WO2016079485A1 - Système de récupération de chaleur résiduelle combiné à un stockage d'énergie à air comprimé - Google Patents

Système de récupération de chaleur résiduelle combiné à un stockage d'énergie à air comprimé Download PDF

Info

Publication number
WO2016079485A1
WO2016079485A1 PCT/GB2015/053465 GB2015053465W WO2016079485A1 WO 2016079485 A1 WO2016079485 A1 WO 2016079485A1 GB 2015053465 W GB2015053465 W GB 2015053465W WO 2016079485 A1 WO2016079485 A1 WO 2016079485A1
Authority
WO
WIPO (PCT)
Prior art keywords
compressed air
waste heat
energy storage
heat recovery
recovery
Prior art date
Application number
PCT/GB2015/053465
Other languages
English (en)
Inventor
Michael Coney
Karim WAZNI
Original Assignee
Demetair Systems Ltd
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Demetair Systems Ltd filed Critical Demetair Systems Ltd
Publication of WO2016079485A1 publication Critical patent/WO2016079485A1/fr

Links

Classifications

    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F02—COMBUSTION ENGINES; HOT-GAS OR COMBUSTION-PRODUCT ENGINE PLANTS
    • F02C—GAS-TURBINE PLANTS; AIR INTAKES FOR JET-PROPULSION PLANTS; CONTROLLING FUEL SUPPLY IN AIR-BREATHING JET-PROPULSION PLANTS
    • F02C6/00—Plural gas-turbine plants; Combinations of gas-turbine plants with other apparatus; Adaptations of gas-turbine plants for special use
    • F02C6/14—Gas-turbine plants having means for storing energy, e.g. for meeting peak loads
    • F02C6/16—Gas-turbine plants having means for storing energy, e.g. for meeting peak loads for storing compressed air
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F02—COMBUSTION ENGINES; HOT-GAS OR COMBUSTION-PRODUCT ENGINE PLANTS
    • F02C—GAS-TURBINE PLANTS; AIR INTAKES FOR JET-PROPULSION PLANTS; CONTROLLING FUEL SUPPLY IN AIR-BREATHING JET-PROPULSION PLANTS
    • F02C6/00—Plural gas-turbine plants; Combinations of gas-turbine plants with other apparatus; Adaptations of gas-turbine plants for special use
    • F02C6/04—Gas-turbine plants providing heated or pressurised working fluid for other apparatus, e.g. without mechanical power output
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F02—COMBUSTION ENGINES; HOT-GAS OR COMBUSTION-PRODUCT ENGINE PLANTS
    • F02C—GAS-TURBINE PLANTS; AIR INTAKES FOR JET-PROPULSION PLANTS; CONTROLLING FUEL SUPPLY IN AIR-BREATHING JET-PROPULSION PLANTS
    • F02C6/00—Plural gas-turbine plants; Combinations of gas-turbine plants with other apparatus; Adaptations of gas-turbine plants for special use
    • F02C6/18—Plural gas-turbine plants; Combinations of gas-turbine plants with other apparatus; Adaptations of gas-turbine plants for special use using the waste heat of gas-turbine plants outside the plants themselves, e.g. gas-turbine power heat plants
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F05—INDEXING SCHEMES RELATING TO ENGINES OR PUMPS IN VARIOUS SUBCLASSES OF CLASSES F01-F04
    • F05D—INDEXING SCHEME FOR ASPECTS RELATING TO NON-POSITIVE-DISPLACEMENT MACHINES OR ENGINES, GAS-TURBINES OR JET-PROPULSION PLANTS
    • F05D2260/00—Function
    • F05D2260/20—Heat transfer, e.g. cooling
    • F05D2260/211—Heat transfer, e.g. cooling by intercooling, e.g. during a compression cycle
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E60/00—Enabling technologies; Technologies with a potential or indirect contribution to GHG emissions mitigation
    • Y02E60/16—Mechanical energy storage, e.g. flywheels or pressurised fluids

