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WO2008017470A1 - Procédé et installation pour la vaporisation de gaz naturel liquéfié et pour la détente du gaz naturel - Google Patents

Procédé et installation pour la vaporisation de gaz naturel liquéfié et pour la détente du gaz naturel Download PDF

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Publication number
WO2008017470A1
WO2008017470A1 PCT/EP2007/007018 EP2007007018W WO2008017470A1 WO 2008017470 A1 WO2008017470 A1 WO 2008017470A1 EP 2007007018 W EP2007007018 W EP 2007007018W WO 2008017470 A1 WO2008017470 A1 WO 2008017470A1
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Prior art keywords
gas
pressure
heat
mpa
natural gas
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PCT/EP2007/007018
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German (de)
English (en)
Inventor
Hartmut Griepentrog
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Individual
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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
    • F17C5/00—Methods or apparatus for filling containers with liquefied, solidified, or compressed gases under pressures
    • F17C5/06—Methods or apparatus for filling containers with liquefied, solidified, or compressed gases under pressures for filling with compressed gases
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C9/00—Methods or apparatus for discharging liquefied or solidified gases from vessels not under pressure
    • F17C9/02—Methods or apparatus for discharging liquefied or solidified gases from vessels not under pressure with change of state, e.g. vaporisation
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • 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
    • F17C9/04—Recovery of thermal energy
    • 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
    • F17C2221/00—Handled fluid, in particular type of fluid
    • F17C2221/03—Mixtures
    • F17C2221/032—Hydrocarbons
    • F17C2221/035—Propane butane, e.g. LPG, GPL
    • 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
    • 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
    • F17C2223/00—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel
    • F17C2223/04—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel characterised by other properties of handled fluid before transfer
    • F17C2223/042—Localisation of the removal point
    • F17C2223/046—Localisation of the removal point in the liquid
    • 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
    • F17C2227/0171—Arrangement
    • F17C2227/0185—Arrangement comprising several pumps or 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
    • 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
    • F17C2227/0327—Heat exchange with the fluid by heating with recovery of heat
    • 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
    • F17C2227/0332—Heat exchange with the fluid by heating by burning a combustible
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2227/00—Transfer of fluids, i.e. method or means for transferring the fluid; Heat exchange with the fluid
    • F17C2227/03—Heat exchange with the fluid
    • F17C2227/0367—Localisation of heat exchange
    • F17C2227/0388—Localisation of heat exchange separate
    • F17C2227/0393—Localisation of heat exchange separate using a vaporiser
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2260/00—Purposes of gas storage and gas handling
    • F17C2260/03—Dealing with losses
    • F17C2260/035—Dealing with losses of 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
    • F17C2265/00—Effects achieved by gas storage or gas handling
    • F17C2265/05—Regasification
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2270/00—Applications
    • F17C2270/01—Applications for fluid transport or storage

