交換させ、ＢＯＧを液化してＬＮＧ
を生成するシェルアンドコイル式の熱交換器からなるＢ
ＯＧ再液化器と、該ＢＯＧ再液化器で液化生成したＬＮ
Ｇを前記ＬＮＧ貯槽に戻す生成ＬＮＧ返送系統とを備え
たことを特徴としている。In order to achieve the above object, an apparatus for reliquefying vaporized gas in a liquefied natural gas storage tank according to the present invention is an apparatus for storing and pumping liquefied natural gas (LNG). ) Is a device for reliquefying LNG, an LNG storage tank for storing LNG, an LNG pumping system for evaporating and delivering LNG stored in the LNG storage tank to a predetermined pressure, and a BNG generated in the LNG storage tank.
A BOG compression system that compresses OG to a pressure at which it can be liquefied,
The LNG of the LNG pumping system and the BOG compressed by the BOG compression system are heat-exchanged to liquefy the BOG to obtain LNG.
B consisting of a shell-and-coil heat exchanger that produces
OG reliquefier and LN liquefied and produced by the BOG reliquefactor
A production LNG return system for returning G to the LNG storage tank is provided.
【００１７】さらに、前記ＢＯＧ再液化器で液化した生
成ＬＮＧを、前記ＬＮＧ圧送系統の前記ＢＯＧ再液化器
の出口側に送出して合流させる生成ＬＮＧ圧送系統を設
けたこと、前記ＢＯＧ再液化器のコイル側に前記ＬＮＧ
圧送系統のＬＮＧを、シェル側に前記ＢＯＧ圧縮系統で
圧縮したＢＯＧを導入すること、前記ＢＯＧ再液化器の
コイル側を複数の系統で構成するとともに、該複数のコ
イル側に、同一又は異なるＬＮＧ圧送系統のＬＮＧ流体
を通すこと、前記液化天然ガス圧送系統の蒸発ガス再液
化器入口側に、昇圧用の液化天然ガス圧送ポンプを設け
たこと、前記ＬＮＧ圧送系統のＢＯＧ再液化器出口側
に、二次昇圧用のＬＮＧ圧送ポンプを設けたことを特徴
としている。Further, there is provided a production LNG pumping system for delivering the produced LNG liquefied by the BOG reliquefying device to the outlet side of the BOG reliquefying device of the LNG pumping system to join the LNG producing system, and the BOG reliquefying device. LNG on the coil side of
Introducing a BOG compressed by the BOG compression system to the shell side of the LNG of the pumping system, configuring the coil side of the BOG reliquefier with a plurality of systems, and the same or different LNG on the plurality of coil sides. The LNG fluid of the pressure feeding system is passed, a liquefied natural gas pressure pump for pressurization is provided on the inlet side of the evaporative gas reliquefier of the liquefied natural gas pressure feeding system, and the BOG reliquefier outlet side of the LNG pressure feeding system is provided. It is characterized in that an LNG pump for secondary boosting is provided.
【００１８】また、本発明のＬＮＧ貯槽のＢＯＧ再液化
方法は、上記構成のＢＯＧ再液化装置におけるＢＯＧの
再液化方法であって、前記ＢＯＧ再液化器における液化
寒冷源として、ＬＮＧ圧送系統のＬＮＧの液顕熱のみを
使用することを特徴とし、さらに、前記ＢＯＧ再液化器
に導入するＬＮＧ圧送系統のＬＮＧの圧力を、臨界圧力
以上に高めることを特徴としている。The method for reliquefying BOG in a LNG storage tank according to the present invention is a method for reliquefying BOG in the BOG reliquefying apparatus having the above-mentioned structure, wherein the LNG pumping system LNG is used as a liquefying cold source in the BOG reliquefying device. It is characterized in that only the sensible heat of the above is used, and further, the pressure of the LNG in the LNG pumping system to be introduced into the BOG reliquefier is increased to a critical pressure or higher.
【００１９】[0019]
【発明の実施の形態】以下、本発明を、図面を参照して
さらに詳細に説明する。図１及び図２は本発明のＬＮＧ
貯槽のＢＯＧ再液化装置を適用したＬＮＧ貯蔵・圧送設
備の系統例を示すもので、図１はＬＮＧ圧送系統が１系
統の場合の系統図、図２はＬＮＧ圧送系統が２系統の場
合の系統図である。DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENTS Hereinafter, the present invention will be described in more detail with reference to the drawings. 1 and 2 show the LNG of the present invention.
Fig. 1 shows a system example of LNG storage and pumping equipment to which a BOG reliquefaction device for a storage tank is applied. Fig. 1 is a system diagram when one LNG pumping system is provided, and Fig. 2 is a system when two LNG pumping systems are provided. It is a figure.
【００２０】まず、図１に示すＬＮＧ貯蔵・圧送設備
は、ＬＮＧを貯蔵するＬＮＧ貯槽１１と、該ＬＮＧ貯槽
１１内からＬＮＧ送出系統１２に導出されたＬＮＧをＬ
ＮＧ圧送ポンプ１３で需要先の必要圧力まで昇圧した後
に、海水や蒸気等を熱源とするＬＮＧ気化器１４で気化
し、ＮＧとしてＮＧ圧送系統１５から需要先に送出する
ＬＮＧ圧送系統１６と、前記ＬＮＧ貯槽で発生したＢＯ
Ｇを液化可能な圧力まで圧縮するＢＯＧ圧縮機１７を備
えたＢＯＧ圧縮系統１８と、前記ＬＮＧ圧送系統１６を
流れるＬＮＧと前記ＢＯＧ圧縮系統１８で圧縮したＢＯ
Ｇとを熱交換させ、ＢＯＧを液化してＬＮＧを生成する
シェルアンドコイル式のＢＯＧ再液化器１９と、該ＢＯ
Ｇ再液化器１９で液化生成したＬＮＧ（生成ＬＮＧ）の
一部又は全部を前記ＬＮＧ貯槽１１に戻す生成ＬＮＧ返
送系統２０と、前記ＢＯＧ再液化器１９で液化した生成
ＬＮＧの一部又は全部を生成ＬＮＧポンプ２１で昇圧
し、前記ＬＮＧ圧送系統１６のＢＯＧ再液化器１９の出
口側に送出して合流させる生成ＬＮＧ圧送系統２２と、
フレアスタック２３を有するＢＯＧ放出系統２４とによ
り形成されている。なお、ＬＮＧ導入設備等は、図示及
び説明を省略する。First, in the LNG storage / pumping facility shown in FIG. 1, the LNG storage tank 11 for storing LNG and the LNG delivered from the LNG storage tank 11 to the LNG delivery system 12 are connected to the LNG storage tank 11.