Definitions

  • CAES compressed air energy storage
  • CAES compression and expansion without adding heat to the system.
  • Another type of CAES involves the quasi-isothermal compression of air using water sprays or liquid foam and heat rejection at low temperature. During energy recovery, the compressed air is expanded quasi-isothermally, again using water sprays or foam. We use the term isothermal CAES to describe this type of system.
  • any proposed CAES system has to meet certain demanding objectives.
  • One of these is to maximise the so-called round-trip efficiency which refers to the fraction of the stored energy which is actually recovered and turned back into useful electric energy when it is needed.
  • Another key objective is to minimise the total capital cost of the plant. In some systems it is the cost of air storage which is the dominant factor, in other systems it may be the cost of heat storage or the cost of the compressors, expanders, heat exchangers and other plant items. In some situations, the operating cost may be a very important factor, for example if the recovery of stored energy involves the burning of additional amounts of high grade fuel.
  • the requirement for energy storage is generally linked to a particular application, a particular location, a particular power and energy storage capacity and a particular response time. In some situations, a pure energy storage system with no additional fuel consumption may be appropriate. In other situations, the ability to produce more power than was originally stored is attractive, even though this requires consumption of fuel.
  • the field of interest relevant to the present invention is the application of compressed air energy storage to situations where waste heat is available at a temperature greater than 400°C, particularly where the waste heat is a sensible heat source such as in hot gases.
  • the source of waste heat could be the exhaust gases from a gas turbine, diesel engine or other combustion process. Alternatively the waste heat could come from various industrial processes, including those in which the source of waste heat is part of a closed circuit in which the gas is not released to the atmosphere.
  • the technical field of interest of the present invention also includes the use of an expansion system in which no fuel is burned in the air which is extracted from storage. Fuel may be burned in the process which generates the waste heat, but it is not burned in the heat recovery process.
  • the technical field of interest also includes the use of compressed air energy storage in combination with an organic Rankine cycle (ORC), or other boiling and condensing cycle suitable for the recovery of low temperature sensible heat.
  • ORC organic Rankine cycle
  • Organic Rankine cycles are particularly suited to the generation of electric power from low temperature sensible heat sources because, compared to water and steam, organic fluids generally have a lower critical temperature and pressure and their latent heat of evaporation is small relative to the required sensible heat input.
  • Steam/water on the other hand is best suited for situations of high heat source temperature or those in which the temperature of the heat source is low, but it does not drop much as heat is extracted. This is the case for example in a nuclear steam generator, where the heat source temperature is quite low at about 280°C, but it does not drop much lower than this.
  • the organic Rankine cycle is a well-established technology with a number of different suppliers and is generally the preferred method of recovering heat from sensible heat sources at temperatures below about 300°C. In the case of a sensible heat source, such as a combustion exhaust gas, the heat source temperature may fall to 100°C or lower as heat is extracted.
  • US patent number 8726629 by Coney describes a compressed air energy storage system in which an organic Rankine cycle may be used to recover low temperature heat after expansion.
  • the compressed air which is extracted from storage is expanded in one or more high pressure expanders before it is admitted to the combustion chamber of a modified gas turbine, in which the blading of the gas turbine has been removed.
  • the partially expanded compressed air is admitted to the combustion chamber at the same temperature and pressure as would apply in the unmodified gas turbine.
  • Fuel is burned in the compressed air and the combustion products are expanded through the turbine as in the unmodified gas turbine.
  • the combustion products then flow to one or more recuperators, which are used to preheat the compressed air.
  • the exhaust gases may be released to the atmosphere or they may be passed to an organic Rankine cycle if the exhaust temperature is sufficient to justify this.
  • US patent 8726629 describes an invention which involves the combustion of fuel in the compressed air taken from storage. It also requires the use of a modified gas turbine, and is therefore not applicable to the recovery of waste heat from an unmodified gas turbine or from some other source of waste heat such as a diesel engine or an industrial process. US patent 8726629 does not describe the use of an organic Rankine cycle in combination with the air compression system.
  • US patent number 6305158 by Nakhamkin describes a compressed air energy storage system which utilises the exhaust heat of a gas turbine to preheat the compressed air which is taken out of storage before it is injected into the combustion chamber of the same gas turbine in such a way that the added air supplements the flow from the gas turbine compressor. The injection of the additional air increases the output of the turbine without increasing the load on the gas turbine compressor.
  • US patent 6305158 does not describe the application of an organic Rankine cycle to recover part of the heat of
  • US patent 6305158 does not describe the use of a separate air expansion system. Furthermore, US patent 6305158 involves some modification to an existing gas turbine, since it requires the facility to inject compressed air into the gas turbine combustor. It is also clear that US patent 6305158 describes an invention which cannot be applied to other types of waste heat source.
  • a further type of compressed air energy storage system involves the quasi-isothermal compression of air by using water sprays or a liquid foam to cool the air during the actual compression process. Energy recovery is performed by a quasi-isothermal expansion using water sprays or a liquid foam to maintain the temperature. Although waste heat can be used in this case to heat the water sprays or liquid foam, the temperature of the water or foam is limited to much less than 400°C.
  • the present invention is a compressed air energy storage (CAES) scheme in which air is compressed to a high pressure by multistage intercooled compression, then stored at high pressure and near ambient temperature. There is no storage of the heat of compression. Instead, this heat is transferred by the intercoolers to an organic Rankine cycle (ORC), or other boiling/condensing cycle suitable for recovery of low temperature sensible heat.
  • ORC organic Rankine cycle
  • the ORC (or an equivalent cycle) generates power, partially offsetting the power consumption of the air compressors.
  • the stored compressed air is heated in heat exchangers by high temperature exhaust gas or other form of waste heat from an external source and then expanded in a multistage process of heating followed by expansion. Power is generated in each stage of the expansion. Following the last heating stage, the exhaust gases or other waste heat medium is still hot enough to be used in the same organic Rankine cycle, (or equivalent cycle) which is used in the compression process.
  • the number of expansion stages is not necessarily the same as the number of compression stages.
  • the temperature of the air after each compression stage may be about 220°C.
  • the power produced by the ORC serves to reduce the net work of compression.
  • the ORC power output may be used internally within the system to help to power the air compressors or it may be exported.
  • the compressed air which is extracted from the compressed air energy store is preferably preheated in a recuperator.
