WO2020054068A1 - Procédé de fonctionnement d'un équipement de réception de gaz naturel liquéfié - Google Patents

Procédé de fonctionnement d'un équipement de réception de gaz naturel liquéfié Download PDF

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Publication number
WO2020054068A1
WO2020054068A1 PCT/JP2018/034255 JP2018034255W WO2020054068A1 WO 2020054068 A1 WO2020054068 A1 WO 2020054068A1 JP 2018034255 W JP2018034255 W JP 2018034255W WO 2020054068 A1 WO2020054068 A1 WO 2020054068A1
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Prior art keywords
natural gas
liquefied natural
gas
storage tank
period
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PCT/JP2018/034255
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English (en)
Japanese (ja)
Inventor
浩二郎 倉田
高橋　真二
篤志 神谷
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日揮グローバル株式会社
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Priority to PCT/JP2018/034255 priority Critical patent/WO2020054068A1/fr
Priority to JP2018560924A priority patent/JP6503521B1/ja
Priority to EP18933604.3A priority patent/EP3851730A4/fr
Priority to KR1020217005583A priority patent/KR20210058819A/ko
Publication of WO2020054068A1 publication Critical patent/WO2020054068A1/fr

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    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C9/00—Methods or apparatus for discharging liquefied or solidified gases from vessels not under pressure
    • F17C9/02—Methods or apparatus for discharging liquefied or solidified gases from vessels not under pressure with change of state, e.g. vaporisation
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C13/00—Details of vessels or of the filling or discharging of vessels
    • F17C13/02—Special adaptations of indicating, measuring, or monitoring equipment
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2221/00—Handled fluid, in particular type of fluid
    • F17C2221/03—Mixtures
    • F17C2221/032—Hydrocarbons
    • F17C2221/033—Methane, e.g. natural gas, CNG, LNG, GNL, GNC, PLNG
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2223/00—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel
    • F17C2223/01—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel characterised by the phase
    • F17C2223/0146—Two-phase
    • F17C2223/0153—Liquefied gas, e.g. LPG, GPL
    • F17C2223/0161—Liquefied gas, e.g. LPG, GPL cryogenic, e.g. LNG, GNL, PLNG
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2223/00—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel
    • F17C2223/03—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel characterised by the pressure level
    • F17C2223/033—Small pressure, e.g. for liquefied gas
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2225/00—Handled fluid after transfer, i.e. state of fluid after transfer from the vessel
    • F17C2225/01—Handled fluid after transfer, i.e. state of fluid after transfer from the vessel characterised by the phase
    • F17C2225/0107—Single phase
    • F17C2225/0123—Single phase gaseous, e.g. CNG, GNC
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2225/00—Handled fluid after transfer, i.e. state of fluid after transfer from the vessel
    • F17C2225/03—Handled fluid after transfer, i.e. state of fluid after transfer from the vessel characterised by the pressure level
    • F17C2225/035—High pressure, i.e. between 10 and 80 bars
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2227/00—Transfer of fluids, i.e. method or means for transferring the fluid; Heat exchange with the fluid
    • F17C2227/01—Propulsion of the fluid
    • F17C2227/0128—Propulsion of the fluid with pumps or compressors
    • F17C2227/0135—Pumps
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2227/00—Transfer of fluids, i.e. method or means for transferring the fluid; Heat exchange with the fluid
    • F17C2227/01—Propulsion of the fluid
    • F17C2227/0128—Propulsion of the fluid with pumps or compressors
    • F17C2227/0157—Compressors
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2227/00—Transfer of fluids, i.e. method or means for transferring the fluid; Heat exchange with the fluid
    • F17C2227/03—Heat exchange with the fluid
    • F17C2227/0302—Heat exchange with the fluid by heating
    • F17C2227/0309—Heat exchange with the fluid by heating using another fluid
    • F17C2227/0316—Water heating
    • F17C2227/0318—Water heating using seawater
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2250/00—Accessories; Control means; Indicating, measuring or monitoring of parameters
    • F17C2250/03—Control means
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2250/00—Accessories; Control means; Indicating, measuring or monitoring of parameters
    • F17C2250/04—Indicating or measuring of parameters as input values
    • F17C2250/0404—Parameters indicated or measured
    • F17C2250/043—Pressure
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2265/00—Effects achieved by gas storage or gas handling
    • F17C2265/03—Treating the boil-off
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2265/00—Effects achieved by gas storage or gas handling
    • F17C2265/03—Treating the boil-off
    • F17C2265/032—Treating the boil-off by recovery
    • F17C2265/037—Treating the boil-off by recovery with pressurising
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2265/00—Effects achieved by gas storage or gas handling
    • F17C2265/05—Regasification
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2265/00—Effects achieved by gas storage or gas handling
    • F17C2265/06—Fluid distribution
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2265/00—Effects achieved by gas storage or gas handling
    • F17C2265/06—Fluid distribution
    • F17C2265/068—Distribution pipeline networks
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2270/00—Applications
    • F17C2270/01—Applications for fluid transport or storage
    • F17C2270/0134—Applications for fluid transport or storage placed above the ground

