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CN114688453B - Pressure-reducing and temperature-rising system and method for fuel gas system of LNG receiving station - Google Patents

Pressure-reducing and temperature-rising system and method for fuel gas system of LNG receiving station Download PDF

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Publication number
CN114688453B
CN114688453B CN202210421624.5A CN202210421624A CN114688453B CN 114688453 B CN114688453 B CN 114688453B CN 202210421624 A CN202210421624 A CN 202210421624A CN 114688453 B CN114688453 B CN 114688453B
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Prior art keywords
temperature
thermometer
flow
low
energy separation
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CN114688453A (en
Inventor
吕梦芸
安东雨
陈�峰
彭延建
陈锐莹
姜夏雪
王亚群
孙亚娟
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CNOOC Gas and Power Group Co Ltd
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CNOOC Gas and Power Group Co Ltd
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Classifications

    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • 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
    • 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
    • F17C13/00—Details of vessels or of the filling or discharging of vessels
    • F17C13/02—Special adaptations of indicating, measuring, or monitoring equipment
    • F17C13/025—Special adaptations of indicating, measuring, or monitoring equipment having the pressure as the parameter
    • 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
    • F17C13/026—Special adaptations of indicating, measuring, or monitoring equipment having the temperature as the parameter
    • 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
    • F17C13/04—Arrangement or mounting of valves
    • 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
    • F25B—REFRIGERATION MACHINES, PLANTS OR SYSTEMS; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS
    • F25B9/00—Compression machines, plants or systems, in which the refrigerant is air or other gas of low boiling point
    • F25B9/02—Compression machines, plants or systems, in which the refrigerant is air or other gas of low boiling point using Joule-Thompson effect; using vortex effect
    • F25B9/04—Compression machines, plants or systems, in which the refrigerant is air or other gas of low boiling point using Joule-Thompson effect; using vortex effect using vortex effect
    • 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
    • F25J1/02—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
    • F25J1/0228—Coupling of the liquefaction unit to other units or processes, so-called integrated processes
    • F25J1/0232—Coupling of the liquefaction unit to other units or processes, so-called integrated processes integration within a pressure letdown station of a high pressure pipeline system
    • 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
    • F17C2205/00—Vessel construction, in particular mounting arrangements, attachments or identifications means
    • F17C2205/03—Fluid connections, filters, valves, closure means or other attachments
    • F17C2205/0302—Fittings, valves, filters, or components in connection with the gas storage device
    • 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
    • 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
    • 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
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2227/00—Transfer of fluids, i.e. method or means for transferring the fluid; Heat exchange with the fluid
    • F17C2227/03—Heat exchange with the fluid
    • F17C2227/0367—Localisation of heat exchange
    • F17C2227/0388—Localisation of heat exchange separate
    • 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
    • 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
    • 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
    • F17C2250/0439—Temperature

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  • Engineering & Computer Science (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Physics & Mathematics (AREA)
  • Thermal Sciences (AREA)
  • Chemical & Material Sciences (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • General Chemical & Material Sciences (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Filling Or Discharging Of Gas Storage Vessels (AREA)

Abstract

The invention relates to a depressurization and heating system and a depressurization and heating method for a fuel gas system of an LNG receiving station, which are characterized by comprising an energy separation control system and a heat exchange system; the energy separation control system comprises an energy separation control system, a heat exchange system, a LNG receiving station, a low-pressure BOG compressor, a recondensor, a fuel gas system, a liquefied natural gas technology field, and the like.

Description

Pressure-reducing and temperature-rising system and method for fuel gas system of LNG receiving station
Technical Field
The invention relates to a depressurization and temperature rising system and method for a fuel gas system of an LNG receiving station, and belongs to the technical field of liquefied natural gas.
Background
Liquefied Natural Gas (LNG) receiving stations generally use high-pressure export natural gas as a supply source for a fuel gas system of the receiving station, and the pressure required by the fuel gas system is far lower than the export pressure, so that the high-pressure export natural gas needs to be throttled and depressurized. Because of the Joule-Thomson effect, low temperature appears after natural gas throttles and reduces pressure, and the fuel gas system can be provided with an air temperature type heater or an electric heater for heating throttled low-temperature fluid.
However, in the process of throttling and depressurization, energy waste is serious, the low temperature caused by the energy waste can be used as fuel gas supply after additional heat input compensation, the occupied area of the whole pressure regulating and temperature supplementing system is large, and the investment of the whole station yard is increased.
Disclosure of Invention
Aiming at the problems, the invention aims to provide a depressurization and temperature-rising system and method for a fuel gas system of an LNG receiving station, which can reduce the energy consumption in the whole depressurization and temperature-rising process.
In order to achieve the above purpose, the present invention adopts the following technical scheme: in one aspect, a depressurization and temperature elevation system for a fuel gas system of an LNG receiving station is provided, and the depressurization and temperature elevation system comprises an energy separation control system and a heat exchange system;
the inlet of the energy separation control system is connected with the output end of a natural gas pipeline of the LNG receiving station through a first cut-off valve, the hot end port of the energy separation control system is connected with a fuel gas supply system through a second cut-off valve, the cold end port of the energy separation control system is connected with the first inlet of the heat exchange system, the second inlet of the heat exchange system is connected with a BOG low-pressure compressor of the LNG receiving station, the first outlet of the heat exchange system is connected with a recondenser, and the second outlet of the heat exchange system is connected with the fuel gas supply system through the second cut-off valve;
the energy separation control system is used for carrying out energy separation on the input natural gas to obtain high-temperature fluid and low-temperature fluid, and carrying out flow regulation control on the high-temperature fluid at the hot end port so as to ensure that the temperature of the high-temperature fluid meets the temperature requirement of the downstream fuel gas;
the heat exchange system is used for adjusting the flow of the BOG output by the BOG low-pressure compressor, and exchanging heat between the low-temperature fluid at the cold port and the BOG from the BOG low-pressure compressor so that the temperature of the low-temperature fluid after heat exchange meets the temperature requirement of the downstream fuel gas.