After the pressure is increased to the required pressure of the demand destination by the NG pressure feed pump 13, it is vaporized by the LNG vaporizer 14 using seawater or steam as a heat source, and is sent as an NG from the NG pressure feed system 15 to the demand destination. BO generated in LNG storage tank
A BOG compression system 18 including a BOG compressor 17 for compressing G to a liquefiable pressure, an LNG flowing through the LNG pumping system 16, and a BO compressed by the BOG compression system 18.
A shell-and-coil type BOG reliquefying device 19 that heat-exchanges with G to liquefy BOG to produce LNG;
A part or all of the LNG (production LNG) liquefied and generated in the G reliquefaction device 19 is returned to the LNG storage tank 11, and a part or all of the generation LNG liquefied in the BOG reliquefaction device 19. A production LNG pumping system 22 for boosting the pressure with the production LNG pump 21, sending it to the outlet side of the BOG reliquefier 19 of the LNG pumping system 16, and joining it.
And a BOG release system 24 having a flare stack 23. Note that illustration and description of the LNG introduction equipment and the like are omitted.
【００２１】前記ＢＯＧ再液化器１９は、シェルアンド
コイル式熱交換器であり、その構造は周知のように、直
径の小さな、例えば直径１０ｍｍ程度の伝熱管からなる
コイル１９ａをシェル（外筒）１９ｂの軸方向中心上に
設けられた芯金（又は芯筒）の周りに螺旋状に多段に巻
き付け、各コイル段間にシェル側流体の通路を形成する
ため、円周方向に放射状にかつ伝熱管巻き付け高さ範囲
に、薄板帯状又は針金状のスペーサーを配設したもので
ある。The BOG reliquefier 19 is a shell-and-coil heat exchanger, and as its structure is well known, the coil 19a consisting of a heat transfer tube having a small diameter, for example, a diameter of about 10 mm is shelled (outer cylinder). 19b is spirally wound in multiple stages around a cored bar (or cored tube) provided on the axial center of 19b, and shell-side fluid passages are formed between the coil stages, so that radial and radial transmission is performed in the circumferential direction. A strip-shaped or wire-shaped spacer is arranged in the height range around which the heat tube is wound.
【００２２】このシェルアンドコイル式熱交換器は、コ
イル内流体とシェル側流体との温度差により発生する熱
歪を、螺旋状に巻き付けられた伸縮自在のコイル１９ａ
の伸縮で吸収できること、コイル１９ａの長さは１００
ｍ以上でも可能であり、長さ方向の構造的制約がないこ
と、管内流速を高くできるので管内側境膜伝熱も高くな
ること、スペーサーの寸法及び個数を最適に選定するこ
とによりシェル側流体の圧力損失を抑えながら流速も高
く設定できるからシェル側の境膜伝熱も高くできるこ
と、コイル１９ａがシェル１９ｂを貫通する管板をシェ
ル側の鏡板や胴体に複数個配設することにより、複数の
コイル内流体を流すようにすることが容易であること、
コイル内に高圧流体, シェル側に低圧流体を流すことに
より、安価でかつ構造強度に優れたものであること等の
長所を有するものであり、この結果、伝熱面積を小型化
するとともに、シェル側形状を細長くできるから、据え
付け面積も小さくできる。This shell-and-coil heat exchanger has an expandable coil 19a spirally wound about thermal strain generated by a temperature difference between a fluid inside the coil and a fluid on the shell side.
Can be absorbed by expansion and contraction, and the length of the coil 19a is 100
It is also possible to use m or more, there is no structural restriction in the length direction, the flow velocity in the pipe can be increased, so that the heat transfer to the film inside the pipe is also increased, and the size and number of spacers are optimally selected to make the shell side fluid Since the flow velocity can be set high while suppressing the pressure loss of the shell, the film heat transfer on the shell side can also be increased, and by disposing a plurality of tube plates through which the coil 19a penetrates the shell 19b on the shell side end plate or the body, It is easy to make the fluid in the coil flow,
By flowing a high-pressure fluid in the coil and a low-pressure fluid in the shell side, it has advantages such as being inexpensive and excellent in structural strength.As a result, the heat transfer area can be reduced and the shell can be made smaller. Since the side shape can be elongated, the installation area can be reduced.
【００２３】すなわち、シェルアンドコイル式の熱交換
器は、他の形式の熱交換器に比較して熱応力吸収性，熱
回収性，信頼性，小型化に優れ、いずれも不定期に不定
量変動するＢＯＧを圧送系統のＬＮＧで液化するＢＯＧ
再液化器１９として、最適な構造，機能を有している。That is, the shell-and-coil type heat exchanger is superior to other types of heat exchangers in heat stress absorption, heat recovery, reliability, and miniaturization, and any of them is irregular and irregular. BOG that liquefies fluctuating BOG with LNG in the pumping system
The reliquefaction device 19 has an optimum structure and function.