  • recuperator is the expanded air exiting from the last expansion stage.
  • the preheated air is heated by a gas turbine exhaust or other source of waste heat to a temperature of at least 400°C and preferably more than 500°C, which is much higher than the typical temperature of about 220°C of the air at the end of each compression stage.
  • the hot air is then expanded through a certain pressure range and then reheated and expanded again in each successive stage.
  • the system should preferably be designed so that the temperature of the thermal input to the organic Rankine cycle during expansion is close to the thermal input temperature during compression in order that the organic fluid is well-matched to the thermal input temperature in both cases. This can be achieved if the temperature of the air after each expansion stage is similar to the temperature of the air after each compression stage.
  • the air expansion system uses high temperature heat, which is at least 400°C at the hot end and preferably above 200°C at the cold end, this provides a substantial differential between the mean air expansion temperature and the mean air compression temperature.
  • This temperature differential combined with the application of the organic Rankine cycle under similar conditions both during the compression and during the expansion allows the system to produce significantly more electrical energy during the energy recovery phase than is consumed in the energy storage phase. In other words, the apparent round trip efficiency from an external point of view exceeds 100%.
  • the organic Rankine cycle is not very suitable for the utilisation of high temperature heat, because suitable organic fluids are not available.
  • the air compression and expansion cycle which may be termed a Brayton cycle, is inefficient at low temperatures, but is very suitable for the conversion of sensible heat at high temperatures.
  • the combination of the two sensible heat recovery systems is a very effective way of utilising the waste heat for the purpose of power generation and may be used as a form of combined cycle power generation without storing the compressed air.
  • the ability to store or consume compressed air allows the net power output or power input of the system to be controlled over a wide range.
  • the envisaged storage pressure for the proposed system may be about 200 bar, which is higher than is normally considered appropriate for an underground salt cavern.
  • Underground storage is still a possible option if for example the cavity is drilled out of rock and is at a sufficient depth which can support the high pressure.
  • the rock may need to be lined with a suitable liner in order to seal it.
  • the liner may be designed to take part of the pressure load with the surrounding rock also bearing part of the pressure load.
  • Above ground pressure vessels can be made from steel, but an alternative option may be to use composite pressure vessels.
  • the air compression and air expansion may be performed by turbo- machinery or by reciprocating compressor/expanders.
  • the reciprocating compressor/expanders may be modified commercial diesel engines. Alternatively other types of compressor/expander, such as screw machines, or rotary vane machines may be used. In the case of reciprocating compressors/expanders the same machines may be used for both compression and expansion, but with different valve timing in each case. However, if this is done then it would not be possible to run both the compression and the expansion at the same time.
  • the pressure of the air storage system may be maintained at a constant level by means of a hydraulic pump-turbine which pumps water at high pressure into the air storage system during the energy recovery phase and releases the water in the opposite direction through the pump-turbine during the energy storage phase.
  • An alternative embodiment of the invention is to use an air pressure store without a hydraulic pressure compensating system.
  • the pressure in the air storage system might be allowed to vary from a maximum of 200 bar down to about 50 bar, such that the system pressure varies by a factor of 4.
  • the pressures and temperatures though the system would vary with the storage pressure, which would adversely affect the performance.
  • the need for flexibility in the individual components can be reduced by reducing the variation in the system pressure.
  • the system pressure may be allowed to vary between 200 bar and 100 bar.
  • the disadvantage is that a significantly larger air storage volume is required for the same amount of stored energy.
  • the organic Rankine cycle would be designed so that it is used during energy storage, during energy recovery and when both the compression and the expansion system are running at the same time. However, under some circumstances it may be preferable for reasons of cost or simplicity to limit the operation of the organic Rankine cycle so that it does not operate to the fullest possible extent in all three of these scenarios.
  • the ORC could be sized so that it could recover all the heat of compression or all the residual heat of expansion but not all the available heat from both sources at the same time.
  • Figure 1 shows the preferred configuration of the system which is used during the energy storage phase when air is being compressed and stored.
  • Figure 2 shows the configuration used during the energy recovery phase when the air is released from storage and is heated and expanded. Many of the components are common to both diagrams.
  • atmospheric air at 1 is drawn into a first compressor stage 3 and compressed. This air exits from the compressor 3 and flows through pipe 4 to the intercooler 5, where it is cooled by a suitable heat transfer fluid.
  • the cooled air exits the intercooler 5 via pipe 6 and flows to another compressor 7, where it is further compressed.
  • the air exits the compressor 7 via pipe 8 and is cooled by the heat transfer fluid in intercooler 9 before flowing through pipe 10 to the third compressor stage 1 1 .
  • the air is compressed further in compressor 1 1 and then exits via pipe 12 to the third intercooler 13, where it is again cooled by the heat transfer fluid.
  • the compressed air exits the third intercooler via pipe 14 and flows to the last compressor stage 15.
  • the air exits the final compressor stage via pipe 16, then flows to an aftercooler 17, where is cooled again by the same heat transfer fluid.
  • the air typically enters each successive intercooler and the aftercooler at a temperature which may be in the range 200-280°C and exits each cooler at a temperature which may be near to 50°C. It is advantageous to cool the
  • the air entering cooler 19 may be cooled by a fan 20 blowing atmospheric air 21 , which exits the cooler at 22.
  • the cooler 19 may use water circulated from a river, lake or the sea, with or without a cooling tower.
  • FIG. 1 shows a constant pressure air storage system in which water flows into or out of vessel 27 by means of a hydraulic pump-turbine 30. During the storage phase which is shown in Figure 1 ,
  • compressed air flows into 27 and water flows out via pipe 29 to the pump-turbine 30. This generates some power which to some extent offsets the power consumption of the air compressors.
  • the heat transfer fluid which circulates through the intercoolers 5, 9, 13 and the aftercooler 17 may be a commercial thermic oil such as Dowtherm A.
  • This particular heat transfer fluid may be operated at temperatures up to 257°C in an unpressurised system.
  • the maximum operating temperature of Dowtherm A is about 400°C, but the pressure needs to be maintained above 1 1 bar abs to prevent boiling. In the present application, it should not be necessary to
  • pressurise Dowtherm A if this is used as the heat transfer fluid.
  • water may be used as the heat transfer fluid, but in this case, the water would certainly have to be pressurised to prevent boiling.
  • FIG. 1 shows a pump 31 which circulates the heat transfer fluid via a pipe 32 and a manifold 53.