Definitions

  • the present invention relates to a method for expanding gas, in particular natural gas, to a desired discharge pressure, in particular for a gas supply device and / or for evaporating liquid gas, in particular liquefied natural gas, and such systems.
  • Liquefied natural gas is supplied, for example, by tankers or in any other form.
  • a gas supply device such as a storage or a pipeline
  • the liquid gas For evaporation further energy expenditure is necessary.
  • US 3,367,258 Bl describes that there are basically two options if the gas is to be compressed to a certain pressure. In low pressure evaporation, the liquid gas is first vaporized and then compressed to the desired pressure. In high pressure evaporation, the liquid gas is compressed to the desired pressure - for example, in two stages to about 3.5 MPa or more - and then vaporized and heated to about 4 ° C. This probably corresponds to the discharge pressure or required pressure for other applications.
  • gas supply facilities which store or provide the gas in gaseous form and in particular serve the general gas supply, usually operate with a supply or gas pressure of about 8 MPa.
  • the discharge pressure at which the vaporized gas is delivered to a gas supply device corresponds to this supply pressure.
  • This storage pressure is then lowered for end users in several stages, in particular to a final discharge pressure of about 105 kPa.
  • Planning of the gas supply envisage storing the gas in caverns before discharge into a gas supply device in order to compensate for fluctuations in acceptance. For a significantly higher gas pressure of 27 MPa, for example, is provided.
  • the present invention has for its object to provide an improved method and an improved system for relaxing gas, especially natural gas, to a desired discharge pressure and / or evaporation of liquid gas, in particular liquefied natural gas, with a higher efficiency or energy utilization and / or an improved heat transfer is enabled or become.
  • a first aspect of the present invention is first to compress the gas to an elevated pressure which is well above the discharge pressure and / or at least 15 or 18 MPa.
  • the compaction is carried out by at least substantially isochoric heat.
  • the gas in the gaseous state in particular after evaporation or after removal from a store o. The like.
  • This compression is preferably isochoric by means of a corresponding heat exchanger.
  • the relaxation takes place on the opposite to the initial pressure optionally higher or lower discharge pressure, in particular mechanical energy is generated by means of an expansion machine. This allows a very energy-efficient release of the gas.
  • compression to the increased pressure may also be accomplished by a compressor or the like.
  • Another aspect of the present invention is to first compress the (liquid) gas to the elevated pressure, which is well above the discharge pressure and / or at least 15 or 18 MPa, and then evaporate by supplying heat. Due to the increased pressure - at least in the relevant temperature range from about 110 K to room temperature or above - in contrast to the usual lower pressures - in the (gas to be liquefied) a quasi-ideal gas behavior or an at least substantially constant specific heat capacity c p - specific heat capacity at constant pressure - reached. This allows a significant improvement in the supply of heat or the so-called heat exchange through a heat exchanger (heat exchanger) and accordingly allows a more effective use of energy.
  • heat exchanger heat exchanger
  • Another aspect of the present invention is to relax the vaporized and heated gas from the increased pressure back to the desired delivery pressure.
  • the relaxation by means of an expansion machine, z.
  • Example via a displacement machine, a turbine or a reciprocating engine, so that mechanical energy for operating a work machine, such as an electric generator, can be generated. This in turn allows optimized energy utilization.
  • the (to be liquefied) gas is not only compressed to the increased pressure, but also heated to a relation to the desired discharge temperature of, for example, about 275 to 280 K significantly elevated temperature and then during or by the relaxation so-.
  • the desired discharge temperature for example, about 275 to 280 K significantly elevated temperature and then during or by the relaxation so-.
  • Fig. 1 is a schematic view of a proposed system according to a first embodiment
  • Fig. 2 is a schematic enthalpy diagram of natural gas
  • FIG. 3 shows a schematic T-s diagram of a first method sequence
  • FIG. 4 is a schematic view of a proposed plant according to a second embodiment
  • FIG. 6 is a schematic T-s diagram of a third method sequence.
  • the present invention is particularly concerned with the vaporization of liquid gas, in particular liquefied natural gas.
  • liquid gas propane, butane or a mixture thereof
  • LPG Liquified Petrolium Gas
  • the present invention is alternatively or additionally concerned with the venting of gas, especially natural gas. However, this may also be other gas, in particular in the aforementioned sense or air act.
  • the system 1 shows, in a merely schematic, block diagram-like representation, a proposed system 1 for the evaporation of liquid natural gas according to a first embodiment.
  • the system 1 has a connection or inlet 2 or the like for receiving the liquid natural gas, not shown, for example, from a tanker, storage, or the like, not shown.
  • the pressure at the inlet 2 is for example about 1.1 MPa, the temperature for example about 1 13 K.
  • the liquid natural gas is compressed to an elevated pressure.
  • the system 1 preferably has at least one pump 3, optionally a further pump 4.
