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
• • 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
  • F02C1/00—Gas-turbine plants characterised by the use of hot gases or unheated pressurised gases, as the working fluid
  • F02C1/04—Gas-turbine plants characterised by the use of hot gases or unheated pressurised gases, as the working fluid the working fluid being heated indirectly
  • F02C1/10—Closed cycles
• • 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
  • F05D2240/00—Components
  • F05D2240/20—Rotors
  • F05D2240/30—Characteristics of rotor blades, i.e. of any element transforming dynamic fluid energy to or from rotational energy and being attached to a rotor
  • F05D2240/301—Cross-sectional characteristics
• • 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
  • F05D2260/42—Storage of energy
• • 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
  • Y02E20/00—Combustion technologies with mitigation potential
  • Y02E20/14—Combined heat and power generation [CHP]
• • 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
  • Y02E60/14—Thermal energy storage

Definitions

• a heat exchanger may be employed to transfer heat between a thermal storage material and a working fluid for use with turbomachinery.
• the heat engine may be reversible, e.g., it may also be a heat pump, and the working fluid and heat exchanger may be used to transfer heat or cold to thermal storage media.
• a Pumped Heat Energy Storage (“PHES”) system may include at least a working fluid circulated through a closed cycle fluid path including at least two heat exchangers, at least one turbine, and at least one compressor.
• a system includes PHES system that includes a first reversible turbomachine, a second reversible turbomachine, a hot-side heat exchanger, and a cold-side heat exchanger.
• the PHES system is configured to operate in a charge mode and a discharge mode.
• the first reversible turbomachine acts as a compressor
• the second reversible turbomachine acts as a turbine
• a working fluid circulates through, in sequence, the first reversible turbomachine, the hot-side heat exchanger, the second reversible turbomachine, the cold-side heat exchanger, and back to the first reversible turbomachine.
• the first reversible turbomachine acts as a turbine
• the second reversible turbomachine acts as a compressor
• the working fluid circulates through, in sequence, the first reversible turbomachine, the cold-side heat exchanger, the second reversible turbomachine, the hot-side heat exchanger, and back to the first reversible turbomachine.
• a system in another aspect, includes PHES system that includes a first reversible turbomachine, a second reversible turbomachine, a hot-side heat exchanger, a cold-side heat exchanger, and a recuperator heat exchanger.
• the PHES system is configured to operate in a charge mode and a discharge mode.
• the first reversible turbomachine acts as a compressor
• the second reversible turbomachine acts as a turbine
• a working fluid circulates through, in sequence, the first reversible turbomachine, the hot-side heat exchanger, the recuperator heat exchanger, the second reversible turbomachine, the cold-side heat exchanger, the recuperator heat exchanger, and back to the first reversible turbomachine.
• the first reversible turbomachine acts as a turbine
• the second reversible turbomachine acts as a compressor
• the working fluid circulates through, in sequence, the first reversible turbomachine, the recuperator heat exchanger, the cold-side heat exchanger, the second reversible turbomachine, the recuperator heat exchanger, the hot-side heat exchanger, and back to the first reversible turbomachine.
• a method in another aspect, includes operating a first reversible turbomachine as a compressor and circulating a working fluid from the first reversible turbomachine to, in sequence, a hot-side heat exchanger, a second turbomachine acting as a turbine, a cold-side heat exchanger, and back to the first reversible turbomachine.
• the method further includes operating the first reversible turbomachine as a turbine and circulating the working fluid from the first reversible turbomachine to, in sequence, the cold-side heat exchanger, a third turbomachine acting as a compressor, the hot-side heat exchanger, and back to the first reversible turbomachine.
• FIG.1 schematically illustrates operation of a pumped thermal electric storage system.
• FIG.2 is a schematic flow diagram of working fluid and heat storage media of a pumped thermal system in a charge/heat pump mode.
• FIG.3 is a schematic flow diagram of working fluid and heat storage media of a pumped thermal system in a discharge/heat engine mode.
• FIG. 4 is a schematic pressure and temperature diagram of the working fluid as it undergoes the charge cycle in FIG.2.
• FIG. 5 is a schematic pressure and temperature diagram of the working fluid as it undergoes the discharge cycle in FIG.3.
• FIG.6 is a schematic perspective view of a closed working fluid system in the pumped thermal system in FIGs.2-3.
• FIG.7 is a schematic perspective view of the pumped thermal system in FIGs.2-3 with hot side and cold side storage tanks and a closed cycle working fluid system.
• FIG. 10 shows a heat storage cycle in a pumped thermal system with variable compression ratios between the charge and discharge cycles.
• FIG. 11 shows roundtrip efficiency contours for a water/salt system. The symbols ⁇ and represent an approximate range of present large turbomachinery adiabatic efficiency values. The dashed arrows represent the direction of increasing efficiency.
• FIG. 12 shows roundtrip efficiency contours for a colder storage/salt system. The symbols represent an approximate range of present large turbomachinery adiabatic efficiency values.
• FIG. 13 is a schematic flow diagram of working fluid and heat storage media of a pumped thermal system with a gas-gas heat exchanger for the working fluid in a charge/heat pump mode. [0019] FIG.
• FIG. 14 is a schematic flow diagram of working fluid and heat storage media of a pumped thermal system with a gas-gas heat exchanger for the working fluid in a discharge/heat engine mode.
• FIG. 15 is a schematic flow diagram of working fluid and heat storage media of a pumped thermal system with a gas-gas heat exchanger for the working fluid in a charge/heat pump mode with indirect heat rejection to the environment.
• FIG. 16 is a schematic flow diagram of working fluid and heat storage media of a pumped thermal system with a gas-gas heat exchanger for the working fluid in a discharge/heat engine mode with indirect heat rejection to the environment.
• FIG. 15 is a schematic flow diagram of working fluid and heat storage media of a pumped thermal system with a gas-gas heat exchanger for the working fluid in a discharge/heat engine mode with indirect heat rejection to the environment.
• FIG. 16 is a schematic flow diagram of working fluid and heat storage media of a pumped thermal system with a gas-gas heat exchanger for the working fluid in a discharge/
• FIG. 19 is a schematic flow diagram of hot side recharging in a pumped heat cycle in solar mode with heating of a solar salt solely by solar power.
• FIG.20 is a schematic flow diagram of a pumped thermal system discharge cycle with heat rejection to ambient.