【００２４】ＬＮＧ貯槽１１内のＬＮＧは、ＬＮＧ送出
系統１２に導出されてＬＮＧ圧送ポンプ１３により需要
先の必要圧力まで昇圧された後、ＬＮＧ圧送系統１６を
通り、ＢＯＧ再液化器１９のコイル１９ａ側に液化寒冷
源として導入される。The LNG in the LNG storage tank 11 is led to the LNG delivery system 12 and boosted by the LNG pumping pump 13 to the required pressure of the customer, and then passes through the LNG pumping system 16 and the coil 19a of the BOG reliquefier 19. Introduced to the side as a liquefied cold source.
【００２５】一方，ＬＮＧ貯槽１１の上部に滞留したＢ
ＯＧは、ＢＯＧ圧縮系統１８に設けられたＢＯＧ圧縮機
１７により、前記ＢＯＧ再液化器１９に液化寒冷源とし
て導入されるＬＮＧ圧送系統１６のＬＮＧの温度で液化
可能な圧力まで圧縮された後、ＢＯＧ再液化器１９のシ
ェル１９ｂ側に導入される。On the other hand, B accumulated in the upper part of the LNG storage tank 11
The OG is compressed by the BOG compressor 17 provided in the BOG compression system 18 to a pressure at which it can be liquefied at the temperature of LNG in the LNG pumping system 16 that is introduced into the BOG reliquefaction device 19 as a liquefied cold source. It is introduced to the shell 19b side of the BOG reliquefier 19.
【００２６】ＢＯＧ再液化器１９のコイル１９ａ側に導
入されたＬＮＧは、ＢＯＧに液顕熱の範囲で寒冷を与え
て昇温し、ガス化せず液状のままＢＯＧ再液化器１９を
導出し、ＬＮＧ圧送系統１６のＬＮＧ気化器１４で海水
や蒸気等を熱源として気化し、ＮＧ圧送系統１５から需
要先に送出される。The LNG introduced to the coil 19a side of the BOG reliquefier 19 gives cold to the BOG in the range of sensible heat of the liquid to raise the temperature, and is led out of the BOG reliquefier 19 without being gasified. , LNG vaporizer 14 of LNG pumping system 16 vaporizes seawater, steam, etc. as a heat source, and sends out from NG pumping system 15 to a customer.
【００２７】また、液化可能な圧力まで圧縮されてＢＯ
Ｇ再液化器１９のシェル１９ｂ側に導入されたＢＯＧ
は、上記コイル１９ａ内を流れるＬＮＧ圧送系統１６の
ＬＮＧの液顕熱で冷却されて液化し、生成ＬＮＧとなっ
てＢＯＧ再液化器１９のシェル１９ｂ内に滞留する。Further, when the BO is compressed to a pressure at which it can be liquefied
BOG introduced to the shell 19b side of the G reliquefier 19
Is cooled and liquefied by the sensible heat of LNG in the LNG pumping system 16 flowing in the coil 19a, and becomes liquefied LNG, and stays in the shell 19b of the BOG reliquefier 19.
【００２８】そして、上記ＢＯＧ再液化器１９内の生成
ＬＮＧは、その一部あるいは全部が、生成ＬＮＧ圧送系
統２２に設けられた生成ＬＮＧポンプ２１で、ＬＮＧ圧
送系統１６と同じ圧力に昇圧された後、ＬＮＧ圧送系統
１６のＬＮＧ気化器１４の上流側に導入され、ＬＮＧ圧
送系統１６のＬＮＧと合流してＬＮＧ気化器１４で気化
し、ＮＧ圧送系統１５から需要先に送出される。The production LNG in the BOG reliquefaction device 19 is partially or wholly boosted to the same pressure as that of the LNG pumping system 16 by the production LNG pump 21 provided in the production LNG pumping system 22. After that, it is introduced to the upstream side of the LNG vaporizer 14 of the LNG pumping system 16, merges with the LNG of the LNG pumping system 16, is vaporized by the LNG vaporizer 14, and is delivered from the NG pumping system 15 to the demand destination.
【００２９】このように、ＢＯＧを、ＢＯＧ再液化器１
９でＬＮＧにより再液化させるために必要な圧力までＢ
ＯＧ圧縮機１７でガス圧縮し、ＢＯＧ再液化器１９で液
化生成した後に需要先の必要圧力まで生成ＬＮＧポンプ
２１で液状で昇圧することにより、従来、需要先の必要
圧力までガス圧縮していた場合に比べ、ＢＯＧの圧縮動
力費を低減できる。例えば、圧力７Ｋｇ／ｃｍ2 Ｇで流
量が毎時２０トンのＢＯＧを、ガス状で８０Ｋｇ／ｃｍ
2 Ｇまで圧縮する場合の圧縮動力は、約５０００ＫＷＨ
であるが、圧力７Ｋｇ／ｃｍ2 ＧでＢＯＧを液化した
後、液状で８０Ｋｇ／ｃｍ2 Ｇまで昇圧した場合の昇圧
動力は、約３５０ＫＷＨとなる。As described above, the BOG is transferred to the BOG reliquefaction device 1
9 up to the pressure required to reliquefy by LNG B
The gas is compressed by the OG compressor 17, liquefied and generated by the BOG reliquefier 19, and then generated up to the required pressure of the demand destination in a liquid state by the LNG pump 21, so that conventionally, the gas is compressed to the required pressure of the demand destination. Compared to the case, the BOG compression power cost can be reduced. For example, a BOG having a pressure of 7 Kg / cm 2 G and a flow rate of 20 tons per hour is used in a gaseous state of 80 Kg / cm.
The compression power when compressing up to 2 G is about 5000 KWH
Although, after liquefying BOG pressure 7 Kg / cm 2 G, the step-up power when pressurized to 80 Kg / cm 2 G in liquid form is about 350KWH.