Definitions

  • the present invention relates to a method of operating a liquefied natural gas receiving facility for receiving liquefied natural gas (Liquefied: LNG), storing it in a storage tank, vaporizing the LNG and shipping the product gas.
  • liquefied natural gas Liquefied: LNG
  • DR Demand Response
  • DR for reducing power demand
  • a customer who does not have a private power generation facility or a storage battery or has insufficient capacity has to reduce power demand.
  • a factory may need to perform production adjustment, and it is difficult to participate in the DR mechanism unless it is certain that the merits of performing DR will exceed the disadvantages caused by production adjustment.
  • Patent Literature 1 discloses a demand response system that outputs a power supply and demand adjustment command signal directly from a power company side to an electric device control device that controls the operation of electric devices on the consumer side and performs DR. Is described. However, it is difficult for an external power company to directly participate in a demand response system that directly controls the operation of an electric device for a customer who needs to perform operations such as ensuring safety when operating the electric device.
  • Patent Document 2 also discloses that BOG (Boil Off Gas: LNG) mixed with liquefied natural gas vaporized by a vaporizer by controlling the load of a BOG compressor in accordance with the required heat quantity of a gas consuming destination. A technique for adjusting the amount of LNG vaporized in the tank is described. On the other hand, Patent Document 2 does not describe a technique related to DR.
  • BOG Bit Off Gas: LNG
  • the present invention has been made under such a background, and provides a technology corresponding to demand response (DR) while maintaining stable operation of a liquefied natural gas receiving facility.
  • DR demand response
  • the method for operating the liquefied natural gas receiving facility of the present invention is a method for operating the liquefied natural gas receiving facility
  • the liquefied natural gas receiving facility is a storage tank for storing liquefied natural gas received from outside, a liquefied natural gas discharged from the storage tank is vaporized, and a vaporizer for shipping in a gas state
  • An electric motor-driven gas compressor for boosting the boil-off gas generated in the storage tank and mixing it with the natural gas vaporized by the vaporizer, Receiving a request for power consumption reduction including information related to the reduction period, or assuming that it is received, a study start step to start studying power consumption reduction, and the internal pressure of the storage tank when the gas compression unit is stopped
  • the change of the gas compression unit is predicted based on a comparison result between the reduction period and the stoppage period of the gas compression unit. And determining whether or not to stop the vehicle.
  • the method of operating the liquefied natural gas receiving facility may have the following features.
  • the vaporizer is a normal operation vaporizer for vaporizing liquefied natural gas using seawater supplied from a seawater pump driven by an electric motor, and a liquefied natural gas using the heat of combustion of the natural gas as a heat source.
  • the change in the internal pressure is determined based on a change in the gas phase volume caused by the discharge of the liquefied natural gas from the storage tank and a boil-off gas amount generated in the storage tank. To predict. The amount of boil-off gas generated in the storage tank is determined based on the amount of heat input to the storage tank.
  • a period during which the predicted value of the change in the internal pressure of the storage tank is less than the upper limit of the operating pressure provided in the storage tank is defined as the stoppable period.
  • a continuation determination step of making a determination that gives priority to continuing operation of the gas compression unit is included.
  • the method includes a pressure setting step and a pressure lowering step of reducing the internal pressure of the storage tank to the target pressure. After the pressure lowering step, the stop possibility determination step is performed again.
  • the present invention calculates a stoppable period of the gas compression unit for extracting boil-off gas from the liquefied natural gas storage tank, and determines whether to stop the gas compression unit based on the calculated result.
  • Demand response can be performed without hindering the response.
  • Fig. 1 shows an example of the relationship between participants in a DR transaction.
  • the power transmission and distribution companies 11 and the like include general power transmission and distribution companies such as regional power companies. If a DR contract is made to the power transmission and distribution company 11, a reward may be obtained, but if a request for DR from the power transmission and distribution company 11 cannot be met, a penalty may need to be paid.