  • the heat transfer fluid flows from the manifold 53 in parallel paths 33, 34, 35 and 36 to each intercooler 13, 9, 5 and the aftercooler 17. After passing through the intercoolers and the aftercooler, the heat transfer fluid flows to an outlet manifold 41 via pipes 37, 38, 39 and 40. Then the heat transfer fluid flows via pipe 42 to the boiler 43, which evaporates the organic working fluid of the organic Rankine cycle 87. After giving up its heat, the heat transfer fluid exits the boiler 43 via pipe 44 and returns to the circulating pump 31 .
  • An alternative to using an intermediate heat transfer fluid is to use pump 52 to pump the organic working fluid through the intercoolers 5, 9 and 13 and through the aftercooler 17 which would be connected in parallel. In this case there would be no need for the boiler 33 or the pump 31 , since the intercoolers and aftercooler would generate the organic vapour which would pass direct to the organic turbine.
  • the application of organic Rankine cycles both with and without an intermediate heat transfer fluid is well-known. The question of whether or not to use an intermediate heat transfer fluid is determined by considerations of safety, cost, controllability, reliability and maintenance.
  • the organic working fluid may be a hydrocarbon such as butane or isopentane or it may be a refrigerant, which is chosen so that it meets the regulatory requirements concerning the depletion of ozone in the atmosphere.
  • the choice of working fluid depends on the intended working temperatures of the cycle.
  • the organic working fluid is circulated by means of pump 52, which supplies condensed liquid to the boiler 43 via pipe 45.
  • the organic fluid is completely evaporated in the boiler so that dry organic vapour flows via pipe 46 to the organic turbine 47, which drives a generator 48.
  • organic fluids do not become wet after expansion in a turbine, so dry organic vapour exits the turbine 47 via pipe 49 and flows to the condenser 50.
  • the condenser is cooled by external cooling means, which may use river or sea water or it may use atmospheric air as the coolant.
  • the organic vapour is condensed to liquid and returns to the circulating pump 52 via pipe 51 .
  • the organic Rankine cycle 87 may include a regenerator (not shown) which transfers heat from the vapour flowing in pipe 49 to the condensed liquid flowing in pipe 45, but this may not be advantageous in the present application.
  • the hydraulic pump-turbine 30 may be used as a fast response system to modify the input or output of the energy storage system as a short-term
  • the hydraulic pump-turbine could be adjusted to run at a lower or higher flow rate or it could be stopped altogether. Over a longer period of time the pressure of the air reservoir may drift from its normal setting, but the fast response of the hydraulic pump-turbine could give valuable time for other generating plant to be run up or run down as necessary. The drift of pressure in the air storage system can then be corrected.
  • the power generated in the ORC and the power generated by the constant pressure system each amount to about 10% of the compression power. Thus there is total power generated which is about 20% of the
  • compression power The power generated by the ORC and by the hydraulic pumping system during compression may be exported or it may be used internally within the air compression system.
  • the ORC power and the hydraulic pump-turbine power could be used to power part of the
  • the hydraulic system consumes or generates power in opposition to the air storage system, which means that the power rating and performance of the overall system at a fixed pressure condition is degraded relative to that which could be obtained without such a hydraulic system. Without the hydraulic system however, it is not possible to realize a system that could operate continuously at a fixed pressure, unless the air storage volume was effectively infinite, or the air was stored deep underwater at a fixed hydrostatic pressure. In practice the pressure of a finite air storage volume would probably vary over a wide range, for example from a maximum of 200 bar down to about 50 bar.
  • the energy recovery system is shown diagrammatically in Figure 2. Some of the components are used for both the energy storage and for energy recovery, in which case they appear both in Figure 1 and in Figure 2.
  • the main items in common in both diagrams are the air storage system, which includes the constant pressure system, and the organic Rankine cycle 87, including the organic boiler 43 and the circulating pump 31 for the heat transfer fluid.
  • compressors 3,7,1 1 ,15 and expanders 73,76,79 may be possible to use some or all of these for both purposes, but they are shown as separate components in the figures.
  • Figure 2 shows an unmodified gas turbine 88 consisting of a compressor 61 , gas turbine combustor 62 and turbine 63.
  • the gas turbine 88 drives a generator 60.
  • the gas turbine and generator may be pre-existing, such that the proposed CAES system is a retrofit.
  • the CAES system could be a retrofit to another existing source of waste heat.
  • FIG. 2 shows a heat recovery heat exchanger which consists of two parts 64 and 65.
  • the gas turbine exhaust gas 89 at the highest available temperature is used in a gas-to-air heat exchanger 64, which consists of a number of parallel flow paths, corresponding to the number of expansion stages in the air expansion system.
  • Figure 2 shows three
  • the second part 65 of the heat recovery heat exchanger is a gas-to-liquid heat exchanger which supplies heat to the organic Rankine cycle 87 via the same heat transfer fluid which was used in
  • compressed air is taken from the storage vessel 27, which is maintained at constant pressure by pumping water from the low pressure reservoir 28 into the high pressure air storage vessel by means of the hydraulic pump-turbine 30.
  • the compressed air flows via pipes 26 and 69 to the air-to-air recuperator 70.
  • Condensed water which was stored in vessel 25 during the compression phase may be re-injected into the compressed air by means of a small pump 84 so that it also flows along pipe 69 to the air-to-air recuperator 70. If sufficient waste heat is available, additional water may be injected into vessel 25 to increase the thermal capacity of the air during the expansion process and thereby increase the power output.
  • the compressed air with some liquid water is pre-heated in recuperator 70 using fully expanded air which may be at a temperature of about 250°C.
  • the compressed air then flows via pipe 71 to the high pressure air tubing of heat exchanger 64 and is heated to near the maximum available temperature of the waste heat.
  • the hot compressed air then flows via pipe 72 to the high pressure expander 73 and is expanded to a lower pressure and temperature of about 250°C. After the high pressure expansion the air exits the high pressure expander 73 via pipe 74 and re-enters the heat exchanger 64, passing through a set of tubing designed for an intermediate pressure.
  • the air is re-heated to the maximum available temperature and exits the heat exchanger 64 via pipe 75.
  • the reheated air is then expanded in the expander 76 and exits via pipe 77.
  • the air is then reheated again to the maximum available temperature in another set of heat exchanger tubing and then flows via pipe 78 to the last expander 79.
  • Finally the expanded air flows to the air-to-air recuperator 70 via pipe 81 and from there the cooled low pressure air escapes to the atmosphere via duct 82.
  • the air expanders 73, 76 and 79 drive a generator 80.
  • This generator could be a motor-generator which can operate both as the motor 2 shown in Figure 1 and as the generator 80 shown in Figure 2.
  • the operation of the organic Rankine cycle 87 is essentially the same as described in connection with the energy storage phase.
  • the main difference is that in this case the heat transfer liquid is circulated through the gas-to-liquid heat exchanger 65 shown in Figure 2, instead of through the intercoolers and aftercooler shown in Figure 1 . It is possible to do without a heat transfer fluid for the purpose of heat recovery.
  • pump 52 would pump the organic fluid directly through the heat exchanger 65, where it would be evaporated. The organic vapour would then be sent directly to the organic turbine 47 and there would be no need for either the pump 31 or the boiler 43.