【００３０】また、ＢＯＧの発生量が多く、ＬＮＧ圧送
系統１６のＬＮＧの成分が変化し、ＮＧ圧送系統１５で
需要先へ送出するＮＧのカロリーが高くなり過ぎるよう
な場合には、上述のようにして、ＢＯＧ再液化器１９で
液化した生成ＬＮＧをＬＮＧ圧送系統１６のＬＮＧに混
合したり、生成ＬＮＧ返送系統２０からカロリー調整に
見合う量をＬＮＧ貯槽１１に返送したりすることによ
り、ＢＯＧ発生量が多い場合でも、従来のようにカロリ
ー調整装置を設ける必要がなくなる。この生成ＬＮＧの
ＬＮＧ圧送系統１６への導入とＬＮＧ貯槽１１への返送
は、両者を同時に行ってもよく、いずれか一方のみを行
うようにしてもよい。When the amount of BOG generated is large and the LNG component of the LNG pumping system 16 changes, and the NG calorie delivered to the customer in the NG pumping system 15 becomes too high in calories, the above-mentioned procedure is performed. Then, by mixing the produced LNG liquefied by the BOG reliquefier 19 with the LNG of the LNG pumping system 16, or by returning the amount corresponding to the calorie adjustment from the produced LNG returning system 20 to the LNG storage tank 11, the BOG is generated. Even when the amount is large, it is not necessary to provide a calorie adjusting device as in the conventional case. The introduction of the produced LNG into the LNG pressure feeding system 16 and the return to the LNG storage tank 11 may be performed simultaneously, or only one of them may be performed.
【００３１】さらに、ＢＯＧ再液化器１９におけるＢＯ
Ｇの液化に際して寒冷源となるＬＮＧ圧送系統１６のＬ
ＮＧが沸騰しないようにＬＮＧの液顕熱のみを使用する
ことにより、安定した寒冷供給を行うことができるとと
もに、沸騰による振動の発生も防止できる。また、ＬＮ
Ｇ圧送系統１６のＬＮＧの圧力を臨界圧力以上に高める
ことにより、送出ＬＮＧ及びＢＯＧの流量変動による伝
熱表面温度変化時でもＬＮＧ側の沸騰ガス化を確実に防
止できるので、より安定した状態でＢＯＧの液化運転を
行うことができる。Further, the BO in the BOG reliquefier 19 is
L of the LNG pumping system 16 which becomes a cold source when liquefying G
By using only the liquid sensible heat of LNG so that NG does not boil, it is possible to perform stable cold supply and to prevent vibration due to boiling. Also, LN
By increasing the LNG pressure in the G pressure feeding system 16 to a critical pressure or higher, it is possible to reliably prevent boiling gasification on the LNG side even when the heat transfer surface temperature changes due to flow rate fluctuations of the sending LNG and BOG. A liquefaction operation of BOG can be performed.
【００３２】なお、送出ＮＧの圧力や流量によっては、
ＬＮＧ圧送ポンプ１３を設けることなくＬＮＧ貯槽１１
に需要先の必要圧力まで昇圧可能な加圧装置を設け、自
圧でＬＮＧを送出することも可能である。また、ＬＮＧ
貯槽１１のＬＮＧが、ＬＮＧ送出系統１２の自圧でＢＯ
Ｇ再液化器１９に導入することが可能な場合は、ＬＮＧ
圧送ポンプ１３をＢＯＧ再液化器１９の出口側に設置
し、ＬＮＧ送出系統１２のＬＮＧをポンプで昇圧するこ
となくＢＯＧ再液化器１９でＢＯＧの液化寒冷源として
使用した後、需要先圧力まで昇圧するように形成するこ
とが望ましい。これにより、寒冷源としての送出ＬＮＧ
の昇圧による温度上昇がなくなり、ＬＮＧの寒冷を有効
に利用できるので、ＢＯＧの液化可能な圧力を低くする
ことができ、ＢＯＧ圧縮機１７の動力費をさらに低減し
たり、ＢＯＧ再液化器１９を小型化したりすることがで
きる。Incidentally, depending on the pressure and flow rate of the delivery NG,
LNG storage tank 11 without providing LNG pressure pump 13
It is also possible to provide a pressurizing device capable of increasing the pressure up to the required pressure at the demand destination and to send LNG by its own pressure. Also, LNG
LNG of the storage tank 11 is BO by the self-pressure of the LNG delivery system 12.
If it can be introduced into the G reliquefier 19, LNG
The pump 13 is installed on the outlet side of the BOG reliquefier 19, and the LNG of the LNG delivery system 12 is used as a liquefied cold source of the BOG by the BOG reliquefier 19 without boosting the pressure, and then boosted to the demand pressure. It is desirable to form it. As a result, it is possible to send LNG as a cold source.
Since the temperature rise due to pressurization of LNG can be eliminated and the cold of LNG can be effectively utilized, the liquefiable pressure of BOG can be lowered, the power cost of BOG compressor 17 can be further reduced, and BOG reliquefier 19 can be used. It can be downsized.
【００３３】さらに、ＮＧ圧送系統１５から需要先へ送
出するＮＧの送出圧力が高い場合は、ＢＯＧ再液化器１
９の出口側のＬＮＧ圧送系統１６と生成ＬＮＧ圧送系統
２２との合流後、あるいは合流前に、二次昇圧用のＬＮ
Ｇポンプ（図示せず）を設けることで容易に対処でき
る。Furthermore, when the delivery pressure of the NG delivered from the NG pressure delivery system 15 to the customer is high, the BOG reliquefier 1
LN for secondary pressurization after or before the joining of the LNG pumping system 16 and the production LNG pumping system 22 on the outlet side of 9.
This can be easily dealt with by providing a G pump (not shown).