Further, the heat exchange system is also used for automatically adjusting the temperature control of the electric heating load of the low-temperature fluid at the cold end opening so that the temperature of the output low-temperature fluid meets the temperature requirement of the downstream fuel air.
Further, the energy separation control system comprises a first flow regulating valve, a second flow regulating valve, a first gas turbine flowmeter, a second gas turbine flowmeter, a first pressure gauge, a second pressure gauge, a third pressure gauge, a first thermometer, a second thermometer, a third thermometer, a fourth thermometer, a vortex tube, a flow controller, a flow meter and an energy separation control and display;
the inlet of the first flow regulating valve is connected with the first cut-off valve, the outlet of the first flow regulating valve is connected with the inlet of the vortex tube sequentially through the first gas turbine flowmeter, the first pressure gauge and the first thermometer, the first gas turbine flowmeter is used for monitoring the input natural gas flow, the first pressure gauge and the first thermometer are used for monitoring the input natural gas pressure and temperature, and the vortex tube is used for carrying out energy separation on the input natural gas to obtain high-temperature fluid and low-temperature fluid;
the hot end port of the vortex tube is connected with a fuel gas supply system through the second pressure gauge, the second thermometer, the second gas turbine flowmeter, the second flow regulating valve, the third thermometer and the second cut-off valve in sequence, the second pressure gauge and the second thermometer are used for monitoring the pressure and the temperature of high-temperature fluid of the hot end port, the second gas turbine flowmeter is used for monitoring the flow of the high-temperature fluid of the hot end port, and the third thermometer is used for monitoring the temperature of the high-temperature fluid regulated by the second flow regulating valve;
the cold end opening of the vortex tube is connected with the first inlet of the heat exchange system through the third pressure gauge and the fourth thermometer, and the third pressure gauge and the fourth thermometer are used for monitoring the pressure and the temperature of the low-temperature fluid of the cold end opening;
the energy separation control and display are respectively and electrically connected with the second flow regulating valve, the first gas turbine flowmeter, the first pressure gauge, the second pressure gauge, the third pressure gauge, the first thermometer, the second thermometer, the third thermometer, the fourth thermometer, the flow controller and the flow meter, the flow meter is also electrically connected with the second gas turbine flowmeter, and the flow controller is also respectively and electrically connected with the first flow regulating valve.
Further, the energy separation control and the display are internally provided with:
the first parameter setting module is used for presetting the inlet flow of the vortex tube according to the requirement of the downstream fuel gas demand and presetting the output temperature of the high-temperature fluid according to the requirement of the downstream fuel gas temperature;
the first data acquisition module is used for acquiring data monitored by each pressure gauge, each thermometer and each flowmeter;
the first regulating valve control module is used for controlling the opening degree of the first flow regulating valve through the flow controller according to the preset inlet flow and the flow monitored by the first gas turbine flowmeter so that the flow of the output integral fluid meets the requirement of downstream fuel gas demand; controlling the opening degree of the second flow regulating valve according to the preset output temperature and the temperature monitored by the third thermometer so that the temperature of the output high-temperature fluid meets the temperature requirement of the downstream fuel air;
and the display module is used for displaying the separation effect of the vortex tube and the data monitored by each device in real time.
Further, the heat exchange system comprises a heat exchanger, a third flow regulating valve, an electric heating temperature compensator, a fifth thermometer, a sixth thermometer and a temperature controller;
the first inlet of the heat exchanger is connected with the cold end port of the energy separation control system, the second inlet of the heat exchanger is connected with the BOG low-pressure compressor of the LNG receiving station through the third flow regulating valve, and the heat exchanger is used for exchanging heat between low-temperature fluid at the cold end port of the energy separation control system and BOG of the BOG low-pressure compressor;
the BOG outlet of the heat exchanger is connected with the recondensor, the natural gas outlet of the heat exchanger is connected with a fuel gas supply system through the fifth thermometer, the electric heating temperature compensator and the sixth thermometer in sequence, the fifth thermometer is used for monitoring the temperature of the natural gas at the outlet of the heat exchanger, the sixth thermometer is used for monitoring the temperature of fluid at the outlet of the electric heating temperature compensator, and the electric heating temperature compensator is used for automatically adjusting the electric heating load of the gas after heat exchange according to the temperature monitored by the sixth thermometer and the requirement of the temperature of the downstream fuel gas;
the temperature controller is electrically connected with the third flow regulating valve and the fifth thermometer respectively.
Further, the temperature controller is internally provided with:
the second parameter setting module is used for presetting the output temperature of the low-temperature fluid according to the temperature requirement of the downstream fuel gas;
the second data acquisition module is used for acquiring the temperature monitored by the fifth thermometer;
and the second regulating valve control module is used for controlling the opening degree of the third flow regulating valve according to the preset output temperature and the temperature monitored by the fifth thermometer so that the temperature of the output low-temperature fluid meets the requirement of the temperature of the downstream fuel air.