  • the optimum design of the various components depends on the nature of the waste heat source, in particular the mass flow rate and the temperature.
  • the temperature may affect the optimum number of stages in the compressed air expansion and the choice of working fluid in the organic Rankine cycle.
  • the mass flow rate clearly affects the size of the compressed air system and that of the organic Rankine cycle.
  • the number of air expansion stages may not be the same as the number of compression stages. In expansion, the available waste heat from the gas turbine or other source is shared fairly equally between the different expansion stages.
  • the thermal capacity of the air is similar to that of gas turbine exhaust gas. The exhaust gas flows in parallel paths through the different stages, while the air flow path is in series. Thus if there are more expansion stages, then a smaller air flow is required to match the available waste heat.
  • the air flow rate during expansion is 1 /3 rd or 1/4 th of the exhaust gas flow rate.
  • the air flow during the compression phase is not constrained so it can be chosen to match the expansion air flow or not, depending on the planned utilisation of the CAES system.
  • the numbers of air compression and expansion stages and the magnitude of air mass flow in compression relative to that in expansion does have an impact on the design of the organic Rankine cycle.
  • the proposed system can also be operated as a heat recovery system without storing or recovering compressed air, as illustrated in Figure 3.
  • Figure 3 shows the compression system, which is the same as shown in Figure 1 .
  • the air storage system and air cooler, which appear in Figure 1 are not shown in Figure 3 since they are not used in this situation.
  • Figure 3 includes the air expansion system and the organic Rankine cycle 87, which are also shown in Figure 2. Consistent numbering of the components is used between Figures 1 , 2 and 3 in order to assist the description.
  • Figure 3 also shows a pipe 86 which supplies compressed air directly from the aftercooler 17 of the compression system to the recuperator 70 of the air expansion system.
  • FIG. 3 also shows that the pump 31 supplies heat transfer fluid both to the manifold 53 of the air compression system via pipe 32 and to the low temperature heat recovery heat exchanger 65 via pipe 66.
  • the two flows operate in parallel.
  • the hot heat transfer fluid returns from the outlet manifold 41 of the air compression system via pipe 42 and from the low temperature heat recovery heat exchanger via pipe 67.
  • the organic Rankine cycle 87 For the purpose of operating purely as a heat recovery system without storing or extracting compressed air, it is desirable to size the organic Rankine cycle 87 so that it can operate with both the compression and the expansion heat recovery at the same time. This requires additional pumping capacity for the ORC fluid and for the heat transfer fluid. Also the ORC boiler needs to be sized accordingly. In addition it would probably be necessary to have two parallel ORC turbines.
  • One of the turbines could be sized for the compression duty and the other for the expansion duty, with valves controlling the flow to either one or to both simultaneously.
  • both ORC turbines could be used. The performance of the system in pure heat recovery mode without storage of compressed air is improved slightly relative to the performance with compressed air storage since the losses in the pump- turbine of the hydraulic pumping system are avoided.
  • the flexibility of the system can be enhanced if the motor 2 in Figure 1 and generator 80 in Figure 2 have a variable frequency drive such that the speed of the compressors and expanders can be varied. This allows the air mass flow and the power input or output to be varied with little variation in efficiency.
  • guide vanes may be used to increase the operational flexibility of these components by altering the angle at which the air flow meets the rotating blades of the turbo-compressors or turbines. This allows the turbo-compressors and turbo-expanders to operate more efficiently over a wider range of flow conditions.
  • the best mode for carrying out the invention is considered to be the mode illustrated in Figure 1 for energy storage, Figure 2 for energy recovery and Figure 3 for continuous power generation.
  • a hydraulic compensation system would be used to maintain the stored air at constant high pressure.
  • the air compression and expansion system would be based on turbo-machinery.
  • An organic Rankine cycle would be used in all three types of operation and sized so that it could recover all the available low temperature heat in each case. This may require two organic turbines, which could operate singly or together as required.
  • the waste heat source would ideally be an existing industrial gas turbine designed for peaking duty and with a high exhaust gas temperature approaching 600°C.
  • the invention described here is suitable for retrofitting to existing equipment, if sufficient space is available.
  • the required modifications to the existing plant essentially consist of inserting heat recovery heat exchangers in the flow path of the waste gases. This will have some effect on the backpressure of the system, but it does not involve any other significant modification to the original process.
  • the source of waste heat must be available when it is required to recover the stored energy of the compressed air. This means that the source of waste heat must either be in operation continuously or it must be brought into operation at the same time as the compressed air energy recovery process.
  • Peaking gas turbines are widely used to provide power at times of high demand.
  • the capital costs of these turbines is low but the running costs are high, since the thermal efficiency of simple cycle gas turbines is much less than combined cycle plants, in which the waste heat is recovered by a steam turbine. Consequently most of these simple cycle gas turbines run relatively few hours in a year and the economics of such plant is very dependent on having sufficient running hours or if not, receiving adequate capacity payments for availability.
  • the timing of the operation of the peaking plant is most likely to coincide with the time at which stored energy recovery is required.
  • CAES plant which makes use of the waste heat of such turbines to provide energy storage and recovery could be very beneficial to the utilisation of peaking gas turbines.
  • the energy storage capability would enhance the power output and significantly reduce the running cost of the plant, so that it could be called into operation more frequently and receive higher revenues from additional grid services it could provide, such as frequency regulation and flexible capacity. It would also allow the peaking gas turbine to operate with a better efficiency and lower emissions at part load. Referring to Figure 3, this would be accomplished by running the peaking gas turbine at part load while running the compressor at full load. Some compressed air would be used for heat recovery but a substantial fraction of the air would be stored.
  • the power delivered to the grid could be much smaller than the minimum part load capability of a stand-alone peaking plant and the surplus energy would be stored for future use.
  • This also has advantages relative to air emissions, in particular CO emissions, which tend to increase when a peaking gas turbine is run at low load. Peaking gas turbines are sometimes forced to shut down at low power levels because of limits on emissions, but this can be avoided by the method described.
  • a large industrial gas turbine coupled with a waste heat recovery and compressed air energy storage system as described above could use the compressed air storage capacity to vary the net output in response to demand from about -60% to +180% of the original gas turbine power output.
  • the same plant could operate indefinitely without storing or consuming compressed air as a power generator with an efficiency of 45%, which is about 10 percentage points higher than the efficiency of the gas turbine by itself.