  • the compression or pumping or pressurization of the liquid natural gas takes place in the illustration example in one stage or, if necessary, in several stages.
  • the increased pressure of the natural gas is preferably at least 18 MPa, in particular at least 20 MPa, more preferably substantially 24 MPa or more, in the illustrated embodiment about 27 MPa.
  • the increased pressure is preferably more than 5 MPa, in particular more than 10 MPa, above a discharge pressure of the system 1 to a gas supply device G only, which is connected via a connection or outlet 5 to the system 1 and, for example, a non-illustrated Memory or a pipeline, not shown, may have for the evaporated natural gas.
  • a delivery with the final pressure to a gas supply device G of an end user can take place.
  • the increased pressure is preferably chosen such that the natural gas at the elevated pressure has an at least substantially independent of the temperature specific heat capacity c p . This applies at least for the relevant temperature range of, for example, 113 K to about 275 K or above.
  • the schematic diagram of Figure 2 illustrates schematically the dependence of the enthalpy H on the temperature T and the pressure p.
  • the x-axis shows the enthalpy increase H without a unit, since this is not about the absolute value, but only about relative values for illustration.
  • the y-axis shows the temperature in Kelvin.
  • the individual curves represent are different isobars whose values are given in the legend in MPa.
  • the derivative or slope of the enthalpy curves corresponds to the specific heat capacity, more precisely the specific heat capacity at constant pressure.
  • the curves represent the course at different pressures.
  • the enthalpy curve approaches a straight line only at the elevated pressure, that is, the specific heat capacity is at least substantially constant. Accordingly, the increased pressure should preferably be at least 15 MPa in order to achieve an at least substantially constant specific heat capacity of the natural gas.
  • the liquid natural gas is still liquid after compression or pressurization. Even if the temperature has slightly increased as a result and / or by other influences, for example, about 120 to 160 K.
  • the liquid natural gas is evaporated by supplying heat.
  • this is preferably carried out in a heat exchanger 6 located downstream of the pump 3 or 4.
  • the heat supply or the heat exchange and the evaporation preferably take place at substantially constant pressure (isobaric), ie at the elevated pressure of the initially still liquid natural gas.
  • the evaporation takes place in particular within the heat exchanger 6.
  • the initially still liquid natural gas can be compressed, for example, by the pumps 3, 4 to a pressure somewhat above the elevated pressure and / or the pressure of the natural gas in the heat exchanger 6 can vary somewhat due to the evaporation process.
  • the heat supply for heating and evaporation of the natural gas can generally be done in any way.
  • marine heat or a so-called immersion flame evaporator, open-rack evaporator or the like may be employed.
  • the "cold energy” may also be used, for example, in the chemical or food industry or the like.
  • the heat is supplied by a thermal power plant 7, for example with a turbine, as indicated in Figure 1.
  • a power plant 7 in the context of the present invention, in particular a gas turbine plant, steam turbine plant and / or combined gas and steam turbine plant or the like is to be understood.
  • a turbine system is used in particular for the generation of electrical and / or mechanical energy.
  • the turbine system can be operated with an open or closed circuit, wherein the medium for the heat transfer to the natural gas to be vaporized or to be heated can be liquid and / or gaseous.
  • the heat supply to evaporate the natural gas or the heat exchanger 6 leads particularly preferably to a cooling of said and / or other medium of the power plant 7, for example, intake air to a lowering of the condenser temperature of a combined cycle power plant or the like.
  • a cooling of said and / or other medium of the power plant 7 for example, intake air to a lowering of the condenser temperature of a combined cycle power plant or the like.
  • the potential or actual efficiency of the power plant 7 can thus be increased.
  • only a single heat exchanger 6 is provided to evaporate the still liquid natural gas and heated to a desired, in particular elevated temperature.
  • the evaporation and in particular also heating are thus preferably carried out in one stage.
  • this does not rule out that several heat exchangers 6 are connected in parallel or work to achieve a desired throughput. Even if several heat exchangers 6 are connected in series, the evaporation of the natural gas preferably takes place only in one, in particular in the first heat exchanger 6.
  • the vaporized natural gas - in particular directly in the heat exchanger 6 - to a relation to the discharge temperature at the terminal or outlet 5, for example, about 273 to 285 K increased temperature, preferably to more than 300 K, in particular more than 340 K, more preferably in substantial 360 K or more, heated.
  • the increased pressure results in a specific heat capacity of the natural gas which is essentially independent of the temperature or constant.
  • the heat is supplied by a warmer medium (in particular in the heat exchanger 6 and particularly preferably by the power plant 7), which preferably also has a substantially independent of the temperature or constant specific heat capacity and / or is preferably liquid.
  • the heat for evaporating the liquid natural gas is completely supplied or provided by the power plant 7.