In another aspect, a method for reducing and increasing temperature of a fuel gas system of an LNG receiving station is provided, including the following steps:
presetting an inlet flow of an energy separation control system according to a downstream fuel gas demand, presetting an output temperature of a high-temperature fluid according to a downstream fuel gas temperature demand, and presetting an output temperature of a low-temperature fluid according to a downstream fuel gas temperature demand;
the LNG receiving station outputs natural gas, the natural gas enters an energy separation control system through a first cut-off valve, and the energy separation control system performs energy separation on the high-pressure natural gas to obtain high-temperature fluid and low-temperature fluid;
the energy separation control system carries out flow regulation control on the high-temperature fluid at the hot end port according to preset inlet flow and output temperature and flow and temperature monitored in real time, so that the temperature of the high-temperature fluid meets the temperature requirement of the downstream fuel air;
the heat exchange system exchanges heat between the low-temperature fluid output by the energy separation control system and the BOG of the BOG low-pressure compressor, and adjusts the flow of the BOG to control the temperature of the low-temperature fluid after heat exchange, so that the temperature of the output low-temperature fluid meets the temperature requirement of the downstream fuel gas.
Further, the LNG receiving station outputs natural gas, and the natural gas enters an energy separation control system through a first cut-off valve, and the energy separation control system performs energy separation on the high-pressure natural gas to obtain a high-temperature fluid and a low-temperature fluid, including:
the LNG receiving station outputs natural gas and enters an energy separation control system through a first cut-off valve;
the first gas turbine flowmeter monitors the flow of the input natural gas in real time, and the first pressure gauge and the first thermometer monitor the pressure and the temperature of the input natural gas in real time;
the vortex tube performs energy separation on the input high-pressure natural gas to obtain a high-temperature fluid and a low-temperature fluid.
Further, the energy separation control system performs flow regulation control on the high-temperature fluid at the hot end port according to preset inlet flow and output temperature and flow and temperature monitored in real time, so that the temperature of the high-temperature fluid meets the temperature requirement of the downstream fuel air, and the energy separation control system comprises:
the energy separation control and display acquire data monitored by each pressure gauge, thermometer and flowmeter;
the energy separation control and display controls the opening degree of the first flow regulating valve through the flow controller according to the preset inlet flow and the flow monitored by the first gas turbine flowmeter, so that the flow of the output integral fluid meets the requirement of downstream fuel gas demand;
the energy separation control and display controls the opening of the second flow regulating valve through the flow controller according to the preset output temperature and the temperature monitored by the third thermometer, so that the temperature of the output high-temperature fluid meets the temperature requirement of the downstream fuel air.
Further, the heat exchange system exchanges heat between the low-temperature fluid output by the energy separation control system and the BOG of the BOG low-pressure compressor, and adjusts the flow of the BOG to control the temperature of the low-temperature fluid after heat exchange, so that the temperature of the output low-temperature fluid meets the temperature requirement of the downstream fuel gas, and the heat exchange system comprises:
the heat exchanger exchanges heat between the low-temperature fluid at the cold port of the energy separation control system and the BOG of the BOG low-pressure compressor, the cold energy of the fluid at the cold port is transferred to the BOG, and the BOG after heat exchange enters the recondensor;
the temperature controller controls the opening of the third flow regulating valve according to the downstream fuel air temperature requirement and the temperature monitored by the fifth thermometer so that the temperature of the output low-temperature fluid meets the downstream fuel air temperature requirement;
when the BOG of the LNG receiving station can supply enough heat, the electric heating temperature compensator does not work, and the low-temperature fluid after heat exchange is directly output; when the BOG of the LNG receiving station is insufficient in heat supply, the electric heating temperature compensator is started, and the electric heating load is automatically adjusted according to the temperature monitored by the sixth thermometer and the downstream fuel air temperature requirement, so that the low-temperature fluid temperature of the outlet meets the downstream fuel air temperature requirement.
Due to the adoption of the technical scheme, the invention has the following advantages:
1. the invention is provided with the energy separation control system and the heat exchange system, and can effectively utilize the energy in the process of reducing the pressure of the high-pressure external natural gas to the pressure required by the fuel gas by the energy separation effect of the vortex tube in the energy separation control system, directly obtain the high-temperature natural gas meeting the temperature requirement of the downstream fuel gas, and simultaneously obtain the cold port gas which is easier to exchange heat and raise the temperature.
2. According to the invention, for the separated low-temperature fluid of the cold port, the heat energy of the LNG receiving station is considered to be utilized, a high-temperature BOG heat exchange flow with the outlet of the BOG low-pressure compressor is set, the cold energy of the low-temperature fluid is transferred to the BOG to be recondensed, meanwhile, the temperature rise of the fluid of the cold port is completed, and the energy utilization rate of the whole LNG receiving station is improved.
3. The invention is provided with the electric heating temperature compensator for automatically adjusting the load at the downstream of the low-temperature fluid/BOG heat exchanger of the cold port, can cope with the working condition of insufficient BOG heat supply, ensures the stability of fuel gas supply and improves the applicability of the invention.
4. The invention can reduce the occupied area of the fuel gas system, is not limited by the ambient temperature, has wide application range and high energy utilization rate, and has higher economy.
In conclusion, the invention can be widely applied to the technical field of liquefied natural gas.
Drawings
Various other advantages and benefits will become apparent to those of ordinary skill in the art upon reading the following detailed description of the preferred embodiments. The drawings are only for purposes of illustrating the preferred embodiments and are not to be construed as limiting the invention. Like parts are designated with like reference numerals throughout the drawings. In the drawings:
fig. 1 is a schematic diagram of the system of the present invention.
Detailed Description
Exemplary embodiments of the present invention will be described in more detail below with reference to the accompanying drawings. While exemplary embodiments of the present invention are shown in the drawings, it should be understood that the present invention may be embodied in various forms and should not be limited to the embodiments set forth herein. Rather, these embodiments are provided so that this disclosure will be thorough and complete, and will fully convey the scope of the invention to those skilled in the art.