Landscapes

  • Engineering & Computer Science (AREA)
  • Chemical & Material Sciences (AREA)
  • Combustion & Propulsion (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Engine Equipment That Uses Special Cycles (AREA)

Abstract

L'invention porte sur un système de récupération de chaleur résiduelle apte pour des gaz à haute température au-dessus de 400° C, lequel système est combiné à un stockage d'énergie à air comprimé. De l'air atmosphérique est comprimé en un processus de compression à étapes multiples à l'aide de refroidisseurs intermédiaires et d'un post-refroidisseur qui transfèrent la chaleur de compression à un cycle de Rankine organique. L'air est de préférence stocké dans un système de stockage qui utilise une pompe-turbine hydraulique pour pomper de l'eau vers l'intérieur ou vers l'extérieur du récipient de stockage, de telle sorte qu'une pression approximativement constante est maintenue. Pendant la récupération d'énergie, de l'air comprimé est récupéré à partir du stockage, chauffé par la source de chaleur résiduelle puis détendu par étapes, de telle sorte que la température d'air après chaque étape de détente est supérieure à 200° C. La chaleur résiduelle à des températures plus basses est récupérée dans le même cycle de Rankine organique que celui utilisé en compression. Le système peut également être actionné de façon continue sous la forme d'un système de récupération de chaleur pure sans stockage ni extraction d'air comprimé.
PCT/GB2015/053465 2014-11-17 2015-11-13 Système de récupération de chaleur résiduelle combiné à un stockage d'énergie à air comprimé WO2016079485A1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
GB1420343.4A GB2532281A (en) 2014-11-17 2014-11-17 A waste heat recovery system combined with compressed air energy storage
GB1420343.4 2014-11-17

Publications (1)

Publication Number Publication Date
WO2016079485A1 true WO2016079485A1 (fr) 2016-05-26

Family

ID=52248424

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/GB2015/053465 WO2016079485A1 (fr) 2014-11-17 2015-11-13 Système de récupération de chaleur résiduelle combiné à un stockage d'énergie à air comprimé

Country Status (2)

Country Link
GB (1) GB2532281A (fr)
WO (1) WO2016079485A1 (fr)

Cited By (21)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN106988996A (zh) * 2017-03-02 2017-07-28 西安交通大学 一种回收空分压缩机级间冷却余热发电的装置
WO2018107279A1 (fr) * 2016-12-13 2018-06-21 Blue Box Technology Inc. Appareil pour extraire de l'énergie à partir de la chaleur perdue
FR3074844A1 (fr) * 2017-12-11 2019-06-14 IFP Energies Nouvelles Procede ameliore de stockage et de production d'energie avec une gestion de l'eau optimisee
FR3074845A1 (fr) * 2017-12-11 2019-06-14 IFP Energies Nouvelles Systeme de stockage et de recuperation d'energie ameliore
CN110567192A (zh) * 2019-09-04 2019-12-13 鞍钢股份有限公司 一种制氧工序余热梯级利用系统及方法
CN110567191A (zh) * 2019-09-04 2019-12-13 鞍钢股份有限公司 一种制氧工序余热回收利用系统及方法
CN110906775A (zh) * 2019-10-30 2020-03-24 鞍钢股份有限公司 适用于波动热负荷的余热利用系统及方法
CN111156087A (zh) * 2020-01-21 2020-05-15 王丽琴 一种内燃机动力装置及其应用系统
CN112424482A (zh) * 2018-05-16 2021-02-26 绿意能源股份公司 用于气体的压缩、膨胀和/或存储的方法、系统和设备
CN113032992A (zh) * 2021-03-22 2021-06-25 西安热工研究院有限公司 一种与煤电耦合的高压空气储能系统最优冷源的确定方法
EP3907390A1 (fr) * 2020-05-05 2021-11-10 Fundación Cener Usine de production d'énergie
CN114439564A (zh) * 2022-01-30 2022-05-06 中国长江三峡集团有限公司 一种光热增强的压缩空气储能系统及方法
WO2022117406A1 (fr) 2020-12-03 2022-06-09 IFP Energies Nouvelles Procede de stockage et de recuperation d'energie avec optimisation thermique a la detente
WO2022117398A1 (fr) 2020-12-03 2022-06-09 IFP Energies Nouvelles Systeme et procede de stockage et de recuperation d'energie par gaz comprime avec recuperation de liquide
WO2022117407A1 (fr) 2020-12-03 2022-06-09 IFP Energies Nouvelles Système et procédé de stockage et de récupération d'énergie par gaz comprimé avec cycle de rankine
WO2022117397A1 (fr) 2020-12-03 2022-06-09 IFP Energies Nouvelles Systeme et procede de stockage et de recuperation d'energie par gaz comprime avec rechauffage de liquide
FR3117163A1 (fr) 2020-12-03 2022-06-10 IFP Energies Nouvelles procédé de stockage et de récupération d’énergie comprenant une turbine à gaz pour réchauffer le gaz comprimé à la détente
WO2022166381A1 (fr) * 2021-02-07 2022-08-11 百穰新能源科技(深圳)有限公司 Dispositif et procédé de stockage d'énergie basés sur un changement de phase gaz-liquide de co2 pour compléter de l'énergie externe
CN114909196A (zh) * 2022-04-28 2022-08-16 西安热工研究院有限公司 一种抽水压缩等压释放空气储能系统及方法
CN115013220A (zh) * 2022-06-30 2022-09-06 中国电建集团华东勘测设计研究院有限公司 基于中深层干热岩的紧凑型地热能压缩空气储能系统、方法
CN116202128A (zh) * 2023-02-23 2023-06-02 中国电建集团河北省电力勘测设计研究院有限公司 一种利用压缩空气储能压缩热余热供暖的方法