【００３４】さらにまた、ＢＯＧ再液化器１９内の生成
ＬＮＧの圧力が需要先の必要圧力以上の場合は、生成Ｌ
ＮＧ圧送系統２２の生成ＬＮＧポンプ２１を省略でき
る。Furthermore, when the pressure of the produced LNG in the BOG reliquefaction unit 19 is higher than the required pressure of the demand destination, the produced LNG is generated.
The generation LNG pump 21 of the NG pumping system 22 can be omitted.
【００３５】次に、図２に示すＬＮＧ貯蔵・圧送設備
は、２基のＬＮＧ貯槽１１ａ，１１ｂを設け、一方のＬ
ＮＧ貯槽１１ａのＬＮＧを比較的低圧の需要先、例えば
都市ガス用として、他方のＬＮＧ貯槽１１ｂのＬＮＧを
比較的高圧の需要先、例えば発電用燃料ガスとして、そ
れぞれ供給するように形成した例を示している。Next, the LNG storage / pumping facility shown in FIG. 2 is provided with two LNG storage tanks 11a and 11b, and one LNG storage tank is provided.
An example in which the LNG of the NG storage tank 11a is supplied to a relatively low-voltage demand destination, for example, for city gas, and the LNG of the other LNG storage tank 11b is supplied to a relatively high-pressure demand destination, for example, fuel gas for power generation Shows.
【００３６】一方のＬＮＧ貯槽１１ａに貯蔵されている
ＬＮＧは、該ＬＮＧ貯槽１１ａに設けられたＬＮＧ送出
系統１２ａに導出され、ＬＮＧ圧送ポンプ１３ａで需要
先の必要圧力まで昇圧された後、ＬＮＧ圧送系統１６ａ
に設けられたＢＯＧ再液化器３１の一方のコイル３１ａ
に導入される。The LNG stored in one of the LNG storage tanks 11a is led to an LNG delivery system 12a provided in the LNG storage tank 11a, boosted by a LNG pumping pump 13a to a required pressure at a demand destination, and then LNG pumped. System 16a
One coil 31a of the BOG reliquefier 31 provided in the
Will be introduced.
【００３７】また、他方のＬＮＧ貯槽１１ｂに貯蔵され
ているＬＮＧは、該ＬＮＧ貯槽１１ｂに設けられたＬＮ
Ｇ送出系統１２ｂに導出され、ＬＮＧ圧送ポンプ１３ｂ
で臨界圧力以上（例えば５０ｋｇ／ｃｍ2 Ｇ）に昇圧さ
れた後、ＬＮＧ圧送系統１６ｂを流れて前記ＢＯＧ再液
化器３１の他方のコイル３１ｂに導入される。The LNG stored in the other LNG storage tank 11b is the LN provided in the LNG storage tank 11b.
LNG pressure feed pump 13b led to G delivery system 12b
After the pressure is raised to a critical pressure or higher (for example, 50 kg / cm 2 G), it flows through the LNG pumping system 16b and is introduced into the other coil 31b of the BOG reliquefier 31.
【００３８】各ＬＮＧ貯槽１１ａ，１１ｂの上部に滞留
したＢＯＧは、それぞれのＢＯＧ圧縮系統１８ａ，１８
ｂに導出されてＢＯＧ圧縮機１７の手前で合流し、該Ｂ
ＯＧ圧縮機１７で前記ＢＯＧ再液化器３１の両コイル３
１ａ，３１ｂを流れる液化寒冷源であるＬＮＧの温度で
液化可能な圧力まで昇圧された後、ＢＯＧ再液化器３１
のシェル３１ｃ側に導入される。The BOG accumulated in the upper part of each LNG storage tank 11a, 11b is converted into the BOG compression system 18a, 18 respectively.
b and is merged in front of the BOG compressor 17,
Both coils 3 of the BOG reliquefier 31 in the OG compressor 17
After the pressure is increased to a liquefiable pressure at the temperature of LNG, which is a liquefaction cold source flowing through 1a and 31b, the BOG reliquefaction device 31
Is introduced on the side of the shell 31c.
【００３９】ＢＯＧ再液化器３１のコイル３１ａ，３１
ｂ側に導入された両ＬＮＧは、双方ともＢＯＧに液顕熱
の範囲（例えば、約−１２０〜約−１５５℃）で寒冷を
与え、ガス化せずに液状のまま昇温して導出され、コイ
ル３１ａを導出した低圧側のＬＮＧは、ＬＮＧ気化器１
４ａで気化してＮＧとなり、ＮＧ圧送系統１５ａから需
要先に送出される。また、コイル３１ｂを導出した高圧
側のＬＮＧは、二次昇圧用のＬＮＧ圧送ポンプ３２で需
要先の必要な圧力（例えば８０ｋｇ／ｃｍ2 Ｇ）まで更
に昇圧された後、ＬＮＧ気化器１４ｂで気化してＮＧと
なり、ＮＧ圧送系統１５ｂから需要先に送出される。一
方、液化可能な圧力まで圧縮されてＢＯＧ再液化器３１
に導入されたＢＯＧは、両ＬＮＧの液顕熱で冷却され液
化し、生成ＬＮＧとなってＢＯＧ再液化器３１のシェル
３１ｃの底部に滞留する。Coils 31a, 31 of the BOG reliquefaction device 31
Both LNG introduced to the b side give cold to the BOG in the range of sensible heat of the liquid (for example, about -120 to about -155 ° C), and are led out by raising the temperature in a liquid state without being gasified. , LNG on the low-pressure side that led out the coil 31a is the LNG vaporizer 1
4a vaporizes into NG and is sent to the demand destination from the NG pressure feeding system 15a. The LNG on the high-pressure side, which has led out the coil 31b, is further boosted to the pressure required by the customer (for example, 80 kg / cm 2 G) by the LNG pressure pump 32 for secondary boosting, and then vaporized by the LNG vaporizer 14b. It becomes NG and becomes NG, and is sent to the demand destination from the NG pressure feeding system 15b. On the other hand, the BOG reliquefier 31 is compressed to a pressure that can be liquefied.