• FIG.21 is a schematic flow diagram of a pumped thermal system discharge cycle with heat rejection to an intermediate fluid circulated in a thermal bath at ambient temperature.
• FIGs. 22 and 23 are pumped thermal systems with separate compressor/turbine pairs for charge and discharge modes.
• FIGs. 24 and 25 show pumped thermal systems configured in a combustion heat input generation mode.
• FIG. 26 is a schematic flow diagram of hot side recharging in a pumped heat cycle through heating by a combustion heat source or a waste heat source.
• FIG.27 shows an example of a pumped thermal system with pressure regulated power control.
• FIG. 28 shows an example of a pumped thermal system with a pressure encased generator.
• FIG.29 is an example of variable stators in a compressor/turbine pair.
• FIG. 30 shows a computer system that is programmed to implement various methods and/or regulate various systems of the present disclosure.
• FIGs. 31A and 31B are schematic flow diagrams of working fluid and heat storage media of a pumped thermal system with reversible turbomachinery in charge and discharge modes.
• FIGs. 32A and 32B are schematic flow diagrams of working fluid and heat storage media of a pumped thermal system with reversible turbomachinery in charge and discharge modes.
• FIG.33 is a schematic diagram of a combined turbomachine drivetrain.
• FIG.34 is a schematic diagram of individual turbomachine drivetrains.
• FIG. 35 is a representation of a pair of reversible turbomachines, according to an example embodiment.
• FIGs. 36-39 are illustrations of reversible turbomachine blades compared to conventional turbine and compressor blades, according to example embodiments.
• FIG. 40 is a representation of a compressor or turbine stage, viewed axially, according to an example embodiment.
• FIG.42 is an illustration of an example blade arc, according to an example embodiment.
• FIGs. 43-45 are illustrations of blade shapes based on the blade arc of FIG. 42, according to example embodiments. [0043] FIGs.
• Example systems and methods are described herein. It should be understood that the words “example” and/or “exemplary” are used herein to mean “serving as an example, instance, or illustration.” Any embodiment or feature described herein as being an “example” or “exemplary” is not necessarily to be construed as preferred or advantageous over other embodiments or features. The example embodiments described herein are not meant to be limiting. It will be readily understood that certain aspects of the disclosed systems and methods can be arranged and combined in a wide variety of different configurations, all of which are contemplated herein.
• a closed thermodynamic cycle power generation or energy storage system such as a reversible Brayton cycle system, may use a generator/motor connected to a turbine and a compressor which act on a working fluid circulating in the system.
• working fluids include air, argon, carbon dioxide, or gaseous mixtures.
• a closed thermodynamic cycle power generation or energy storage system such as a reversible Brayton cycle system, may have a hot side and/or a cold side. Each side may include a heat exchanger coupled to one or more cold storage containers and/or one or more hot storage containers.
• the heat exchangers may be arranged as counterflow heat exchangers for higher thermal efficiency.
• Liquid thermal storage medium may include, for example, liquids that are stable at high temperatures, such as molten nitrate salt or solar salt, or liquids that are stable at low temperatures, such as glycols or alkanes such as hexane.
• the hot side molten salt may include a hot storage at approximately 565 °C and a cold storage at approximately 290 °C and the cold side hexane may include a hot storage at approximately 35 °C and a cold storage at approximately -60 °C.
• Large power generation systems may be slow to ramp up to full power generation.
• out-of-phase transient spikes in generated power in such large systems may be disruptive.
• Each power subunit may include a valve arrangement configurable to be in a connected state or an isolated state with respect to a shared hot side thermal store and a shared cold side thermal store (i.e., to be in use or not in use).
• reversible generally refers to a process or operation that can be reversed via infinitesimal changes in some property of the process or operation without substantial entropy production (e.g., dissipation of energy). A reversible process may be approximated by a process that is at thermodynamic equilibrium.
• the direction of flow of energy is reversible.
• the general direction of operation of a reversible process e.g., the direction of fluid flow
• the general direction of operation of a reversible process can be reversed, such as, e.g., from clockwise to counterclockwise, and vice versa.
• sequence generally refers to elements (e.g., unit operations) in order. Such order can refer to process order, such as, for example, the order in which a fluid flows from one element to another.
• a compressor, heat storage unit and turbine in sequence includes the compressor upstream of the heat exchange unit, and the heat exchange unit upstream of the turbine.
• a fluid can flow from the compressor to the heat exchange unit and from the heat exchange unit to the turbine.
• a fluid flowing through unit operations in sequence can flow through the unit operations sequentially.
• a sequence of elements can include one or more intervening elements.
• a system comprising a compressor, heat storage unit and turbine in sequence can include an auxiliary tank between the compressor and the heat storage unit.
• a sequence of elements can be cyclical.
• Pumped thermal systems The disclosure provides pumped thermal systems capable of storing electrical energy and/or heat, and releasing energy (e.g., producing electricity) at a later time.
• the pumped thermal systems of the disclosure may include a heat engine, and a heat pump (or refrigerator). In some cases, the heat engine can be operated in reverse as a heat pump.
• the heat engine can be operated in reverse as a refrigerator.
• Any description of heat pump/heat engine systems or refrigerator/heat engine systems capable of reverse operation herein may also be applied to systems comprising separate and/or a combination of separate and reverse- operable heat engine system(s), heat pump system(s) and/or refrigerator system(s).
• any description of configurations or operation of heat pumps herein may also be applied to configurations or operation of refrigerators, and vice versa.
• Systems of the present disclosure can operate as heat engines or heat pumps (or refrigerators). In some situations, systems of the disclosure can alternately operate as heat engines and heat pumps.
• a system can operate as a heat engine to generate power, and subsequently operate as a heat pump to store energy, or vice versa.
• Such systems can alternately and sequentially operate as heat engines as heat pumps.
• such systems reversibly or substantially reversibly operate as heat engines as heat pumps.
• Electricity may be stored in the form of thermal energy of two materials or media at different temperatures (e.g., thermal energy reservoirs comprising heat storage fluids or thermal storage media) by using a combined heat pump/heat engine system.
• a charging or heat pump mode work may be consumed by the system for transferring heat from a cold material or medium to a hot material or medium, thus lowering the temperature (e.g., sensible energy) of the cold material and increasing the temperature (i.e., sensible energy) of the hot material.