  • the resource aggregator 12 adjusts the demand and supply of the DR collectively for the plurality of consumers 13 to distribute rewards and reduce the risk of penalty payment. Examples of the contents of the supply and demand adjustment include selection of a customer 13 that can respond to a DR request from the power transmission and distribution company 11 and assignment of a response period.
  • DR includes “up DR” for increasing power demand and “down DR” for reducing power demand.
  • up DR When the amount of power generated from renewable energy is large and the power demand needs to be increased, a request for an “up DR” is issued.
  • the power demand in the jurisdiction of the power transmission and distribution company 11 is tight, a request for “down DR” is issued.
  • the company of the LNG receiving facility 2 of this example constitutes one of the customers 13 among the participants of the above-mentioned DR transaction.
  • the power transmission and distribution company 11 requests the resource aggregator 12 for a “down DR” including information on the reduction amount and the reduction period (reduction request).
  • the resource aggregator 12 adjusts the supply and demand of the plurality of customers 13 (customers A, B, and LNG receiving facilities 2) in accordance with each reducible amount in order to reduce power consumption corresponding to the reduction request. .
  • the power transmission and distribution company 11 can obtain the effect of reducing the power load in response to the reduction request.
  • the LNG receiving facility 2 shown in FIG. 1 has a function of receiving and storing LNG from the outside, vaporizing the stored LNG, and shipping it to the demand destination 3.
  • This LNG receiving facility 2 has a facility configuration that can be applied to DR in comparison with a customer 13 such as a factory or the like that requires production adjustment when performing “down DR” (hereinafter referred to as “DR”).
  • DR down DR
  • the LNG receiving facility 2 includes an LNG tank 21 for storing LNG, LNG pumps 211 and 22 for delivering LNG from the LNG tank 21 to discharge gas to the demand destination 3, and an LNG vaporizing gas for vaporizing LNG. It is provided with a vaporizer (ORV 231 and SMV 232 to be described later) to be brought into a state, and a calorie adjusting unit 26 for adding a liquefied petroleum gas (LPG: Liquefied Petroleum Gas) to the vaporized gas to obtain a product gas.
  • LPG Liquefied Petroleum Gas
  • the LNG tank 21 is a storage tank that stores, for example, LNG received from the LNG tanker 4 in a liquid state cooled to about ⁇ 162 ° C., and its type (above-ground tank, underground tank, underground tank, etc.) and There is no particular limitation on the capacity.
  • FIG. 2 shows an example of a ground-type tank in which the upper surface of a cylindrical side wall is covered with a dome-shaped roof.
  • the LNG stored in the LNG tank 21 is sent to the vaporizers 231 and 232 via the LNG pump 211 provided in the LNG tank 21 and the delivery pump 22 for increasing pressure.
  • the LNG receiving facility 2 of this example includes an ORV (Open Rack Vaporizer) 231 that is a vaporizer that vaporizes LNG by using seawater (SW) supplied from a seawater pump (not shown) driven by an electric motor as a heat source.
  • An SMV (Submerged-combustion @ Vaporizer) 232 which is a vaporizer for vaporizing LNG using the heat of combustion of natural gas as a heat source, can be used by switching.
  • LNG is vaporized using the ORV 231 during normal operation, and the SMV 232 is in a standby state for emergency operation such as when a power failure occurs.
  • a plurality of ORVs 231 and SMVs 232 are provided.
  • an intermediate fluid such as propane or the like, which is heated using seawater, and an intermediate fluid such as IFV (Intermediate Fluid Vaporizer) that vaporizes LNG may be used as a vaporizer for normal operation.
  • Seawater is also supplied to the IFV using a seawater pump driven by an electric motor.
  • the calorie adjusting unit 26 mixes LPG for calorific value adjustment with the vaporized gas, and ships a product gas having a calorific value required by the customer 3.
  • LPG butane or propane
  • LPG tank 25 is sent to the calorie adjusting unit 26 in a liquid state via the LPG pump 251.
  • This LPG is vaporized by the heat adjusting unit 26 using a heat medium, and is mixed with the vaporized gas sent from the ORV 231 side to become a product gas.
  • the product gas whose heat amount has been adjusted by the heat amount adjusting unit 26 is delivered to the demand destination 3.
  • the LNG tank 21 for storing LNG, part of the LNG is vaporized due to heat input from the outside or the like, and BOG is generated.