  • the vaporized natural gas is then relieved of the increased pressure, in particular to the discharge pressure of preferably at most 22 or 10 MPa, in particular substantially 8 to 8.5 MPa or less, or even to the ultimate pressure of, for example, about 105 kPa.
  • the delivery pressure may be at least substantially equal to the output pressure - here, the liquid natural gas - above (which is often the case), below, or even equal to the final delivery pressure.
  • the expansion takes place in a single-stage or multi-stage expansion machine 8.
  • the expansion machine 8 has a displacement machine or reciprocating piston engine, preferably a turbine 9, in which the natural gas is supplied from the increased pressure. At least substantially relaxed to the discharge pressure.
  • the expansion machine 8 or turbine 9 drives a working machine, in this case a generator 10, to generate electricity, as indicated in FIG.
  • the expansion machine 8 or turbine 9 can alternatively or additionally also be used for other purposes, for example for generating mechanical energy.
  • the turbine 9 may also form part of the power plant 7 or be coupled or combined in any other way with this.
  • the gas cools, preferably to about or below 300 K, more preferably at least substantially to the desired discharge temperature.
  • the system 1 can be provided on the delivery side with a pressure control or regulation, which is not shown, or the like. This can also be done by appropriate control of the expansion machine 8 or turbine 9.
  • cooling and / or heating of the natural gas after relaxing to the desired discharge temperature - for example by means of an optional (further) heat exchanger 11, as indicated in Figure 1 - take place.
  • the natural gas is heated in the first heat exchanger 6, for example, only to a lower temperature and / or cooled in the expansion machine 8 below the discharge temperature.
  • the additional heat exchanger 11 can in turn be coupled to the power plant 7 or receive its heat from it.
  • the additional heat exchanger 11 can in turn be coupled to the power plant 7 or receive its heat from it.
  • other technical solutions are possible, as already generally addressed for the supply of heat for the evaporation of natural gas.
  • the power plant 7 can form part of the plant 1 or be designed as a separate plant or separately therefrom.
  • the proposed Appendix 1 allows a particularly efficient evaporation and / or good energy utilization. Bills have shown that in Combined with a gas turbine plant or the like a high efficiency and energy yield can be achieved.
  • the schematic Ts diagram according to FIG. 3 explains a preferred first workflow or method sequence in the illustration example.
  • the x-axis gives the specific entropy s in kJ • kg '1 • K ' 1 .
  • the y-axis indicates the temperature in K.
  • the lines represent isochores and isobars with different values according to the legend.
  • the compression can be effected in particular by means of the pump 3 and / or at least substantially adiabatically. The compression thus takes place in particular not along an Isochoren 12, even if this looks like in the illustration of FIG. 3, but z. B. along a polytropic.
  • state B the temperature of the still liquid gas has already increased somewhat, for example to about 120 to 130 K.
  • the first still liquid gas changes its state, in particular at least substantially along an isobaric 13 (ie while maintaining its pressure) until the state C is reached.
  • the initially still liquid gas is evaporated and is then in gaseous form with the increased pressure and the elevated temperature of, for example, about 360 K.
  • the transition from the liquid to the gaseous phase preferably takes place in a single step or in a single heat exchanger 6.
  • the heating from state B to state C can take place via other intermediate states and / or also in several stages.
  • state C the natural gas is completely vaporized and in particular heated to the elevated temperature of, for example, about 360K.
  • the natural gas is expanded, as indicated by arrow P2.
  • the natural gas can also be expanded in multiple stages with multi-stage intermediate heating, which can take place along an isobar and / or isochores, in order to keep the temperature in front of the expansion machine and a given discharge temperature low.
  • the system 1 has only optionally a pump 3 o. The like. In the second embodiment.
  • the plant 1 preferably has a second, downstream heat exchanger 6 'for supplying heat.
  • This heat supply can in principle be done in any way.
  • the heat is again supplied by a thermal power plant T, in particular a turbine, as indicated in FIG.
  • the further power plant 7 * can also be coupled to the first power plant 7 or formed by it.
  • the heating of the natural gas in the first heat exchanger 6 is preferably at least substantially at constant pressure, ie isobaric.
  • the transition from the liquid to the gaseous phase of the natural gas is preferably carried out in the first heat exchanger 6.
  • the second heat exchanger 6 1 is preferably designed such that an at least substantially isochronous heating, in particular therefore at least substantially at constant volume, of the natural gas takes place.
  • the compression is at least substantially isochoric for at least a portion of the pressure increase.
  • the T-s diagram according to FIG. 5 shows, by way of example, a second method sequence, which can be implemented, in particular, with the proposed system 1 according to the second embodiment.
  • the liquid natural gas in the first heat exchanger 6 at least substantially at constant pressure - namely at least substantially along Isobaric 13 - heated and evaporated.
  • a compression to a desired pressure for example 7 to 10 MPa or more, in particular by the optional pump 3, take place.