• a discharging or heat engine mode work may be produced by the system by transferring heat from the hot material to the cold material, thus lowering the temperature (i.e., sensible energy) of the hot material and increasing the temperature (i.e., sensible energy) of the cold material.
• the system may be configured to ensure that the work produced by the system on discharge is a favorable fraction of the energy consumed on charge.
• the system may be configured to achieve high roundtrip efficiency, defined herein as the work produced by the system on discharge divided by the work consumed by the system on charge. Further, the system may be configured to achieve the high roundtrip efficiency using components of a desired (e.g., acceptably low) cost.
• Arrows H and W in FIG. 1 represent directions of heat flow and work, respectively.
• Heat engines, heat pumps and refrigerators of the disclosure may involve a working fluid to and from which heat is transferred while undergoing a thermodynamic cycle. The heat engines, heat pumps and refrigerators of the disclosure may operate in a closed cycle.
• Closed cycles allow, for example, a broader selection of working fluids, operation at elevated cold side pressures, operation at lower cold side temperatures, improved efficiency, and reduced risk of turbine damage.
• One or more aspects of the disclosure described in relation to systems having working fluids undergoing closed cycles may also be applied to systems having working fluids undergoing open cycles.
• the heat engines may operate on a Brayton cycle and the heat pumps/refrigerators may operate on a reverse Brayton cycle (also known as a gas refrigeration cycle).
• Other examples of thermodynamic cycles that the working fluid may undergo or approximate include the Rankine cycle, the ideal vapor-compression refrigeration cycle, the Stirling cycle, the Ericsson cycle or any other cycle advantageously employed in concert with heat exchange with heat storage fluids of the disclosure.
• the working fluid can undergo a thermodynamic cycle operating at one, two or more pressure levels.
• the working fluid may operate in a closed cycle between a low pressure limit on a cold side of the system and a high pressure limit on a hot side of the system.
• a low pressure limit of about 10 atmospheres (atm) or greater can be used.
• the low pressure limit may be at least about 1 atm, at least about 2 atm, at least about 5 atm, at least about 10 atm, at least about 15 atm, at least about 20 atm, at least about 30 atm, at least about 40 atm, at least about 60 atm, at least about 80 atm, at least about 100 atm, at least about 120 atm, at least about 160 atm, or at least about 200 atm, 500 atm, 1000 atm, or more.
• a sub-atmospheric low pressure limit may be used.
• the low pressure limit may be less than about 0.1 atm, less than about 0.2 atm, less than about 0.5 atm, or less than about 1 atm.
• the low pressure limit may be about 1 atmosphere (atm). In the case of a working fluid operating in an open cycle, the low pressure limit may be about 1 atm or equal to ambient pressure.
• the value of the low pressure limit may be selected based on desired power output and/or power input requirements of the thermodynamic cycle. For example, a pumped thermal system with a low pressure limit of about 10 atm may be able to provide a power output comparable to an industrial gas turbine with ambient (1 atm) air intake. The value of the low pressure limit may also be subject to cost/safety tradeoffs.
• the value of the low pressure limit may be limited by the value of the high pressure limit, the operating ranges of the hot side and cold side heat storage media (e.g., pressure and temperature ranges over which the heat storage media are stable), pressure ratios and operating conditions (e.g., operating limits, optimal operating conditions, pressure drop) achievable by turbomachinery and/or other system components, or any combination thereof.
• the high pressure limit may be determined in accordance with these system constraints. In some instances, higher values of the high pressure limit may lead to improved heat transfer between the working fluid and the hot side storage medium.
• Working fluids used in pumped thermal systems may include air, argon, other noble gases, carbon dioxide, hydrogen, oxygen, or any combination thereof, and/or other fluids in gaseous, liquid, critical, or supercritical state (e.g., supercritical CO2).
• the working fluid can be a gas or a low viscosity liquid (e.g., viscosity below about 500x10 -6 Poise at 1 atm), satisfying the requirement that the flow be continual.
• a gas with a high specific heat ratio may be used to achieve higher cycle efficiency than a gas with a low specific heat ratio.
• argon e.g., specific heat ratio of about 1.66
• air e.g., specific heat ratio of about 1.4
• the working fluid may be a blend of one, two, three or more fluids.
• helium having a high thermal conductivity and a high specific heat
• Pumped thermal systems herein may utilize heat storage media or materials, such as one or more heat storage fluids.
• the heat storage media can be gases or low viscosity liquids, satisfying the requirement that the flow be continual.
• the systems may utilize a first heat storage medium on a hot side of the system (“hot side thermal storage (HTS) medium” or “HTS” herein) and a second heat storage medium on a cold side of the system (“cold side thermal storage (CTS) medium” or “CTS” herein).
• the thermal storage media e.g., low viscosity liquids
• can have high heat capacities per unit volume e.g., heat capacities above about 1400 Joule (kilogram Kelvin) -1
• high thermal conductivities e.g., thermal conductivities above about 0.7 Watt (meter Kelvin) -1 ).
• thermal storage media on either the hot side, cold side or both the hot side and the cold side
• the operating temperatures of the hot side thermal storage medium can be in the liquid range of the hot side thermal storage medium
• the operating temperatures of the cold side thermal storage medium can be in the liquid range of the cold side thermal storage medium.
• liquids may enable a more rapid exchange of large amounts of heat by convective counter-flow than solids or gases.
• liquid HTS and CTS media may advantageously be used.
• Pumped thermal systems utilizing thermal storage media herein may advantageously provide a safe, non-toxic and geography-independent energy (e.g., electricity) storage alternative.
• the hot side thermal storage medium can be a molten salt or a mixture of molten salts. Any salt or salt mixture that is liquid over the operating temperature range of the hot side thermal storage medium may be employed.
• Molten salts can provide numerous advantages as thermal energy storage media, such as low vapor pressure, lack of toxicity, chemical stability, low chemical reactivity with typical steels (e.g., melting point below the creep temperature of steels, low corrosiveness, low capacity to dissolve iron and nickel), and low cost.
• the HTS is a mixture of sodium nitrate and potassium nitrate. In some examples, the HTS is a eutectic mixture of sodium nitrate and potassium nitrate.
• the HTS is a mixture of sodium nitrate and potassium nitrate having a lowered melting point than the individual constituents, an increased boiling point than the individual constituents, or a combination thereof.