  • the LNG tank 21 is connected to a BOG compressor 24 which is a gas compression unit for extracting BOG.
  • the BOG compressor 24 of this example is driven by an electric motor (not shown).
  • the BOG compressor 24 is, for example, a multi-stage BOG compressor having three compression stages as shown in FIG. 2, and is configured to reduce the BOG of about 12 to 22 kPaG (the suction side pressure of the first compression stage) to 2 to 22 kPaG. The pressure is increased to about 7.5 MPaG (pressure on the discharge side of the final compression stage).
  • the boosted BOG merges with the LNG vaporized by the vaporizer (ORV231 or SMV232), and is calorie-adjusted, and then delivered to the demand destination 3 as a product gas.
  • the power consumption of about several megawatts can be reduced by stopping the BOG compressor 24. Even if the BOG compressor 24 is stopped, the LNG pumps 211 and 22 are not affected, and the LNG supply can be continued. Further, by stopping the ORV 231, power consumption of about several hundred kilowatts can be reduced.
  • the ORV 231 is stopped, if the SMV 232 is operated, the LNG can be continuously vaporized. From these viewpoints, it can be said that the LNG receiving facility 2 is a customer 13 having an applicable facility configuration when participating in the DR transaction.
  • the LNG receiving facility 2 LNG is received from the LNG tanker 4 once to several times a month.
  • the amount of BOG generated in the LNG tank 21 increases to several times the normal time, for example, to about four times. It may be difficult to stop the BOG compressor 24 during a period in which a large amount of BOG occurs. Therefore, by predicting a change in the internal pressure of the LNG tank 21 when the BOG compressor 24 is stopped and specifying the period during which the BOG compressor 24 can be stopped, the DR operation can be performed without hindering the stable operation of the LNG receiving facility 2. It can be determined whether or not the operation can be performed.
  • the heat input to the LNG tank 21 from the outside is Qtank [J / h]
  • the heat input from the LNG pump 211 is Qpump [ J / h] and the amount of heat input from other equipment as Qetc [J / h]
  • the amount of BOG generated per unit time in the LNG tank 21 Wbog [kg / h] is expressed by the following equation (Equation 3). (Where ⁇ is the latent heat of vaporization of LNG [J / kg]).
  • the pressure in the LNG tank 21 at time t1 is p1 [kPaG]
  • the pressure at time t2 is p2 [kPaG]
  • the BOG densities at each pressure are ⁇ 1 and ⁇ 2 [kg / m 3 ], respectively.
  • the LNG tank 21 in the LNG tank 21 during the period is determined based on only the change in the liquid level of the LNG in the LNG tank 21 at each time of the liquid level t1 and t2. You can know the pressure change.
  • the calculation of the stop period using (Equation 5) is based on the pressure change in the LNG tank 21. It is done based on.
  • the LNG tank 24 is operated under the condition that the BOG compressor 24 is stopped. It is possible to specify a possible stop period (t2 ⁇ t1) for maintaining the pressure in the pressure 21 below the upper limit of the operating pressure. As described above, the change (L2-L1) in the liquid level of LNG during the stoppable period can be predicted from (Equation 1). In the LNG receiving facility 2 of the present example, it is possible to determine whether to perform the DR based on the calculation result of the stoppable period of the BOG compressor 24 described above.
  • the LNG receiving facility 2 operates the LNG pumps 211 and 22, the ORV 231, the BOG compressor 24, and the like during normal operation, and ships the product gas at the required heat quantity and flow rate to the demand destination 3 ( P11).
  • the operation data I12: the discharge flow rate F, the liquid level L1 of the LNG in the LNG tank 21, and the heat input Qtank
  • the external temperature and the amount of heat supplied from a heater are continuously obtained.
  • the LNG receiving facility 2 expects to receive a DR execution (reduction in power consumption) request based on a change in outside temperature, a power supply / demand forecast announced by the power transmission and distribution company 11, and the like. Examination of reduction can be started (examination start step). In this case, based on the acquired operation data and the prediction of the temperature change (prediction of Qtank), the equations (3, 5) are calculated and the pressure in the LNG tank 21 from the time when the DR is predicted to be performed is calculated. A change is predicted (P13). Then, the possible stop time of the BOG compressor 24 is calculated based on the pressure change (P14).
  • the above calculation may be performed offline by an operator using a computer, or may be automatically calculated using an operation management system of the LNG receiving facility 2 such as a DCS (Distributed Control System).