  • FIG. 5 shows the transition from state A to state B according to arrow Pia.
  • a heating to more than 200 K in particular substantially 210 K.
  • the heat can be at a pressure of for example about 7 to 10 MPa, in particular substantially 9 to 10 MPa.
  • a second heat supply takes place to further heat the already gaseous natural gas and to increase its pressure.
  • This heat is at least substantially isochoric - that is, at least substantially at constant volume - in the second heat exchanger 6 '.
  • the state of the gas changes from B to C according to arrow PIb.
  • the heating thus takes place at least substantially along the isochores 12 (line of constant density) in FIG. 5.
  • the second or at least substantially isochoric working heat exchanger 6 ' operates particularly preferably discontinuously so in so-called batch mode.
  • the natural gas to be heated is heated in batches at constant volume by supplying heat, whereby the pressure of the respective charge of the natural gas is increased accordingly. So can be done in a very efficient way at least substantially isochoric heating of the natural gas.
  • the particular isochoric heat supply or heating of the natural gas can, if necessary, also take place in a plurality of steps or stages, if appropriate with a plurality of second heat exchangers 6 'or in any other suitable manner. Also, an alternating heating and relaxing can be done several times.
  • the following procedure is possible. Starting from the initial state with, for example, about 113 K and a pressure of about 8.2 MPa, the liquid natural gas is first compressed, for example by means of the pump 3, to a pressure of, for example, about 9.54 MPa. In this case, the temperature may increase slightly, for example to about 113.8 K.
  • the temperature can be raised, for example, to about 280 K and the pressure increased to about 33.2 MPa.
  • first relaxation for example via a first expansion machine, such as the turbine 9.
  • first expansion machine such as the turbine 9.
  • the pressure is lowered, for example, to 8 MPa, the temperature of the gaseous natural gas thereby falling to about 241 K.
  • a further or second, at least substantially isochoric preheating for example, in a third heat exchanger, not shown - to eg 280 K and a pressure of about 1.15 MPa.
  • Fig. 6 shows in a very schematic Ts-diagram (the x-axis is to denote the specific entropy s, but units have been omitted) a third proposed procedure.
  • the proposed relaxation can be carried out in particular after a proposed liquefaction of the natural gas or after another liquefaction of the natural gas or independently.
  • the proposed relaxation of natural gas for example, can be used to the natural gas of the usual accumulator pressure of about 8.0 MPa as the initial pressure to the usual final discharge pressure of about 105 kPa as discharge pressure to relax.
  • the proposed relaxation can be carried out in particular with the system 1 (FIG. 4) without the first heat exchanger 6.
  • the relevant explanations therefore apply in particular in addition or correspondingly.
  • FIG. 6 illustrates that the natural gas to be expanded is heated isochorally, starting from state B (for example about 8 MPa or more and for example 275 to 300 K or less) at least substantially along the isochores 12, ie according to arrow Pl.
  • the heat supply to this preheating can in turn preferably be provided by the power plant 7 or 7 'or other means available.
  • the natural gas then preferably again has the increased pressure and the elevated temperature in the sense already mentioned.
  • the proposed relaxation can also take place in several stages and / or with alternating preheating and relaxation.
  • the proposed relaxation can be used in particular with the required reduction of the usual gas supply pressure of, for example, about 8 MPa to the usual final discharge pressure of for example about 105 kPa.
  • a corresponding power plant or turbine plant can be combined with the proposed plant 1 for relaxing.
  • Such a combination plant can then be used in particular locally or decentralized, for example, to relax natural gas from the usual storage or remote supply pressure to the final discharge pressure.
  • the pressure of the liquefied natural gas is brought to a level prior to entering the evaporator or heat exchanger, which ensures the most constant specific heat capacity at constant pressure during preheating to give a favorable evaporator or heat exchanger design with the same temperature difference between the evaporating natural gas and the heat-bonded or heat-introducing medium at the inlet and outlet as possible.
  • the relaxation of the natural gas can, as already mentioned, multi-stage, possibly with an intermediate heating, take place.
  • the liquid natural gas is preferably vaporized at said high pressures.
  • the term "evaporate” or “evaporate” is preferably to be understood in the present invention that at the lower pressure temperature the natural gas would be in gaseous form.
  • the proposed plants 1 and / or processes can be used not only for natural gas but also for other gases or purposes.
  • the proposed relaxation of gas by initially at least substantially isochoric preheating and subsequent relaxation in particular for gas pressure or air pressure storage can be used.
  • the proposed relaxation can be used in an air pressure storage power plant.
  • Such a power plant pumps in particular ambient air in underground caverns o. The like.
  • For energy storage When relaxing, the air, which is preferably under very high pressure, then drives in particular a generator or a sonic generator. stige work machine.
  • the proposed relaxation can be used for better energy utilization just in connection with such an air storage power plant or for other purposes.