• Other examples include potassium nitrate, calcium nitrate, sodium nitrate, sodium nitrite, lithium nitrate, mineral oil, or any combination thereof.
• Further examples include any gaseous (including compressed gases), liquid or solid media (e.g., powdered solids) having suitable (e.g., high) thermal storage capacities and/or capable of achieving suitable (e.g., high) heat transfer rates with the working fluid.
• a mix of 60% sodium nitrate and 40% potassium nitrate can have a heat capacity of approximately 1500 Joule (Kelvin mole) -1 and a thermal conductivity of approximately 0.75 Watt (meter Kelvin) -1 within a temperature range of interest.
• the hot side thermal storage medium may be operated in a temperature range that structural steels can handle.
• liquid water at temperatures of about 0oC to 100oC (about 273 K-373 K) and a pressure of about 1 atm may be used as the cold side thermal storage medium.
• the operating temperature can be kept below about 100oC or less while maintaining an operating pressure of 1 atm (i.e., no pressurization).
• the temperature operating range of the cold side thermal storage medium may be extended (e.g., to -30oC to 100oC at 1 atm) by using a mixture of water and one or more antifreeze compounds (e.g., ethylene glycol, propylene glycol, or glycerol).
• improved storage efficiency may be achieved by increasing the temperature difference at which the system operates, for example, by using a cold side heat storage fluid capable of operating at lower temperatures.
• the cold side thermal storage media may comprise hydrocarbons, such as, for example, alkanes (e.g., hexane or heptane), alkenes, alkynes, aldehydes, ketones, carboxylic acids (e.g., HCOOH), ethers, cycloalkanes, aromatic hydrocarbons, alcohols (e.g., butanol), other type(s) of hydrocarbon molecules, or any combinations thereof.
• the cold side thermal storage medium can be hexane (e.g., n-hexane).
• Hexane has a wide liquid range and can remain fluid (i.e., runny) over its entire liquid range (-94 oC to 68oC at 1 atm). Hexane’s low temperature properties are aided by its immiscibility with water. Other liquids, such as, for example, ethanol or methanol can become viscous at the low temperature ends of their liquid ranges due to pre-crystallization of water absorbed from air.
• the cold side thermal storage medium can be heptane (e.g., n-heptane). Heptane has a wide liquid range and can remain fluid (i.e., runny) over its entire liquid range (-91 oC to 98oC at 1 atm).
• Heptane low temperature properties are aided by its immiscibility with water.
• other heat storage media can be used, such as, for example, isohexane (2- methylpentane).
• cryogenic liquids having boiling points below about - 150°C (123 K) or about -180 °C (93.15 K) may be used as cold side thermal storage media (e.g., propane, butane, pentane, nitrogen, helium, neon, argon and krypton, air, hydrogen, methane, or liquefied natural gas).
• choice of cold side thermal storage medium may be limited by the choice of working fluid.
• a liquid cold side thermal storage medium having a liquid temperature range at least partially or substantially above the boiling point of the working fluid may be required.
• the operating temperature range of CTS and/or HTS media can be changed by pressurizing (i.e., raising the pressure) or evacuating (i.e., lowering the pressure) the tanks and thus changing the temperature at which the storage media undergo phase transitions (e.g., going from liquid to solid, or from liquid to gas).
• the hot side and the cold side heat storage fluids of the pumped thermal systems are in a liquid state over at least a portion of the operating temperature range of the energy storage device.
• the hot side heat storage fluid may be liquid within a given range of temperatures.
• the cold side heat storage fluid may be liquid within a given range of temperatures.
• the heat storage fluids may be heated, cooled or maintained to achieve a suitable operating temperature prior to, during or after operation.
• Pumped thermal systems of the disclosure may cycle between charged and discharged modes. In some examples, the pumped thermal systems can be fully charged, partially charged or partially discharged, or fully discharged. In some cases, cold side heat storage may be charged (also “recharged” herein) independently from hot side heat storage. Further, in some implementations, charging (or some portion thereof) and discharging (or some portion thereof) can occur simultaneously.
• a first portion of a hot side heat storage may be recharged while a second portion of the hot side heat storage together with a cold side heat storage are being discharged.
• the pumped thermal systems may be capable of storing energy for a given amount of time.
• a given amount of energy may be stored for at least about 1 second, at least about 30 seconds, at least about 1 minute, at least about 5 minutes, at least about 30 minutes, at least about 1 hour, at least about 2 hours, at least about 3 hours, at least about 4 hours, at least about 5 hours, at least about 6 hours, at least about 7 hours, at least about 8 hours, at least about 9 hours, at least about 10 hours, at least about 12 hours at least about 14 hours, at least about 16 hours, at least about 18 hours, at least about 20 hours, at least about 22 hours, at least about 24 hours (1 day), at least about 2 days, at least about 4 days, at least about 6 days, at least about 8 days, at least about 10 days, 20 days, 30 days, 60 days, 100 days, 1 year or more.
• Pumped thermal systems of the disclosure may be capable of storing/receiving input of, and/or extracting/providing output of a substantially large amount of energy and/or power for use with power generation systems (e.g., intermittent power generation systems such as wind power or solar power), power distribution systems (e.g. electrical grid), and/or other loads or uses in grid-scale or stand-alone settings.
• power generation systems e.g., intermittent power generation systems such as wind power or solar power
• power distribution systems e.g. electrical grid
• other loads or uses in grid-scale or stand-alone settings e.g., electrical grid, and/or other loads or uses in grid-scale or stand-alone settings.
• electric power received from an external power source can be used operate the pumped thermal system in a heat pump mode (i.e., transferring heat from a low temperature reservoir to a high temperature reservoir, thus storing energy).
• an external power source e.g., a wind power system, a solar photovoltaic power system, an electrical grid etc.
• the system can supply electric power to an external power system or load (e.g., one or more electrical grids connected to one or more loads, a load, such as a factory or a power- intensive process, etc.) by operating in a heat engine mode (i.e., transferring heat from a high temperature reservoir to a low temperature reservoir, thus extracting energy).
• the system may receive or reject thermal power, including, but not limited to electromagnetic power (e.g., solar radiation) and thermal power (e.g., sensible energy from a medium heated by solar radiation, heat of combustion etc.).