Families Citing this family (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
FR3074846B1 (fr) * 2017-12-11 2019-12-20 IFP Energies Nouvelles Procede de stockage et de production d'energie par air comprime avec recuperation d'energie supplementaire
CZ2018215A3 (cs) * 2018-05-04 2019-09-18 Vysoká Škola Báňská-Technická Univerzita Ostrava Zařízení pro výrobu elektřiny a tepla s akumulací médií
US11944635B1 (en) 2023-07-24 2024-04-02 Poviva Corp Compositions and methods for treating epilepsy
US11986485B1 (en) 2023-07-24 2024-05-21 Poviva Corp Compositions and methods for treating epilepsy
CN117803477B (zh) * 2023-12-22 2024-06-11 中国航空工业集团公司金城南京机电液压工程研究中心 一种基于燃油进行电液热互补的机电系统

Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4942736A (en) * 1988-09-19 1990-07-24 Ormat Inc. Method of and apparatus for producing power from solar energy
US6038849A (en) * 1998-07-07 2000-03-21 Michael Nakhamkin Method of operating a combustion turbine power plant using supplemental compressed air
WO2011059557A2 (fr) * 2009-11-13 2011-05-19 General Electric Company Système et procédé pour production d'énergie secondaire dans un système de stockage d'énergie à air comprimé
WO2013124504A1 (fr) * 2012-02-23 2013-08-29 Prextor Systems, S.L. Technique de stockage d'énergie par air comprimé (caes) à cycle combiné (ccc)
US8689566B1 (en) * 2012-10-04 2014-04-08 Lightsail Energy, Inc. Compressed air energy system integrated with gas turbine

Family Cites Families (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CH696978A5 (de) * 2003-12-22 2008-02-29 Alstom Technology Ltd Kraftwerksanlage, und Verfahren zum Betrieb.
US8341964B2 (en) * 2009-10-27 2013-01-01 General Electric Company System and method of using a compressed air storage system with a gas turbine
US20110094231A1 (en) * 2009-10-28 2011-04-28 Freund Sebastian W Adiabatic compressed air energy storage system with multi-stage thermal energy storage
JP5747309B2 (ja) * 2011-07-29 2015-07-15 一般財団法人電力中央研究所 Ｃａｅｓシステムおよびこれを有する発電プラント

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4942736A (en) * 1988-09-19 1990-07-24 Ormat Inc. Method of and apparatus for producing power from solar energy
US6038849A (en) * 1998-07-07 2000-03-21 Michael Nakhamkin Method of operating a combustion turbine power plant using supplemental compressed air
WO2011059557A2 (fr) * 2009-11-13 2011-05-19 General Electric Company Système et procédé pour production d'énergie secondaire dans un système de stockage d'énergie à air comprimé
WO2013124504A1 (fr) * 2012-02-23 2013-08-29 Prextor Systems, S.L. Technique de stockage d'énergie par air comprimé (caes) à cycle combiné (ccc)
US8689566B1 (en) * 2012-10-04 2014-04-08 Lightsail Energy, Inc. Compressed air energy system integrated with gas turbine