The BOG introduced into the BOG is cooled and liquefied by the sensible heat of both LNG and becomes liquefied LNG, and stays at the bottom of the shell 31c of the BOG reliquefier 31.
【００４０】そして、上記生成ＬＮＧは、その一部又は
全部が生成ＬＮＧ圧送系統２２に導出され、生成ＬＮＧ
ポンプ２１で、前記高圧側のＬＮＧ圧送系統１６ｂを流
れるＬＮＧの圧力に応じた圧力まで昇圧された後、第２
ＬＮＧ圧送ポンプ３２の上流でＬＮＧ圧送系統１６ｂを
流れるＬＮＧと合流し、ＬＮＧ気化器１４ｂで気化して
ＮＧ圧送系統１５ｂから送出される。A part or all of the generated LNG is led to the generated LNG pumping system 22 to generate the generated LNG.
After being boosted by the pump 21 to a pressure corresponding to the pressure of the LNG flowing through the LNG pressure feeding system 16b on the high pressure side, the second
It is merged with LNG flowing in the LNG pressure feeding system 16b upstream of the LNG pressure feeding pump 32, vaporized by the LNG vaporizer 14b, and sent out from the NG pressure feeding system 15b.
【００４１】また、ＢＯＧの発生量が多く、その結果、
両ＬＮＧ圧送系統１６ａ，１６ｂのＬＮＧの成分が変化
し、需要先へ送るＮＧのカロリーが高くなり過ぎるよう
な場合には、ＢＯＧ再液化器３１で液化した生成ＬＮＧ
の適当量を生成ＬＮＧ返送系統２０に導出し、ＬＮＧ貯
槽１１ａ，１１ｂに、それぞれのカロリー調整に見合う
量が分岐経路２０ａ，２０ｂを介して分配返送すればよ
い。なお、ＬＮＧ圧送系統１６ａ，１６ｂへの導入混合
でカロリー調整可能な場合は、前記生成ＬＮＧ圧送系統
２２からＬＮＧ圧送系統１６ａ，１６ｂに生成ＬＮＧを
導入混合させるようにしてもよい。このとき、高圧側の
生成ＬＮＧ圧送系統２２から減圧弁を介して低圧側のＬ
ＮＧ圧送系統１６ａに生成ＬＮＧを導入するようにして
もよく、これとは別に、低圧側用の生成ＬＮＧ圧送系統
を設けるようにしてもよい。Further, a large amount of BOG is generated, and as a result,
When the LNG components of both LNG pumping systems 16a and 16b change and the calories of NG sent to the customer become too high, the generated LNG liquefied by the BOG reliquefier 31
It is sufficient to derive an appropriate amount of the above into the generation LNG returning system 20 and to distribute and return to the LNG storage tanks 11a and 11b through the branch paths 20a and 20b in an amount corresponding to each calorie adjustment. If calorie can be adjusted by introducing and mixing the LNG pumping systems 16a and 16b, the generated LNG may be introduced and mixed from the LNG pumping system 22 to the LNG pumping systems 16a and 16b. At this time, the low pressure side L is generated from the high pressure side generation LNG pressure feeding system 22 via the pressure reducing valve.
The generated LNG may be introduced into the NG pressure feed system 16a, or, in addition to this, a low pressure side generated LNG pressure feed system may be provided.
【００４２】なお、本形態例においても、前記図１の説
明で記載したように、例えば、ＬＮＧ貯槽から自圧でＬ
ＮＧを送出できる場合は、ＬＮＧ圧送ポンプを設ける必
要がないこと、生成ＬＮＧ圧送系統のＬＮＧ圧送系統へ
の接続位置を選択できることなど、その他、本発明の要
旨を逸脱しない範囲内において種々変更を加えることが
可能である。Also in this embodiment, as described in the description of FIG. 1, for example, the LNG storage tank is self-pressurized to the L level.
If NG can be delivered, it is not necessary to provide an LNG pumping pump, the connection position of the generated LNG pumping system to the LNG pumping system can be selected, and other various changes are made without departing from the scope of the present invention. It is possible.
【００４３】[0043]
【発明の効果】以上説明したように、本発明の液化天然
ガス貯槽の蒸発ガス再液化装置によれば、再液化させる
ＢＯＧは、該ＢＯＧを液化するための寒冷源であるＬＮ
Ｇ圧送系統のＬＮＧの温度で液化できる程度に圧縮すれ
ばよく、ＢＯＧを液化して生成した生成ＬＮＧを液化ポ
ンプで圧送系統の必要圧力まで昇圧するから、従来のＢ
ＯＧを圧送系統の圧力までガス圧縮するよりも圧送動力
費が低減できる。また、ＢＯＧを液化した生成ＬＮＧを
ＬＮＧ圧送系統のＬＮＧに混合して送出したり、ＬＮＧ
貯槽に戻したりすることにより、圧送ＬＮＧの成分が高
カロリー成分に偏ることが防止できるので、カロリー調
整装置を不要とすることができる。As described above, according to the evaporative gas reliquefying apparatus for a liquefied natural gas storage tank of the present invention, the BOG to be reliquefied is a cold source for liquefying the BOG, LN.
It is only necessary to compress the LNG in the G pumping system to such a degree that it can be liquefied, and the LNG produced by liquefying BOG is boosted to the required pressure in the pumping system by the liquefaction pump.
The cost of pumping power can be reduced as compared with gas compression of OG to the pressure of the pumping system. In addition, LNG produced by liquefying BOG is mixed with LNG in the LNG pumping system and sent out, or LNG is sent.