• thermal power e.g., sensible energy from a medium heated by solar radiation, heat of combustion etc.
• the pumped thermal systems are grid-synchronous. Synchronization can be achieved by matching speed and frequency of motors/generators and/or turbomachinery of a system with the frequency of one or more grid networks with which the system exchanges power. For example, a compressor and a turbine can rotate at a given, fixed speed (e.g., 3600 revolutions per minute (rpm)) that is a multiple of grid frequency (e.g., 60 hertz (Hz)).
• rpm revolutions per minute
• Hz hertz
• such a configuration may eliminate the need for additional power electronics.
• the turbomachinery and/or the motors/generators are not grid synchronous. In such cases, frequency matching can be accomplished through the use of power electronics.
• the turbomachinery and/or the motors/generators are not directly grid synchronous but can be matched through the use of gears and/or a mechanical gearbox.
• the pumped thermal systems may also be rampable. Such capabilities may enable these grid-scale energy storage systems to operate as peaking power plants and/or as a load following power plants. In some cases, the systems of the disclosure may be capable of operating as base load power plants. [0075] Pumped thermal systems can have a given power capacity.
• each system can have a charge and/or discharge power capacity of less than about 1 megawatt (MW), at least about 1 megawatt, at least about 2 MW, at least about 3 MW, at least about 4 MW, at least about 5 MW, at least about 6 MW, at least about 7 MW, at least about 8 MW, at least about 9 MW, at least about 10 MW, at least about 20 MW, at least about 30 MW, at least about 40 MW, at least about 50 MW, at least about 75 MW, at least about 100 MW, at least about 200 MW, at least about 500 MW, at least about 1 gigawatt (GW), at least about 2 GW, at least about 5 GW, at least about 10 GW, at least about 20 GW, at least about 30 GW, at least about 40 GW, at least about 50 GW, at least about 75 GW, at least about 100 GW, or more.
• MW megawatt
• GW gigawatt
• Pumped thermal systems can have a given energy storage capacity.
• a pumped thermal system is configured as a 100 MW unit operating for 10 hours.
• a pumped thermal system is configured as a 1 GW plant operating for 12 hours.
• the energy storage capacity can be less than about 1 megawatt hour (MWh), at least about 1 megawatt hour, at least about 10 MWh, at least about 100 MWh, at least about 1 gigawatt hour (GWh), at least about 5 GWh, at least about 10 GWh, at least about 20 GWh, at least 50 GWh, at least about 100 GWh, at least about 200 GWh, at least about 500 GWh, at least about 700 GWh, at least about 1000 GWh, or more.
• a given power capacity may be achieved with a given size, configuration and/or operating conditions of the heat engine/heat pump cycle.
• a given energy storage capacity may be achieved with a given size and/or number of hot side thermal storage tanks and/or cold side thermal storage tanks.
• the heat engine/heat pump cycle can operate at a given power capacity for a given amount of time set by the heat storage capacity of the system or plant.
• the number and/or heat storage capacity of the hot side thermal storage tanks may be different from the number and/or heat storage capacity of the cold side thermal storage tanks.
• the number of tanks may depend on the size of individual tanks.
• the size of hot side storage tanks may differ from the size of cold side thermal storage tanks.
• a pumped thermal storage facility can include any suitable number of hot side storage tanks, such as at least about 2, at least about 4, at least about 10, at least about 50, at least about 100, at least about 500, at least about 1,000, at least about 5,000, at least about 10,000, and the like.
• a pumped thermal storage facility includes 2, 3, 4, 5, 6, 7, 8, 9, 10, 15, 20, 30, 40, 50, 60, 70, 80, 90, 100, 200, 300, 400, 500, 600, 700, 800, 900, 1,000 or more hot side tanks.
• a pumped thermal storage facility can also include any suitable number of cold side storage tanks, such as at least about 2, at least about 4, at least about 10, at least about 50, at least about 100, at least about 500, at least about 1,000, at least about 5,000, at least about 10,000, and the like.
• a pumped thermal storage facility includes 2, 3, 4, 5, 6, 7, 8, 9, 10, 15, 20, 30, 40, 50, 60, 70, 80, 90, 100, 200, 300, 400, 500, 600, 700, 800, 900, 1,000 or more cold side tanks.
• Pumped thermal storage cycles [0081] An aspect of the disclosure relates to pumped thermal systems operating on pumped thermal storage cycles. In some examples, the cycles allow electricity to be stored as heat (e.g., in the form of a temperature differential) and then converted back to electricity through the use of at least two pieces of turbomachinery, a compressor and a turbine. The compressor consumes work and raises the temperature and pressure of a working fluid (WF). The turbine produces work and lowers the temperature and pressure of the working fluid.
• WF working fluid
• FIGs. 2 and 3 are schematic flow diagrams of working fluid and heat storage media of an exemplary pumped thermal system in a charge/heat pump mode and in a discharge/heat engine mode, respectively.
• the system may be idealized for simplicity of explanation so that there are no losses (i.e., entropy generation) in either the turbomachinery or heat exchangers.
• the system can include a working fluid 20 (e.g., argon gas) flowing in a closed cycle between a compressor 1, a hot side heat exchanger 2, a turbine 3 and a cold side heat exchanger 4.
• Fluid flow paths/directions for the working fluid 20 e.g., a gas
• a hot side thermal storage (HTS) medium 21 e.g., a low viscosity liquid
• a cold side thermal storage (CTS) medium 22 e.g., a low viscosity liquid
• FIGs.4 and 5 are schematic pressure and temperature diagrams of the working fluid 20 as it undergoes the charge cycles in FIGs. 2 and 3, respectively, once again simplified in the approximation of no entropy generation.
• the heat exchangers 2 and 4 can be configured as counter-flow heat exchangers (CFXs), where the working fluid flows in one direction and the substance it is exchanging heat with is flowing in the opposite direction.
• CFXs counter-flow heat exchangers
• the temperatures of the working fluid and thermal storage medium flip i.e., the counter-flow heat exchanger can have unity effectiveness.
• the counter-flow heat exchangers 2 and 4 can be designed and/or operated to reduce entropy generation in the heat exchangers to negligible levels compared to entropy generation associated with other system components and/or processes (e.g., compressor and/or turbine entropy generation).
• the system may be operated such that entropy generation in the system is minimized.