  • the prediction of the pressure change in the LNG tank 21 and the calculation of the stoppable time of the BOG compressor 24 correspond to the stoppable period calculation step of this example.
  • the number of currently operating ORVs 231 and SMV 232 and the power consumption of the seawater pump are calculated (P21).
  • the resource aggregator 12 When the transmission and distribution company 11 determines that the DR is required, the resource aggregator 12 notifies the resource aggregator 12 in advance of the reduction in power consumption (I01). In FIG. 3, the description of the resource aggregator 12 is omitted. This notification includes, for example, information on the DR implementation period (reduction period) and the requested power reduction.
  • the DR execution period is compared with the previously calculated stoppage period to determine whether the BOG compressor 24 can be stopped (P15: stoppage determination step). For example, when the period during which the BOG compressor 24 can be stopped is longer than the period during which DR is performed, it can be determined that the DR can be performed. Then, upon receiving a power consumption reduction request (I02) from the resource aggregator 12 after the advance notification, it is determined that the BOG compressor 24 is actually stopped (P16), and an operation stop operation is performed (P17: gas compression). Department stop process).
  • I02 power consumption reduction request
  • the power that can be further reduced is grasped (P22). Then, for example, after adjusting with the resource aggregator 12 to the effect that power consumption can be further reduced, when the power consumption reduction request (I02) is received, the vaporizer is switched from the ORV 231 to the SMV 232 (P23: vaporizer). Switching step).
  • an operation adjustment for reducing the pressure in the LNG tank 21 may be performed.
  • the contents of the operation adjustment include increasing the mixing ratio of BOG to the product gas to increase the amount of BOG extracted from the LNG tank 21 or requesting the demand destination 3 to increase the amount of the product gas received.
  • the LNG liquid level is decreased by increasing the LNG supply amount, and the like.
  • the operation is performed such that the target pressure becomes lower than the pressure of the LNG tank 21 at the time of making the determination.
  • the target pressure at the time of performing the adjustment is calculated (P31: target pressure setting step).
  • the target pressure is set to a target pressure at which the stoppage time of the BOG compressor 24 calculated by the above-described method is longer than the DR execution period.
  • the operation adjustment is performed (P33: pressure reduction step). Then, the internal pressure change of the LNG tank 21 is predicted (P13), the stoppage possible period of the BOG compressor 24 is calculated (P14), and the stoppage determination is performed again (P15). If the internal pressure of the LNG tank 21 has reached the target pressure due to the operation adjustment, it is possible to determine that the BOG compressor 24 can be stopped. Therefore, the resource aggregator 12 requests a reduction in power consumption (I02). In response to this, it is determined that the BOG compressor 24 should be stopped (P16), and an operation stop operation is executed (P17).
  • the operation adjustment described above may be performed.
  • the determination of whether or not the BOG compressor 24 can be stopped may be omitted, and a determination may be made that gives priority to continuing the operation of the BOG compressor 24 (continuation determination step).
  • the LNG tanker 4 is scheduled to receive LNG on Saturdays, Sundays, and public holidays, where it is unlikely that a request for DR will be issued. Overlapping periods may be avoided.
  • the stoppage period of the BOG compressor 24 for extracting BOG from the LNG tank 21 is calculated, and whether or not the BOG compressor 24 can be stopped is determined based on the calculated result. Therefore, the DR can be determined without hindering the stable operation of the LNG receiving facility 2. Can be implemented.
  • the prediction of the change in the internal pressure of the LNG tank 21 (P13) and the calculation of the period during which the BOG compressor 24 can be stopped (P14) are performed in advance.
  • the BOG compressor 24 is considered whether or not to stop in response to prior notification of the DR execution.
  • this study order may be changed as appropriate. For example, if there is a sufficient time from when the power consumption reduction request (I02) is received to when it is executed (the BOG compressor 24 is stopped), the internal pressure change of the LNG tank 21 is performed after the reduction request is received. May be calculated, the stoppage period of the BOG compressor 24 may be calculated (P13, 14: stoppage period calculation step), and the possibility of stoppage may be examined (P15: stoppage determination step).