It is to be understood that the terminology used herein is for the purpose of describing particular example embodiments only, and is not intended to be limiting. As used herein, the singular forms "a", "an" and "the" are intended to include the plural forms as well, unless the context clearly indicates otherwise. The terms "comprises," "comprising," "includes," "including," and "having" are inclusive and therefore specify the presence of stated features, steps, operations, elements, and/or components, but do not preclude the presence or addition of one or more other features, steps, operations, elements, components, and/or groups thereof. The method steps, processes, and operations described herein are not to be construed as necessarily requiring their performance in the particular order described or illustrated, unless an order of performance is explicitly stated. It should also be appreciated that additional or alternative steps may be used.
Although the terms first, second, third, etc. may be used herein to describe various elements, components, regions, layers and/or sections, these elements, components, regions, layers and/or sections should not be limited by these terms. These terms may be only used to distinguish one element, component, region, layer or section from another region, layer or section. Terms such as "first," "second," and other numerical terms when used herein do not imply a sequence or order unless clearly indicated by the context. Thus, a first element, component, region, layer or section discussed below could be termed a second element, component, region, layer or section without departing from the teachings of the example embodiments.
For ease of description, spatially relative terms, such as "inner," "outer," "lower," "upper," and the like, may be used herein to describe one element or feature's relationship to another element or feature as illustrated in the figures. Such spatially relative terms are intended to encompass different orientations of the device in use or operation in addition to the orientation depicted in the figures.
The depressurization and temperature rising system and method for the fuel gas system of the LNG receiving station can realize depressurization and separation of high-pressure natural gas; the cold flow ratio is regulated by the energy separation control system, so that hot end port fluid capable of directly meeting the temperature requirement of downstream fuel gas is obtained; the cold end fluid also meets the requirement of the temperature of the downstream fuel gas by setting the heat exchange flow of a heat exchange system for exchanging heat with the BOG and automatically adjusting the load.
Example 1
As shown in fig. 1, the present embodiment provides a depressurization and heating system for a fuel gas system of an LNG receiving station, which includes an energy separation control system 1, a heat exchange system 2, and a connection system, wherein the connection system includes a first shut-off valve 3-1, a second shut-off valve 3-2, and connection pipes between each device and pipe.
The inlet of the energy separation control system 1 is connected with the output end of an external high-pressure natural gas pipeline of the LNG receiving station through a first cut-off valve 3-1, the hot end port of the energy separation control system 1 is connected with an external fuel gas supply system through a connecting pipeline through a second cut-off valve 3-2, the cold end port of the energy separation control system 1 is connected with the first inlet of the heat exchange system 2 through a connecting pipeline, the second inlet of the heat exchange system 2 is connected with a BOG (flash gas) low-pressure compressor of the LNG receiving station through a connecting pipeline, the first outlet of the heat exchange system 2 is connected with an external recondenser, and the second outlet of the heat exchange system 2 is connected with an external fuel gas supply system through a connecting pipeline through a second cut-off valve 3-2.
The energy separation control system 1 is used for carrying out energy separation on the input high-pressure natural gas to obtain high-temperature fluid and low-temperature fluid, and carrying out flow regulation control on the high-temperature fluid at the hot end port so as to ensure that the temperature of the high-temperature fluid meets the temperature requirement of the downstream fuel gas.
The heat exchange system 2 is used for adjusting the flow of the BOG output by the BOG low-pressure compressor, fully utilizing the heat energy of the BOG output by the BOG low-pressure compressor, and exchanging heat between the low-temperature fluid at the cold port and the BOG from the BOG low-pressure compressor so that the temperature of the low-temperature fluid after heat exchange meets the temperature requirement of the downstream fuel air.
The high temperature and the low temperature in the invention refer to the high temperature when the outlet temperature is higher than the inlet temperature, and the corresponding outlet is the hot end port; the outlet temperature is lower than the inlet temperature, and the corresponding outlet is the cold end.
In a preferred embodiment, the heat exchange system 2 is also used for automatically adjusting the temperature control of the electric heating load of the cold-end cryogenic fluid so that the temperature of the output cryogenic fluid meets the downstream fuel air temperature requirement.
In a preferred embodiment, the energy separation control system 1 includes a first flow regulating valve 1-1, a second flow regulating valve 1-2, a first gas turbine flow meter 1-3, a second gas turbine flow meter 1-4, a first pressure meter 1-5, a second pressure meter 1-6, a third pressure meter 1-7, a first temperature meter 1-8, a second temperature meter 1-9, a third temperature meter 1-10, a fourth temperature meter 1-11, a vortex tube 1-12, a flow controller 1-13, a flow meter 1-14, and an energy separation control and display 1-15.
The inlet of the first flow regulating valve 1-1 is connected with the first cut-off valve 3-1 through a connecting pipeline, the outlet of the first flow regulating valve 1-1 is connected with the inlet of the vortex tube 1-12 through the connecting pipeline sequentially through the first gas turbine flowmeter 1-3, the first pressure gauge 1-5 and the first thermometer 1-8, the first gas turbine flowmeter 1-3 is used for monitoring the flow of the input high-pressure natural gas, the first pressure gauge 1-5 and the first thermometer 1-8 are used for monitoring the pressure and the temperature of the input high-pressure natural gas, and the vortex tube 1-12 is used for carrying out energy separation on the input high-pressure natural gas to obtain high-temperature fluid and low-temperature fluid.
The heat port 1-12-1 of the vortex tube 1-12 is connected with an external fuel gas supply system through a connecting pipeline sequentially through a second pressure gauge 1-6, a second thermometer 1-9, a second gas turbine flowmeter 1-4, a second flow regulating valve 1-2, a third thermometer 1-10 and a second cut-off valve 3-2, the second pressure gauge 1-6 and the second thermometer 1-9 are used for monitoring the pressure and the temperature of high-temperature fluid of the heat port, the second gas turbine flowmeter 1-4 is used for monitoring the flow of the high-temperature fluid of the heat port 1-12-1, and the third thermometer 1-10 is used for monitoring the temperature of the high-temperature fluid regulated by the second flow regulating valve 1-2.