• the system may be operated such that entropy generation associated with heat storage units is minimized.
• a temperature difference between fluid elements exchanging heat can be controlled during operation such that entropy generation in hot side and cold side heat storage units is minimized.
• the entropy generated in the hot side and cold side heat storage units is negligible when compared to the entropy generated by the compressor, the turbine, or both the compressor and the turbine.
• entropy generation associated with heat transfer in the heat exchangers 2 and 4 and/or entropy generation associated with operation of the hot side storage unit, the cold side storage unit or both the hot side and cold side storage units can be less than about 50%, less than about 25%, less than about 20%, less than about 15%, less than about 10%, less than about 5%, less than about 4%, less than about 3%, less than about 2%, or less than about 1% of the total entropy generated within the system (e.g., entropy generated by the compressor 1, the hot side heat exchanger 2, the turbine 3, the cold side heat exchanger 4 and/or other components described herein, such as, for example, a recuperator).
• entropy generation can be reduced or minimized if the two substances exchanging heat do so at a local temperature differential ⁇ T ⁇ 0 (i.e., when the temperature difference between any two fluid elements that are in close thermal contact in the heat exchanger is small).
• the temperature differential ⁇ T between any two fluid elements that are in close thermal contact may be less than about 300 Kelvin (K), less than about 200 K , less than about 100 K, less than about 75 K, less than about 50 K, less than about 40 K, less than about 30 K, less than about 20 K, less than about 10 K, less than about 5 K, less than about 3 K, less than about 2 K, or less than about 1 K.
• entropy generation associated with pressure drop can be reduced or minimized by suitable design.
• the heat exchange process can take place at a constant or near-constant pressure.
• a non-negligible pressure drop may be experienced by the working fluid and/or one or more thermal storage media during passage through a heat exchanger.
• Pressure drop in heat exchangers may be controlled (e.g., reduced or minimized) through suitable heat exchanger design.
• the pressure drop across each heat exchanger may be less than about 20% of inlet pressure, less than about 10% of inlet pressure, less than about 5% of inlet pressure, less than about 3% of inlet pressure, less than about 2% of inlet pressure, less than about 1% of inlet pressure, less than about 0.5% of inlet pressure, less than about 0.25% of inlet pressure, or less than about 0.1% of inlet pressure.
• the temperature of the working fluid can either increase (taking heat from the CTS medium 22, corresponding to the charge mode in FIGs.2 and 4) or decrease (giving heat to the CTS medium 22, corresponding to the discharge mode in FIGs. 3 and 5), depending on the temperature of the CTS medium in the heat exchanger relative the temperature of the working fluid.
• the heat addition process in the cold side CFX 4 can take place over a different range of temperatures than the heat removal process in the hot side CFX 2.
• the heat rejection process in the cold side CFX 4 can take place over a different range of temperatures than the heat addition process in the hot side CFX 2.
• At least a portion of the temperature ranges of the hot side and cold side heat exchange processes may overlap during charge, during discharge, or during both charge and discharge.
• the temperatures T0, T1, T0 + and T1 + are so named because T0 + , T1 + are the temperatures achieved at the exit of a compressor with a given compression ratio r, adiabatic efficiency ⁇ c and inlet temperatures of T0, T1 respectively.
• the working fluid 20 can enter the compressor 1 at position 30 at a pressure P and a temperature T (e.g., at T 1 , P 2 ).
• the working fluid passes through the compressor, work W1 is consumed by the compressor to increase the pressure and temperature of the working fluid (e.g., to T 1 + , P 1 ), as indicated by P ⁇ and T ⁇ at position 31.
• the temperature T 1 + of the working fluid exiting the compressor and entering the hot side CFX 2 at position 31 is higher than the temperature of the HTS medium 21 entering the hot side CFX 2 at position 32 from a second hot side thermal storage tank 7 at a temperature T0 + (i.e., T0 + ⁇ T1 + ).
• the working fluid As these two fluids pass in thermal contact with each other in the heat exchanger, the working fluid’s temperature decreases as it moves from position 31 position 34, giving off heat Q1 to the HTS medium, while the temperature of the HTS medium in turn increases as it moves from position 32 to position 33, absorbing heat Q1 from the working fluid.
• the working fluid exits the hot side CFX 2 at position 34 at the temperature T 0 + and the HTS medium exits the hot side CFX 2 at position 33 into a first hot side thermal storage tank 6 at the temperature T1 + .
• the heat exchange process can take place at a constant or near-constant pressure such that the working fluid exits the hot side CFX 2 at position 34 at a lower temperature but same pressure P1, as indicated by P and T ⁇ at position 34.
• the temperature of the HTS medium 21 increases in the hot side CFX 2, while its pressure can remain constant or near-constant.
• the working fluid 20 undergoes expansion in the turbine 3 before exiting the turbine at position 35.
• the pressure and temperature of the working fluid decrease (e.g., to T0, P2), as indicated by P ⁇ and T ⁇ at position 35.
• the magnitude of work W 2 generated by the turbine depends on the enthalpy of the working fluid entering the turbine and the degree of expansion.
• heat is removed from the working fluid between positions 31 and 34 (in the hot side CFX 2) and the working fluid is expanded back to the pressure at which it initially entered the compressor at position 30 (e.g., P 2 ).
• the compression ratio (e.g., P 1 /P 2 ) in the compressor 1 being equal to the expansion ratio in the turbine 3, and the enthalpy of the gas entering the turbine being lower than the enthalpy of the gas exiting the compressor, the work W 2 generated by the turbine 3 is smaller than the work W 1 consumed by the compressor 1 (i.e., W2 ⁇ W1).
• the CTS medium 22 enters the cold side CFX 4 at position 36 from a first cold side thermal storage tank 8 at the temperature T 1 and exits the cold side CFX 4 at position 37 into a second cold side thermal storage tank 9 at the temperature T0, while the working fluid 20 enters the cold side CFX 4 at position 35 at the temperature T 0 and exits the cold side CFX 4 at position 30 at the temperature T1.
• the heat exchange process can take place at a constant or near-constant pressure such that the working fluid exits the cold side CFX 2 at position 30 at a higher temperature but same pressure P2, as indicated by P and T ⁇ at position 30.
• the temperature of the CTS medium 22 decreases in the cold side CFX 2, while its pressure can remain constant or near-constant.