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

Abstract

Le problème décrit par la présente invention est de fournir une technique de gestion d'une réponse à la demande tout en maintenant un fonctionnement stable d'un équipement de réception de gaz naturel liquéfié. La solution selon l'invention porte sur un équipement de réception de gaz naturel liquéfié (2) qui est pourvu d'un réservoir de stockage (21) pour stocker du gaz naturel liquéfié, d'un vaporisateur (231) pour vaporiser du gaz naturel liquéfié qui a été injecté à partir du réservoir de stockage et transporter ce dernier dans un état gazeux, et d'une unité de compression de gaz entraînée par un moteur électrique (24) pour mettre sous pression le gaz d'évaporation qui a été généré dans le réservoir de stockage (2) et mélanger ce dernier dans le gaz naturel vaporisé. Dans une étape de début d'examen, l'examen de la réduction de puissance consommée débute. Dans une étape de calcul de période d'arrêt potentielle, un changement de pression interne du réservoir de stockage (21) est prédit pour un cas où l'unité de compression de gaz (24) est arrêtée, et une période d'arrêt potentielle pour l'unité de compression de gaz (24) est calculée. Ensuite, dans une étape de détermination de faisabilité d'arrêt, la faisabilité d'arrêt de l'unité de compression de gaz (24) est déterminée sur la base d'un résultat de comparaison d'une période de réduction et de la période d'arrêt potentielle.
PCT/JP2018/034255 2018-09-14 2018-09-14 Procédé de fonctionnement d'un équipement de réception de gaz naturel liquéfié WO2020054068A1 (fr)

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PCT/JP2018/034255 WO2020054068A1 (fr) 2018-09-14 2018-09-14 Procédé de fonctionnement d'un équipement de réception de gaz naturel liquéfié
JP2018560924A JP6503521B1 (ja) 2018-09-14 2018-09-14 液化天然ガス受入設備の運転方法
EP18933604.3A EP3851730A4 (fr) 2018-09-14 2018-09-14 Procédé de fonctionnement d'un équipement de réception de gaz naturel liquéfié
KR1020217005583A KR20210058819A (ko) 2018-09-14 2018-09-14 액화천연가스 수입설비의 운전방법

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WO2024122403A1 (fr) * 2022-12-05 2024-06-13 三菱造船株式会社 Procédé de prédiction d'état de gaz liquéfié dans un réservoir, et système de prédiction d'état de gaz liquéfié dans un réservoir

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EP4322312A1 (fr) 2021-05-06 2024-02-14 LG Energy Solution, Ltd. Ensemble barre omnibus, bloc-batterie le comprenant et automobile

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JP2016177399A (ja) * 2015-03-19 2016-10-06 株式会社日立製作所 発電設備管理装置及び発電設備管理方法
JP2018112218A (ja) 2017-01-10 2018-07-19 株式会社Ihi Ｌｎｇ貯留設備のｂｏｇ圧縮機負荷制御装置

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JP2010246306A (ja) * 2009-04-08 2010-10-28 Ntt Facilities Inc 電力供給制御装置、電力供給制御方法および電力供給システム
JP2016177399A (ja) * 2015-03-19 2016-10-06 株式会社日立製作所 発電設備管理装置及び発電設備管理方法
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EP3851730A1 (fr) 2021-07-21
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KR20210058819A (ko) 2021-05-24
JP6503521B1 (ja) 2019-04-17

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