The cold port 1-12-2 of the vortex tube 1-12 is connected with the first inlet of the heat exchange system through a connecting pipeline by a third pressure gauge 1-7 and a fourth thermometer 1-11, and the third pressure gauge 1-7 and the fourth thermometer 1-11 are used for monitoring the pressure and the temperature of the low-temperature fluid of the cold port 1-12-2.
The energy separation control and display 1-15 are respectively and electrically connected with the second flow regulating valve 1-2, the first gas turbine flowmeter 1-3, the first pressure meter 1-5, the second pressure meter 1-6, the third pressure meter 1-7, the first thermometer 1-8, the second thermometer 1-9, the third thermometer 1-10, the fourth thermometer 1-11, the flow controller 1-13 and the flow meter 1-14, the flow meter 1-14 is also electrically connected with the second gas turbine flowmeter 1-4, the flow controller 1-13 is also electrically connected with the first flow regulating valve 1-1, the flow meter 1-14 is used for displaying the flow monitored by the second gas turbine flowmeter 1-4, the energy separation control and display 1-15 is used for controlling the opening degree of the second flow regulating valve 1-2 according to the downstream fuel gas temperature requirement, the flow monitored by the first gas turbine flowmeter 1-3, the second gas turbine flowmeter 1-4 and the temperature monitored by each thermometer, so that the temperature of the high-temperature fluid meets the downstream fuel gas temperature requirement, the flow controller 1-13 is also used for controlling the flow of the flow through the first gas turbine flowmeter 1-3 according to the downstream fuel gas temperature requirement.
In particular, the vortex tubes 1-12 may employ vortex chambers.
Specifically, a first parameter setting module, a first data acquisition module, a first regulating valve control module and a display module are arranged in the energy separation control and display 1-15. The first parameter setting module is used for presetting the inlet flow of the vortex tube according to the requirement of the downstream fuel gas demand and presetting the output temperature of the high-temperature fluid according to the requirement of the downstream fuel gas temperature. The first data acquisition module is used for acquiring data monitored by each pressure gauge, thermometer and flowmeter. The first regulating valve control module is used for controlling the opening degree of the first flow regulating valve 1-1 through the flow controller 1-13 according to the preset inlet flow and the flow monitored by the first gas turbine flowmeter 1-3 so that the flow of the output high-temperature fluid meets the requirement of the downstream fuel gas demand; and controlling the opening degree of the second flow regulating valve 1-2 according to the preset output temperature and the temperature monitored by the third thermometer 1-10 so as to ensure that the temperature of the output high-temperature fluid meets the temperature requirement of the downstream fuel air. The display module is used for displaying the separation effect of the vortex tubes 1-12 and the data monitored by each device in real time.
In a preferred embodiment, the heat exchange system 2 includes a heat exchanger 2-1, a third flow regulating valve 2-2, an electric thermostat 2-3, a fifth thermometer 2-4, a sixth thermometer 2-5, and a temperature controller 2-6.
The first inlet of the heat exchanger 2-1 is connected with the cold end port of the energy separation control system through a connecting pipeline, the second inlet of the heat exchanger 2-1 is connected with the BOG low-pressure compressor of the LNG receiving station through a connecting pipeline through a third flow regulating valve 2-2, and the heat exchanger 2-1 is used for exchanging heat between low-temperature fluid at the cold end port 1-12-2 of the energy separation control system and the BOG of the BOG low-pressure compressor.
The BOG outlet of the heat exchanger 2-1 is connected with an external recondensor, the natural gas outlet of the heat exchanger 2-1 is sequentially connected with an external fuel gas supply system through a fifth thermometer 2-4, an electric heating temperature compensator 2-3 and a sixth thermometer 2-5 through a second cut-off valve 3-2, the electric heating temperature compensator 2-3 is used for automatically adjusting electric heating load of natural gas subjected to heat exchange through the heat exchanger 2-1 according to the temperature monitored by the sixth thermometer 2-5 and the temperature requirement of downstream fuel gas, the fifth thermometer 2-4 is used for monitoring the temperature of fluid at the outlet of the heat exchanger 2-1, and the sixth thermometer 2-5 is used for monitoring the temperature of the fluid at the outlet of the electric heating temperature compensator 2-3.
The temperature controller 2-6 is respectively and electrically connected with the third flow regulating valve 2-2 and the fifth thermometer 2-4, and the temperature controller 2-6 is used for controlling the opening degree of the third flow regulating valve 2-2 according to the downstream fuel gas temperature requirement and the temperature monitored by the fifth thermometer 2-4 so that the fluid temperature after BOG heat exchange with the BOG low-pressure compressor meets the downstream fuel gas temperature requirement.
Specifically, a second parameter setting module, a second data acquisition module and a second regulating valve control module are arranged in the temperature controllers 2-6. The second parameter setting module is used for presetting the output temperature of the low-temperature fluid according to the downstream fuel air temperature requirement. The second data acquisition module is used for acquiring the temperature monitored by the fifth thermometer 2-4. The second regulating valve control module is used for controlling the opening degree of the third flow regulating valve 2-2 according to the preset output temperature and the temperature monitored by the fifth thermometer 2-4 so that the temperature of the output low-temperature fluid meets the temperature requirement of the downstream fuel air.
Specifically, the electric heating temperature compensator 2-3 automatically adjusts the electric heating load according to the temperature monitored by the sixth thermometer 2-5 and the downstream fuel temperature requirement, so that the temperature of the low-temperature fluid at the outlet meets the downstream fuel temperature requirement.