• the heat Q2 is removed from the CTS medium and the heat Q1 is added to the HTS medium, wherein Q 1 > Q 2 .
• a net amount of work W 1 - W 2 is consumed, since the work W1 used by the compressor is greater than the work W2 generated by the turbine.
• a device that consumes work while moving heat from a cold body or thermal storage medium to a hot body or thermal storage medium is a heat pump; thus, the pumped thermal system in the charge mode operates as a heat pump.
• the temperature at which the HTS medium enters the hot side CFX 2 at position 32 is T 1 + instead of T 0 +
• the temperature of the CTS medium entering the cold side CFX 4 at position 36 is T0 instead of T1.
• the working fluid enters the compressor at position 30 at T0 and P2, exits the compressor at position 31 at T0 + ⁇ T1 + and P1, absorbs heat from the HTS medium in the hot side CFX 2, enters the turbine 3 at position 34 at T1 + and P1, exits the turbine at position 35 at T1 > T0 and P2, and finally rejects heat to the CTS medium in the cold side CFX 4, returning to its initial state at position 30 at T 0 and P 2 .
• the HTS medium at temperature T1 + can be stored in a first hot side thermal storage tank 6, the HTS medium at temperature T 0 + can be stored in a second hot side thermal storage tank 7, the CTS medium at temperature T1 can be stored in a first cold side thermal storage tank 8, and the CTS medium at temperature T0 can be stored in a second cold side thermal storage tank 9 during both charge and discharge modes.
• the inlet temperature of the HTS medium at position 32 can be switched between T1 + and T0 + by switching between tanks 6 and 7, respectively.
• the inlet temperature of the CTS medium at position 36 can be switched between T1 and T0 by switching between tanks 8 and 9, respectively.
• Switching between tanks can be achieved by including a valve or a system of valves (e.g., valve systems 12 and 13 in FIG.7) for switching connections between the hot side heat exchanger 2 and the hot side tanks 6 and 7, and/or between the cold side heat exchanger 4 and the cold side tanks 8 and 9 as needed for the charge and discharge modes.
• connections may be switched on the working fluid side instead, while the connections of storage tanks 6, 7, 8 and 9 to the heat exchangers 2 and 4 remain static.
• flow paths and connections to the heat exchangers may depend on the design (e.g., shell-and-tube) of each heat exchanger.
• one or more valves can be used to switch the direction of both the working fluid and the heat storage medium through the counter-flow heat exchanger on charge and discharge. Such configurations may be used, for example, due to high thermal storage capacities of the heat exchanger component, to decrease or eliminate temperature transients, or a combination thereof.
• one or more valves can be used to switch the direction of only the working fluid, while the direction of the HTS or CTS can be changed by changing the direction of pumping, thereby maintaining the counter-flow configuration.
• different valve configurations may be used for the HTS and the CTS. Further, any combination of the valve configurations herein may be used.
• the system may be configured to operate using different valve configurations in different situations (e.g., depending on system operating conditions).
• the working fluid 20 can enter the compressor 1 at position 30 at a pressure P and a temperature T (e.g., at T 0 , P 2 ).
• T e.g., at T 0 , P 2
• work W1 is consumed by the compressor to increase the pressure and temperature of the working fluid (e.g., to T0 + , P1), as indicated by P ⁇ and T ⁇ at position 31.
• the temperature T 0 + of the working fluid exiting the compressor and entering the hot side CFX 2 at position 31 is lower than the temperature of the HTS medium 21 entering the hot side CFX 2 at position 32 from a first hot side thermal storage tank 6 at a temperature T1 + (i.e., T0 + ⁇ T1 + ).
• T1 + i.e., T0 + ⁇ T1 +
• the working fluid increases as it moves from position 31 position 34, absorbing heat Q 1 from the HTS medium, while the temperature of the HTS medium in turn decreases as it moves from position 32 to position 33, giving off heat Q1 to the working fluid.
• the working fluid exits the hot side CFX 2 at position 34 at the temperature T1 + and the HTS medium exits the hot side CFX 2 at position 33 into the second hot side thermal storage tank 7 at the temperature T0 + .
• the heat exchange process can take place at a constant or near-constant pressure such that the working fluid exits the hot side CFX 2 at position 34 at a higher temperature but same pressure P1, as indicated by P and T ⁇ at position 34.
• the temperature of the HTS medium 21 decreases in the hot side CFX 2, while its pressure can remain constant or near-constant.
• the working fluid 20 undergoes expansion in the turbine 3 before exiting the turbine at position 35.
• the pressure and temperature of the working fluid decrease (e.g., to T 1 , P 2 ), as indicated by and at position 35.
• the magnitude of work W2 generated by the turbine depends on the enthalpy of the working fluid entering the turbine and the degree of expansion.
• heat is added to the working fluid between positions 31 and 34 (in the hot side CFX 2) and the working fluid is expanded back to the pressure at which it initially entered the compressor at position 30 (e.g., P2).
• the compression ratio (e.g., P1/P2) in the compressor 1 being equal to the expansion ratio in the turbine 3, and the enthalpy of the gas entering the turbine being higher than the enthalpy of the gas exiting the compressor, the work W2 generated by the turbine 3 is greater than the work W1 consumed by the compressor 1 (i.e., W 2 > W 1 ).
• the temperature T1 at which the working fluid exits the turbine at position 35 is higher than the temperature T 0 at which the working fluid initially entered the compressor at position 30.
• heat Q2 is rejected by the working fluid to the CTS medium 22 in the cold side CFX 4 between positions 35 and 30 (i.e., between the turbine 3 and the compressor 1).
• the CTS medium 22 enters the cold side CFX 4 at position 36 from a second cold side thermal storage tank 9 at the temperature T0 and exits the cold side CFX 4 at position 37 into a first cold side thermal storage tank 8 at the temperature T 1 , while the working fluid 20 enters the cold side CFX 4 at position 35 at the temperature T1 and exits the cold side CFX 4 at position 30 at the temperature T 0 .
• the heat exchange process can take place at a constant or near- constant pressure such that the working fluid exits the cold side CFX 2 at position 30 at a higher temperature but same pressure P2, as indicated by P and T ⁇ at position 30.
• the temperature of the CTS medium 22 increases in the cold side CFX 2, while its pressure can remain constant or near-constant.