By returning to the storage tank, the components of the pressure-fed LNG can be prevented from being biased toward the high-calorie components, so that the calorie adjusting device can be omitted.
【００４４】特に、ＢＯＧ再液化器としてシェルアンド
コイル式の熱交換器を採用することにより、温度差が大
きく、かつ、流量変動の大きいＢＯＧを再液化する際に
発生する熱応力を回避することが容易であり、安全性が
高まるとともに、コイル側を複数の系統で構成すれば、
同一又は異なる複数のＬＮＧを、その寒冷を有効かつ容
易に利用しながら圧送することができる。In particular, by adopting a shell-and-coil type heat exchanger as the BOG reliquefying device, avoiding the thermal stress generated when reliquefying the BOG having a large temperature difference and a large flow rate fluctuation. It is easy and safety is improved, and if the coil side is composed of multiple systems,
The same or different LNGs can be pumped while effectively and easily utilizing the cold.
【００４５】さらに、ＢＯＧ再液化器を出た後のＬＮＧ
を昇圧する二次昇圧用のＬＮＧ圧送ポンプを設置するこ
とにより、ＢＯＧ再液化器における寒冷源としてのＬＮ
Ｇ圧送系統のＬＮＧ導入圧力を低くすることができるの
で、それに伴ってＬＮＧの導入温度も低く設定でき、Ｂ
ＯＧ再液化器の小型化が可能となる。Furthermore, LNG after leaving the BOG reliquefier
By installing an LNG pressure pump for secondary pressure boosting, the LN as a cold source in the BOG reliquefier is installed.
Since the LNG introduction pressure of the G pumping system can be lowered, the LNG introduction temperature can be set low accordingly.
The OG reliquefaction device can be downsized.
【００４６】また、本発明のＢＯＧ再液化方法によれ
ば、ＢＯＧの液化に際して寒冷源となるＬＮＧの液顕熱
のみを使用するようにしたり、ＬＮＧを臨界圧力以上に
高めたりすることにより、寒冷側のＬＮＧに沸騰が発生
しないのでＢＯＧを安定した状態で液化させることがで
き、温度変動及び熱応力発生を最少に抑えることができ
る。Further, according to the BOG reliquefaction method of the present invention, cold liquefaction can be achieved by using only liquid sensible heat of LNG as a cold source in liquefying BOG or by raising LNG to a critical pressure or higher. Since boiling does not occur in the LNG on the side, BOG can be liquefied in a stable state, and temperature fluctuation and thermal stress generation can be suppressed to a minimum.
【図１】 本発明のＬＮＧ貯槽のＢＯＧ再液化装置を適
用したＬＮＧ貯蔵・圧送設備の一例を示す系統図であ
る。FIG. 1 is a system diagram showing an example of LNG storage / pumping equipment to which a BOG reliquefaction device for an LNG storage tank of the present invention is applied.
【図２】 同じく他の形態例を示す系統図である。FIG. 2 is a system diagram showing another example of the embodiment.
【図３】 従来の液化天然ガス貯蔵・圧送設備の一例を
示す系統図である。FIG. 3 is a system diagram showing an example of a conventional liquefied natural gas storage / pumping facility.
１１，１１ａ，１１ｂ…ＬＮＧ貯槽、１２，１２ａ，１
２ｂ…ＬＮＧ送出系統、１３，１３ａ，１３ｂ…ＬＮＧ
圧送ポンプ、１４，１４ａ，１４ｂ…ＬＮＧ気化器、１
５，１５ａ，１５ｂ…ＮＧ圧送系統、１６，１６ａ，１
６ｂ…ＬＮＧ圧送系統、１７…ＢＯＧ圧縮機、１８，１
８ａ，１８ｂ…ＢＯＧ圧縮系統、１９，３１…ＢＯＧ再
液化器、１９ａ，３１ａ，３１ｂコイル、１９ｂ，３１
ｃ…シェル、２０…生成ＬＮＧ返送系統、２１…生成Ｌ
ＮＧポンプ、２２…生成ＬＮＧ圧送系統、２３…フレア
スタック、２４…ＢＯＧ放出系統11, 11a, 11b ... LNG storage tanks, 12, 12a, 1
2b ... LNG sending system, 13, 13a, 13b ... LNG
Pressure pump, 14, 14a, 14b ... LNG vaporizer, 1
5, 15a, 15b ... NG pumping system, 16, 16a, 1
6b ... LNG pumping system, 17 ... BOG compressor, 18,1
8a, 18b ... BOG compression system, 19, 31 ... BOG reliquefier, 19a, 31a, 31b coil, 19b, 31
c ... Shell, 20 ... Generation LNG return system, 21 ... Generation L
NG pump, 22 ... Generation LNG pumping system, 23 ... Flare stack, 24 ... BOG discharging system
Claims (8)
液化天然ガス貯槽の蒸発ガスを再液化する装置であっ
て、液化天然ガスを貯蔵する液化天然ガス貯槽と、該液
化天然ガス貯槽に貯蔵した液化天然ガスを所定圧力まで
昇圧した後に気化して送出する液化天然ガス圧送系統
と、前記液化天然ガス貯槽で発生した蒸発ガスを液化可
能な圧力まで圧縮する蒸発ガス圧縮系統と、前記液化天
然ガス圧送系統の液化天然ガスと前記蒸発ガス圧縮系統
で圧縮した蒸発ガスとを熱交換させ、蒸発ガスを液化し
て液化天然ガスを生成するシェルアンドコイル式の熱交
換器からなる蒸発ガス再液化器と、該蒸発ガス再液化器
で液化生成した液化天然ガスを前記液化天然ガス貯槽に
戻す生成液化天然ガス返送系統とを備えたことを特徴と
する液化天然ガス貯槽の蒸発ガス再液化装置。1. A device for reliquefying evaporated gas in a liquefied natural gas storage tank in a liquefied natural gas storage / pumping facility, the liquefied natural gas storage tank storing the liquefied natural gas, and the liquefied natural gas storage tank. Liquefied natural gas pressure feed system that vaporizes and delivers liquefied natural gas after pressurizing it to a predetermined pressure, evaporative gas compression system that compresses evaporative gas generated in the liquefied natural gas storage tank to a liquefiable pressure, and liquefied natural gas Evaporative gas reliquefier consisting of a shell-and-coil heat exchanger that heat-exchanges the liquefied natural gas of the pressure-feeding system and the evaporative gas compressed by the evaporative gas compression system to liquefy the evaporative gas to produce liquefied natural gas And a liquefied natural gas storage system for returning the liquefied natural gas liquefied and produced by the evaporative gas reliquefaction device to the liquefied natural gas storage tank. Evaporative gas reliquefaction device.