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  • Engineering & Computer Science (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Engine Equipment That Uses Special Cycles (AREA)
  • Filling Or Discharging Of Gas Storage Vessels (AREA)

Abstract

L'invention concerne un procédé et une installation pour la vaporisation et/ou la détente de gaz naturel. Le gaz naturel est vaporisé à une pression supérieure à la pression de sortie dans un appareil d'échange de chaleur, et ensuite détendu au moyen d'une machine d'expansion. Cela permet un échange de chaleur particulièrement efficace et une exploitation optimisée de l'énergie. En variante ou en supplément, le gaz naturel est comprimé au-delà d'une pression de sortie de façon isochore par apport de chaleur, puis détendu pour la production d'énergie mécanique.
PCT/EP2007/007018 2006-08-08 2007-08-08 Procédé et installation pour la vaporisation de gaz naturel liquéfié et pour la détente du gaz naturel Ceased WO2008017470A1 (fr)

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DE102006046246A DE102006046246A1 (de) 2006-08-08 2006-09-28 Verfahren und Anlage zum Verdampfen von verflüssigtem Erdgas und Entspannen von Erdgas

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CN105156891A (zh) * 2015-08-27 2015-12-16 中国石油天然气股份有限公司 基于储气库的联产系统
RU2672232C2 (ru) * 2012-09-18 2018-11-12 Басф Се Способ и установка для получения энергии при снятии давления с технологического природного газа

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PL2264288T3 (pl) 2009-06-11 2012-01-31 Thermonetics Ltd Układ do sprawnego obniżania ciśnienia płynów
DE102010028803A1 (de) * 2010-05-10 2011-11-10 Siemens Aktiengesellschaft Anordnung und Verfahren zur autarken Energieversorgung von Messstationen für die Pipelineüberwachung sowie Verwendung der Anordnung in einer Pipeline
EP3591195A1 (fr) * 2018-07-05 2020-01-08 Siemens Aktiengesellschaft Processus de la turbine à gaz avancée à regazéification de gaz naturel

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RU2672232C2 (ru) * 2012-09-18 2018-11-12 Басф Се Способ и установка для получения энергии при снятии давления с технологического природного газа
CN105156891A (zh) * 2015-08-27 2015-12-16 中国石油天然气股份有限公司 基于储气库的联产系统

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