Cited By (32)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2018107279A1 (fr) * 2016-12-13 2018-06-21 Blue Box Technology Inc. Appareil pour extraire de l'énergie à partir de la chaleur perdue
CN106988996A (zh) * 2017-03-02 2017-07-28 西安交通大学 一种回收空分压缩机级间冷却余热发电的装置
FR3074844A1 (fr) * 2017-12-11 2019-06-14 IFP Energies Nouvelles Procede ameliore de stockage et de production d'energie avec une gestion de l'eau optimisee
FR3074845A1 (fr) * 2017-12-11 2019-06-14 IFP Energies Nouvelles Systeme de stockage et de recuperation d'energie ameliore
WO2019115119A1 (fr) 2017-12-11 2019-06-20 IFP Energies Nouvelles Systeme de stockage et de recuperation d'energie ameliore
WO2019115121A1 (fr) 2017-12-11 2019-06-20 IFP Energies Nouvelles Procede ameliore de stockage et de production d'energie avec une gestion de l'eau optimisee
US11203973B2 (en) 2017-12-11 2021-12-21 IFP Energies Nouvelles Method for storing and producing energy with optimized water management
CN112424482A (zh) * 2018-05-16 2021-02-26 绿意能源股份公司 用于气体的压缩、膨胀和/或存储的方法、系统和设备
CN110567192A (zh) * 2019-09-04 2019-12-13 鞍钢股份有限公司 一种制氧工序余热梯级利用系统及方法
CN110567191A (zh) * 2019-09-04 2019-12-13 鞍钢股份有限公司 一种制氧工序余热回收利用系统及方法
CN110906775A (zh) * 2019-10-30 2020-03-24 鞍钢股份有限公司 适用于波动热负荷的余热利用系统及方法
CN111156087A (zh) * 2020-01-21 2020-05-15 王丽琴 一种内燃机动力装置及其应用系统
EP3907390A1 (fr) * 2020-05-05 2021-11-10 Fundación Cener Usine de production d'énergie
WO2022117398A1 (fr) 2020-12-03 2022-06-09 IFP Energies Nouvelles Systeme et procede de stockage et de recuperation d'energie par gaz comprime avec recuperation de liquide
FR3117166A1 (fr) 2020-12-03 2022-06-10 IFP Energies Nouvelles Système et procédé de stockage et de récupération d’énergie par gaz comprimé avec réchauffage de liquide
WO2022117406A1 (fr) 2020-12-03 2022-06-09 IFP Energies Nouvelles Procede de stockage et de recuperation d'energie avec optimisation thermique a la detente
FR3117167A1 (fr) 2020-12-03 2022-06-10 IFP Energies Nouvelles procédé de stockage et de récupération d’énergie avec optimisation thermique à la détente
WO2022117407A1 (fr) 2020-12-03 2022-06-09 IFP Energies Nouvelles Système et procédé de stockage et de récupération d'énergie par gaz comprimé avec cycle de rankine
WO2022117397A1 (fr) 2020-12-03 2022-06-09 IFP Energies Nouvelles Systeme et procede de stockage et de recuperation d'energie par gaz comprime avec rechauffage de liquide
FR3117164A1 (fr) 2020-12-03 2022-06-10 IFP Energies Nouvelles Système et procédé de stockage et de récupération d’énergie par gaz comprimé avec cycle de Rankine
FR3117163A1 (fr) 2020-12-03 2022-06-10 IFP Energies Nouvelles procédé de stockage et de récupération d’énergie comprenant une turbine à gaz pour réchauffer le gaz comprimé à la détente
FR3117165A1 (fr) 2020-12-03 2022-06-10 IFP Energies Nouvelles Système et procédé de stockage et de récupération d’énergie par gaz comprimé avec récupération de liquide
WO2022166381A1 (fr) * 2021-02-07 2022-08-11 百穰新能源科技(深圳)有限公司 Dispositif et procédé de stockage d'énergie basés sur un changement de phase gaz-liquide de co2 pour compléter de l'énergie externe
CN113032992A (zh) * 2021-03-22 2021-06-25 西安热工研究院有限公司 一种与煤电耦合的高压空气储能系统最优冷源的确定方法
CN113032992B (zh) * 2021-03-22 2023-03-28 西安热工研究院有限公司 一种与煤电耦合的高压空气储能系统最优冷源的确定方法
CN114439564A (zh) * 2022-01-30 2022-05-06 中国长江三峡集团有限公司 一种光热增强的压缩空气储能系统及方法
CN114439564B (zh) * 2022-01-30 2023-08-18 中国长江三峡集团有限公司 一种光热增强的压缩空气储能系统及方法
CN114909196A (zh) * 2022-04-28 2022-08-16 西安热工研究院有限公司 一种抽水压缩等压释放空气储能系统及方法
CN115013220A (zh) * 2022-06-30 2022-09-06 中国电建集团华东勘测设计研究院有限公司 基于中深层干热岩的紧凑型地热能压缩空气储能系统、方法
CN115013220B (zh) * 2022-06-30 2023-10-13 中国电建集团华东勘测设计研究院有限公司 基于中深层干热岩的紧凑型地热能压缩空气储能系统、方法
CN116202128A (zh) * 2023-02-23 2023-06-02 中国电建集团河北省电力勘测设计研究院有限公司 一种利用压缩空气储能压缩热余热供暖的方法
CN116202128B (zh) * 2023-02-23 2023-10-03 中国电建集团河北省电力勘测设计研究院有限公司 一种利用压缩空气储能压缩热余热供暖的方法

Also Published As

Publication number Publication date
GB2532281A (en) 2016-05-18
GB201420343D0 (en) 2014-12-31

Similar Documents

Publication Publication Date Title
WO2016079485A1 (fr) Système de récupération de chaleur résiduelle combiné à un stockage d'énergie à air comprimé
WO2016012764A1 (fr) Système de stockage et de récupération d'énergie d'air comprimé
Rahbar et al. Review of organic Rankine cycle for small-scale applications
EP2550436B1 (fr) Moteurs thermiques avec cycles en cascade
US8869531B2 (en) Heat engines with cascade cycles
US8250847B2 (en) Combined Brayton-Rankine cycle
JP2858750B2 (ja) 貯蔵したエネルギ利用の発電システム，方法およびその装置
US20080050234A1 (en) Wind turbine system
EP3314096B1 (fr) Systeme et procede de production d'energie utile a partir de la chaleur fournie par une source de chaleur
US20080047271A1 (en) Wind turbine system
Parente et al. Micro humid air cycle: Part a—thermodynamic and technical aspects
EP3927949B1 (fr) Installation et procédé de stockage d'énergie
WO2012074940A2 (fr) Moteurs thermiques à cycles en cascade
DK2627876T3 (en) A method and system for utilizing a power source of relatively low temperature
Astolfi Technical options for organic Rankine cycle systems
Choi et al. Development of a 500° C semi-pilot scale supercritical CO2 power cycle test loop
Hudson Technical and economic overview of geothermal atmospheric exhaust and condensing turbines, binary cycle and biphase plant
JPWO2020039416A5 (fr)
RU2745182C1 (ru) Парогазовая установка на сжиженном природном газе
EP4150196B1 (fr) Cycle d'énergie de recondensation pour regazéification de fluide
Galashov et al. Algorithm for calculation of a CCGT of a trinary type with an air condenser
RU2330968C2 (ru) Теплотурбодетандерная установка в системе грс
Brandsar Offshore Rankine Cycles
EA042233B1 (ru) Установка и способ хранения энергии
Bonafin Geothermal Binary Plants for European Development

Legal Events

Date Code Title Description
121 Ep: the epo has been informed by wipo that ep was designated in this application

Ref document number: 15807972

Country of ref document: EP

Kind code of ref document: A1

NENP Non-entry into the national phase

Ref country code: DE

122 Ep: pct application non-entry in european phase

Ref document number: 15807972

Country of ref document: EP

Kind code of ref document: A1