化液化天然ガスを、前記液化天然ガス圧送系統の前記蒸
発ガス再液化器の出口側に送出して合流させる生成液化
天然ガス圧送系統を設けたことを特徴とする請求項１記
載の液化天然ガス貯槽の蒸発ガス再液化装置。2. A product liquefied natural gas pressure feed system for sending the product liquefied liquefied natural gas liquefied by the evaporative gas reliquefaction unit to the outlet side of the evaporative gas reliquefaction unit of the liquefied natural gas pressure feed system for confluence. The evaporative gas reliquefaction apparatus for a liquefied natural gas storage tank according to claim 1, wherein the apparatus is provided.
液化天然ガス圧送系統の液化天然ガスを、シェル側に前
記蒸発ガス圧縮系統で圧縮した蒸発ガスを導入すること
を特徴とする請求項１又は２記載の液化天然ガス貯槽の
蒸発ガス再液化装置。3. The liquefied natural gas of the liquefied natural gas pumping system is introduced to the coil side of the evaporative gas reliquefaction unit, and the evaporative gas compressed by the evaporative gas compression system is introduced to the shell side. 1. An evaporative gas reliquefaction device for a liquefied natural gas storage tank according to 1 or 2.
の系統で構成するとともに、該複数のコイル側に、同一
又は異なる液化天然ガス圧送系統の液化天然ガス流体を
通すことを特徴とする請求項１乃至３のいずれかに記載
の液化天然ガス貯槽の蒸発ガス再液化装置。4. The evaporative gas reliquefier is configured with a plurality of coils on the coil side, and liquefied natural gas fluids of the same or different liquefied natural gas pressure feed systems are passed through the plurality of coils. An evaporative gas reliquefaction device for a liquefied natural gas storage tank according to any one of claims 1 to 3.
液化器入口側に、昇圧用の液化天然ガス圧送ポンプを設
けたことを特徴とする請求項１乃至４のいずれかに記載
の液化天然ガス貯槽の蒸発ガス再液化装置。5. The liquefied natural gas according to any one of claims 1 to 4, wherein a liquefied natural gas pressure pump for pressurization is provided on the inlet side of the evaporative gas reliquefier of the liquefied natural gas pressure feeding system. Evaporative gas reliquefaction device for gas storage tank.
液化器出口側に、二次昇圧用の液化天然ガス圧送ポンプ
を設けたことを特徴とする請求項１乃至５のいずれかに
記載の液化天然ガス貯槽の蒸発ガス再液化装置。6. A liquefied natural gas pressure feed pump for secondary pressurization is provided on the evaporative gas reliquefier outlet side of the liquefied natural gas pressure feed system, according to any one of claims 1 to 5. Evaporative gas reliquefaction equipment for liquefied natural gas storage tanks.
蒸発ガス再液化装置における蒸発ガスの液化方法であっ
て、前記蒸発ガス再液化器における液化寒冷源として、
液化天然ガス圧送系統の液化天然ガスの液顕熱のみを使
用することを特徴とする液化天然ガス貯槽の蒸発ガス再
液化方法。7. A method for liquefying an evaporative gas in an evaporative gas reliquefaction device according to claim 1, wherein the evaporative gas reliquefaction device has a liquefaction cold source
A method for reliquefying evaporated gas in a liquefied natural gas storage tank, which uses only sensible heat of liquefied natural gas in a liquefied natural gas pressure feed system.
然ガス圧送系統の液化天然ガスの圧力を、臨界圧力以上
に高めることを特徴とする請求項７記載の液化天然ガス
貯槽の蒸発ガス再液化方法。8. The liquefied natural gas storage tank according to claim 7, wherein the pressure of the liquefied natural gas in the liquefied natural gas pumping system to be introduced into the evaporative gas reliquefier is increased to a critical pressure or higher. Liquefaction method.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| JP34332195A JP3821506B2 (en) | 1995-12-28 | 1995-12-28 | Evaporative gas reliquefaction equipment for liquefied natural gas storage tanks |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| JP34332195A JP3821506B2 (en) | 1995-12-28 | 1995-12-28 | Evaporative gas reliquefaction equipment for liquefied natural gas storage tanks |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| JPH09183989A true JPH09183989A (en) | 1997-07-15 |
| JP3821506B2 JP3821506B2 (en) | 2006-09-13 |
Family
ID=18360624
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| JP34332195A Expired - Fee Related JP3821506B2 (en) | 1995-12-28 | 1995-12-28 | Evaporative gas reliquefaction equipment for liquefied natural gas storage tanks |
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Cited By (18)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| JP2008513550A (en) * | 2004-09-14 | 2008-05-01 | 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 for extracting ethane from liquefied natural gas |
| JP2009192004A (en) * | 2008-02-15 | 2009-08-27 | Ihi Corp | Liquefied gas vaporizing equipment |
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