In a preferred embodiment, the data monitored by each device in the depressurization and temperature-raising system of the embodiment (i.e., all the pressure, flow and temperature monitoring data) can be directly connected to the DCS system (distributed control system) of the LNG receiving station, i.e., the operation state of the depressurization and temperature-raising system can be monitored from the DCS system.
Example 2
The embodiment provides a depressurization and temperature increase method for a fuel gas system of an LNG receiving station, which comprises the following steps:
1) The inlet flow of the energy separation control system is preset according to the downstream fuel gas demand, the output temperature of the high-temperature fluid is preset according to the downstream fuel gas temperature demand, and the output temperature of the low-temperature fluid is preset according to the downstream fuel gas temperature demand.
2) The LNG receiving station outputs high-pressure natural gas, the high-pressure natural gas enters the energy separation control system 1 through the first cut-off valve 3-1, and the energy separation control system 1 performs energy separation on the high-pressure natural gas to obtain high-temperature fluid and low-temperature fluid, specifically:
2.1 The LNG receiving station outputs high-pressure natural gas, which enters the energy separation control system 1 through the first shut-off valve 3-1.
2.2 The first gas turbine flowmeter 1-3 monitors the flow of the input high-pressure natural gas in real time, and the first pressure gauge 1-5 and the first thermometer 1-8 monitor the pressure and temperature of the input high-pressure natural gas in real time.
2.3 The vortex tube 1-12 performs energy separation on the input high-pressure natural gas to obtain high-temperature fluid and low-temperature fluid.
3) The energy separation control system 1 carries out flow regulation control on the high-temperature fluid at the hot end port according to preset inlet flow and output temperature and flow and temperature monitored in real time, so that the temperature of the high-temperature fluid meets the temperature requirement of downstream fuel air, and specifically comprises the following steps:
3.1 The energy separation control and displays 1-15 acquire data monitored by the pressure gauge, the thermometer and the flowmeter.
3.2 The energy separation control and display device 1-15 controls the opening degree of the first flow regulating valve 1-1 through the flow controller 1-13 according to the preset inlet flow and the flow monitored by the first gas turbine flowmeter 1-3, so that the flow of the output integral fluid meets the requirement of the downstream fuel gas demand.
3.3 The energy separation control and display 1-15 controls the opening of the second flow regulating valve 1-2 according to the preset output temperature and the temperature monitored by the third thermometer 1-10 so that the temperature of the output high-temperature fluid meets the temperature requirement of the downstream fuel air.
Specifically, depending on the vortex tube energy separation characteristics, the temperature of the high temperature fluid and the low temperature fluid are related to the inlet pressure P and the cold flow ratio E (the ratio of the cold end fluid mass flow to the inlet fluid total mass flow). When the inlet pressure P is fixed, the cold flow ratio is increased, so that the temperature rise (the difference between the outlet temperature of the hot end port and the inlet temperature) of the high-temperature fluid of the hot end port 1-12-1 is obvious, and the temperature drop (the difference between the inlet temperature and the outlet temperature of the cold end port) of the low-temperature fluid of the cold end port 1-12-2 is small; decreasing the cold flow ratio, and vice versa.
More specifically, when the temperature value monitored by the third thermometer 1-10 is lower than the downstream fuel gas temperature requirement, the energy separation control and display 1-15 adjusts the opening of the second flow regulating valve 1-2 to increase the cold flow ratio, so that the temperature of the high-temperature fluid of the hot port 1-12-1 is increased, thereby meeting the downstream fuel gas temperature requirement; when the temperature value monitored by the third thermometer 1-10 is higher than the downstream fuel gas temperature requirement, the energy separation control and display 1-15 regulates the opening of the second flow regulating valve 1-2.
4) The heat exchange system 2 exchanges heat between low-temperature fluid output by the energy separation control system and BOG output by the BOG low-pressure compressor, transfers cold energy of fluid at the cold port 1-12-2 to the BOG, and adjusts flow of the BOG to control temperature of the low-temperature fluid after heat exchange, so that the temperature of the output low-temperature fluid meets the temperature requirement of downstream fuel air, and specifically comprises the following steps:
4.1 The heat exchanger 2-1 exchanges heat between the low-temperature fluid of the cold port 1-12-2 and the BOG of the BOG low-pressure compressor, the cold energy of the fluid of the cold port 1-12-2 is transferred to the BOG, and the BOG after heat exchange enters the recondenser.
4.2 The temperature controller 2-6 controls the opening degree of the third flow rate adjustment valve 2-2 so that the temperature of the outputted low-temperature fluid satisfies the downstream fuel air temperature requirement, based on the downstream fuel air temperature requirement and the temperature monitored by the fifth thermometer 2-4.
Specifically, when the temperature monitored by the fifth thermometer 2-4 is lower than the output temperature required by the temperature of the downstream fuel gas, the opening degree of the third flow rate regulating valve 2-2 is adjusted to increase the BOG flow rate, so that the temperature of the outlet low-temperature fluid is increased; otherwise, the opening of the third flow regulating valve 2-2 is reduced, so that the temperature of the fluid at the outlet of the heat exchanger 2-1 meets the temperature requirement of the downstream fuel air.
4.3 Under the working condition that the BOG of the LNG receiving station can supply enough heat, the fluid at the cold port 1-12-2 can meet the temperature requirement of the downstream fuel gas through the heat exchanger 2-1, the electric heating temperature compensator 2-3 does not work, and the low-temperature fluid after heat exchange is directly output; when the BOG of the LNG receiving station is insufficient in heat supply, namely the temperature of the fluid at the outlet of the heat exchanger 2-1 does not meet the requirement on the temperature of the downstream fuel gas, the electric heating temperature compensator 2-3 is started, and the electric heating load is automatically adjusted according to the temperature monitored by the sixth thermometer 2-5 and the requirement on the temperature of the downstream fuel gas, so that the temperature of the low-temperature fluid at the outlet of the LNG receiving station meets the requirement on the temperature of the downstream fuel gas.
5) High temperature fluid and low temperature fluid meeting the downstream fuel gas temperature demand and the downstream fuel gas demand are supplied downstream.
The foregoing embodiments are only for illustrating the present invention, wherein the structures, connection modes, manufacturing processes, etc. of the components may be changed, and all equivalent changes and modifications performed on the basis of the technical solutions of the present invention should not be excluded from the protection scope of the present invention.

Claims (7)

1. The depressurization and heating system for the fuel gas system of the LNG receiving station is characterized by comprising an energy separation control system and a heat exchange system;
the inlet of the energy separation control system is connected with the output end of a natural gas pipeline of the LNG receiving station through a first cut-off valve, the hot end port of the energy separation control system is connected with a fuel gas supply system through a second cut-off valve, the cold end port of the energy separation control system is connected with the first inlet of the heat exchange system, the second inlet of the heat exchange system is connected with a BOG low-pressure compressor of the LNG receiving station, the first outlet of the heat exchange system is connected with a recondenser, and the second outlet of the heat exchange system is connected with the fuel gas supply system through the second cut-off valve;
the energy separation control system is used for carrying out energy separation on the input natural gas to obtain high-temperature fluid and low-temperature fluid, and carrying out flow regulation control on the high-temperature fluid at the hot end port so as to ensure that the temperature of the high-temperature fluid meets the temperature requirement of the downstream fuel gas;
the heat exchange system is used for adjusting the flow of the BOG output by the BOG low-pressure compressor, and exchanging heat between the low-temperature fluid at the cold port and the BOG from the BOG low-pressure compressor so that the temperature of the low-temperature fluid after heat exchange meets the temperature requirement of the downstream fuel gas; the heat exchange system is also used for automatically adjusting the temperature control of the electric heating load of the low-temperature fluid at the cold end opening so that the temperature of the output low-temperature fluid meets the temperature requirement of the downstream fuel gas;
the energy separation control system comprises a first flow regulating valve, a second flow regulating valve, a first gas turbine flowmeter, a second gas turbine flowmeter, a first pressure gauge, a second pressure gauge, a third pressure gauge, a first thermometer, a second thermometer, a third thermometer, a fourth thermometer, a vortex tube, a flow controller, a flow meter and an energy separation control and display;
the inlet of the first flow regulating valve is connected with the first cut-off valve, the outlet of the first flow regulating valve is connected with the inlet of the vortex tube sequentially through the first gas turbine flowmeter, the first pressure gauge and the first thermometer, the first gas turbine flowmeter is used for monitoring the input natural gas flow, the first pressure gauge and the first thermometer are used for monitoring the input natural gas pressure and temperature, and the vortex tube is used for carrying out energy separation on the input natural gas to obtain high-temperature fluid and low-temperature fluid;
the hot end port of the vortex tube is connected with a fuel gas supply system through the second pressure gauge, the second thermometer, the second gas turbine flowmeter, the second flow regulating valve, the third thermometer and the second cut-off valve in sequence, the second pressure gauge and the second thermometer are used for monitoring the pressure and the temperature of high-temperature fluid of the hot end port, the second gas turbine flowmeter is used for monitoring the flow of the high-temperature fluid of the hot end port, and the third thermometer is used for monitoring the temperature of the high-temperature fluid regulated by the second flow regulating valve;
the cold end opening of the vortex tube is connected with the first inlet of the heat exchange system through the third pressure gauge and the fourth thermometer, and the third pressure gauge and the fourth thermometer are used for monitoring the pressure and the temperature of the low-temperature fluid of the cold end opening;
the energy separation control and display are respectively and electrically connected with the second flow regulating valve, the first gas turbine flowmeter, the first pressure gauge, the second pressure gauge, the third pressure gauge, the first thermometer, the second thermometer, the third thermometer, the fourth thermometer, the flow controller and the flow gauge, the flow gauge is also electrically connected with the second gas turbine flowmeter, and the flow controller is also respectively and electrically connected with the first flow regulating valve;
the energy separation control and display are internally provided with:
the first parameter setting module is used for presetting the inlet flow of the vortex tube according to the requirement of the downstream fuel gas demand and presetting the output temperature of the high-temperature fluid according to the requirement of the downstream fuel gas temperature;
the first data acquisition module is used for acquiring data monitored by each pressure gauge, each thermometer and each flowmeter;
the first regulating valve control module is used for controlling the opening degree of the first flow regulating valve through the flow controller according to the preset inlet flow and the flow monitored by the first gas turbine flowmeter so that the flow of the output integral fluid meets the requirement of downstream fuel gas demand; controlling the opening degree of the second flow regulating valve according to the preset output temperature and the temperature monitored by the third thermometer so that the temperature of the output high-temperature fluid meets the temperature requirement of the downstream fuel air;
and the display module is used for displaying the separation effect of the vortex tube and the data monitored by each device in real time.
2. The depressurization and warm-up system for a fuel gas system of an LNG receiving station as recited in claim 1, wherein the heat exchange system comprises a heat exchanger, a third flow rate regulating valve, an electric temperature compensator, a fifth thermometer, a sixth thermometer and a temperature controller;
the first inlet of the heat exchanger is connected with the cold end port of the energy separation control system, the second inlet of the heat exchanger is connected with the BOG low-pressure compressor of the LNG receiving station through the third flow regulating valve, and the heat exchanger is used for exchanging heat between low-temperature fluid at the cold end port of the energy separation control system and BOG of the BOG low-pressure compressor;
the BOG outlet of the heat exchanger is connected with the recondensor, the natural gas outlet of the heat exchanger is connected with a fuel gas supply system through the fifth thermometer, the electric heating temperature compensator and the sixth thermometer in sequence, the fifth thermometer is used for monitoring the temperature of the natural gas at the outlet of the heat exchanger, the sixth thermometer is used for monitoring the temperature of fluid at the outlet of the electric heating temperature compensator, and the electric heating temperature compensator is used for automatically adjusting the electric heating load of the gas after heat exchange according to the temperature monitored by the sixth thermometer and the requirement of the temperature of the downstream fuel gas;
the temperature controller is electrically connected with the third flow regulating valve and the fifth thermometer respectively.
3. The depressurization and warm-up system for a fuel gas system of an LNG receiving station as defined in claim 2, wherein the temperature controller is provided therein with:
the second parameter setting module is used for presetting the output temperature of the low-temperature fluid according to the temperature requirement of the downstream fuel gas;
the second data acquisition module is used for acquiring the temperature monitored by the fifth thermometer;
and the second regulating valve control module is used for controlling the opening degree of the third flow regulating valve according to the preset output temperature and the temperature monitored by the fifth thermometer so that the temperature of the output low-temperature fluid meets the requirement of the temperature of the downstream fuel air.
4. A depressurization and warming method based on the depressurization and warming system for the fuel gas system of the LNG receiving station according to claim 3, characterized by comprising the following contents:
presetting an inlet flow of an energy separation control system according to a downstream fuel gas demand, presetting an output temperature of a high-temperature fluid according to a downstream fuel gas temperature demand, and presetting an output temperature of a low-temperature fluid according to a downstream fuel gas temperature demand;
the LNG receiving station outputs natural gas, the natural gas enters an energy separation control system through a first cut-off valve, and the energy separation control system performs energy separation on the high-pressure natural gas to obtain high-temperature fluid and low-temperature fluid;
the energy separation control system carries out flow regulation control on the high-temperature fluid at the hot end port according to preset inlet flow and output temperature and flow and temperature monitored in real time, so that the temperature of the high-temperature fluid meets the temperature requirement of the downstream fuel air;
the heat exchange system exchanges heat between the low-temperature fluid output by the energy separation control system and the BOG of the BOG low-pressure compressor, and adjusts the flow of the BOG to control the temperature of the low-temperature fluid after heat exchange, so that the temperature of the output low-temperature fluid meets the temperature requirement of the downstream fuel gas.
5. The depressurization and warming method for a depressurization and warming system of a fuel gas system of an LNG receiving station as set forth in claim 4, wherein the LNG receiving station outputs natural gas, the natural gas enters an energy separation control system through a first cut-off valve, and the energy separation control system performs energy separation on the high-pressure natural gas to obtain a high-temperature fluid and a low-temperature fluid, and the depressurization and warming method comprises the steps of:
the LNG receiving station outputs natural gas and enters an energy separation control system through a first cut-off valve;
the first gas turbine flowmeter monitors the flow of the input natural gas in real time, and the first pressure gauge and the first thermometer monitor the pressure and the temperature of the input natural gas in real time;
the vortex tube performs energy separation on the input high-pressure natural gas to obtain a high-temperature fluid and a low-temperature fluid.
6. The method for depressurization and warming of a depressurization and warming system of a fuel gas system of an LNG receiving station as set forth in claim 4, wherein the energy separation control system performs flow regulation control on the hot-side high-temperature fluid according to preset inlet flow and output temperature and flow and temperature monitored in real time so that the temperature of the high-temperature fluid meets the downstream fuel gas temperature requirement, comprising:
the energy separation control and display acquire data monitored by each pressure gauge, thermometer and flowmeter;
the energy separation control and display controls the opening degree of the first flow regulating valve through the flow controller according to the preset inlet flow and the flow monitored by the first gas turbine flowmeter, so that the flow of the output integral fluid meets the requirement of downstream fuel gas demand;
the energy separation control and display controls the opening of the second flow regulating valve through the flow controller according to the preset output temperature and the temperature monitored by the third thermometer, so that the temperature of the output high-temperature fluid meets the temperature requirement of the downstream fuel air.
7. The depressurization and warm-up method for a depressurization and warm-up system of a fuel gas system of an LNG receiving station of claim 4 wherein the heat exchange system exchanges heat between low temperature fluid output by the energy separation control system and BOG of the BOG low pressure compressor and adjusts the flow rate of the BOG to control the temperature of the exchanged low temperature fluid so that the temperature of the output low temperature fluid meets the downstream fuel air temperature requirement, comprising:
the heat exchanger exchanges heat between the low-temperature fluid at the cold port of the energy separation control system and the BOG of the BOG low-pressure compressor, the cold energy of the fluid at the cold port is transferred to the BOG, and the BOG after heat exchange enters the recondensor;
the temperature controller controls the opening of the third flow regulating valve according to the downstream fuel air temperature requirement and the temperature monitored by the fifth thermometer so that the temperature of the output low-temperature fluid meets the downstream fuel air temperature requirement;
when the BOG of the LNG receiving station can supply enough heat, the electric heating temperature compensator does not work, and the low-temperature fluid after heat exchange is directly output; when the BOG of the LNG receiving station is insufficient in heat supply, the electric heating temperature compensator is started, and the electric heating load is automatically adjusted according to the temperature monitored by the sixth thermometer and the downstream fuel air temperature requirement, so that the low-temperature fluid temperature of the outlet meets the downstream fuel air temperature requirement.
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