• the heat Q2 is added to the CTS medium and the heat Q1 is removed from the HTS medium, wherein Q1 > Q2.
• a net amount of work W2 - W1 is generated, since the work W1 used by the compressor is smaller than the work W2 generated by the turbine.
• FIG. 6 is a simplified schematic perspective view of a closed working fluid system in the pumped thermal system in FIGs. 2-3.
• the working fluid 20 (contained inside tubing) circulates clockwise between the compressor 1, the hot side heat exchanger 2, the turbine 3, and the cold side heat exchanger 4.
• the compressor 1 and the turbine 3 can be ganged on a common mechanical shaft 10 such that they rotate together. In some implementations, the compressor 1 and the turbine 3 can have separate mechanical shafts.
• a motor/generator 11 (e.g., including a synchronous motor - synchronous generator converter on a single common shaft) provides power to and from the turbomachinery.
• the compressor, the turbine and the motor/generator are all located on a common shaft.
• Pipes at positions 32 and 33 transfer hot side thermal storage fluid to and from the hot side heat exchanger 2, respectively.
• Pipes at positions 36 and 37 transfer cold side thermal storage fluid to and from the cold side heat exchanger 4, respectively.
• the system of FIG. 6 is illustrated as comprising a compressor 1 and turbine 3, the system can include one or more compressors and one or more turbines, which may operate, for example, in a parallel configuration, or alternatively in a series configuration or in a combination of parallel and series configurations.
• a system of compressors or turbines may be assembled such that a given compression ratio is achieved.
• different compression ratios e.g., on charge and discharge
• the working fluid is directed to a plurality of compressors and/or a plurality of turbines.
• the compressor and/or turbine may have temperature dependent compression ratios. Arrangement and/or operation of the turbomachinery and/or other elements of the system may be adjusted in accordance with the temperature dependence (e.g., to optimize performance).
• FIG. 7 is a simplified schematic perspective view of the pumped thermal system in FIGs.2-3 with hot side and cold side storage tanks and a closed cycle working fluid system.
• the HTS medium is a molten salt and the CTS medium is a low temperature liquid.
• One, two or more first hot side tanks 6 (at the temperature T1 + ) and one, two or more second hot side tanks 7 (at the temperature T0 + ), both for holding the HTS medium, are in fluid communication with a valve 13 configured to transfer the HTS medium to and from the hot side heat exchanger 2.
• the thermal energy reservoirs or storage tanks may be thermally insulated tanks that can hold a suitable quantity of the relevant thermal storage medium (e.g., heat storage fluid).
• the storage tanks may allow for relatively compact storage of large amounts of thermal energy.
• the hot side tanks 6 and/or 7 can have a diameter of about 80 meters, while the cold side tanks 8 and/or 9 can have a diameter of about 60 meters.
• each (i.e., hot side or cold side) thermal storage for a 1 GW plant operating for 12 hours can be about 20 medium-sized oil refinery tanks.
• a third set of tanks containing storage media at intermediate temperatures between the other tanks may be included on the hot side and/or the cold side.
• a third storage or transfer tank (or set of tanks) at a temperature intermediate to the temperatures of a first tank (or set of tanks) and a second tank (or set of tanks) may be provided.
• a set of valves may be provided for switching the storage media between the different tanks and heat exchangers.
• thermal media may be directed to different sets of tanks after exiting the heat exchangers depending on operating conditions and/or cycle being used.
• one or more additional sets of storage tanks at different temperatures may be added on the hot side and/or the cold side.
• the storage tanks e.g., hot side tanks comprising hot side thermal storage medium and/or cold side tanks comprising cold side thermal storage medium
• the storage tanks may operate at ambient pressure.
• thermal energy storage at ambient pressure can provide safety benefits.
• the storage tanks may operate at elevated pressures, such as, for example, at a pressure of at least about 2 atm, at least about 5 atm, at least about 10 atm, at least about 20 atm, or more.
• the storage tanks may operate at reduced pressures, such as, for example, at a pressure of at most about 0.9 atm, at most about 0.7 atm, at most about 0.5 atm, at most about 0.3 atm, at most about 0.1 atm, at most about 0.01 atm, at most about 0.001 atm, or less.
• the storage tanks can be sealed from the surrounding atmosphere.
• the storage tanks may not be sealed.
• the tanks may include one or more pressure regulation or relief systems (e.g., a valve for safety or system optimization).
• the first hot side tank(s) 6 (at the temperature T1 + ) can contain HTS medium at a higher temperature than the second hot side tank(s) 7 (at the temperature T0 + ), and the first cold side tank(s) 8 (at the temperature T1) can contain CTS medium at a higher temperature than the second cold side tank(s) 9 (at the temperature T 0 ).
• HTS medium in the first (higher temperature) hot side tank(s) 6 and/or CTS medium in the second (lower temperature) cold side tank(s) 9 can be replenished.
• HTS medium in the first (higher temperature) hot side tank(s) 6 and/or CTS medium in the second (lower temperature) cold side tank(s) 9 can be consumed.
• two of the four storage tanks 6, 7, 8 and 9 are feeding thermal storage medium to the heat exchangers 2 and 4 at the inlets 32 and 36, respectively, and the other two tanks are receiving thermal storage medium from the heat exchangers 2 and 4 from the exits 33 and 37, respectively.
• the feed tanks can contain a storage medium at a given temperature due to prior operating conditions, while the receiving tanks’ temperatures can depend on current system operation (e.g., operating parameters, loads and/or power input).
• the receiving tank temperatures may be set by the Brayton cycle conditions. In some cases, the receiving tank temperatures may deviate from desired values due to deviations from predetermined cycle conditions (e.g., variation of absolute pressure in response to system demand) and/or due to entropy generation within the system. In some cases (e.g., due to entropy generation), at least one of the four tank temperatures can be higher than desired. In some implementations, a radiator can be used to reject or dissipate this waste heat to the environment. In some cases, heat rejection to the environment may be enhanced (e.g., using evaporative cooling etc.). The waste heat generated during operation of the pumped thermal systems herein can also be utilized for other purposes.
• predetermined cycle conditions e.g., variation of absolute pressure in response to system demand
• entropy generation e.g., due to entropy generation
• at least one of the four tank temperatures can be higher than desired.
• a radiator can be used to reject or dissipate this waste heat to the environment.
• waste heat from one part of the system may be used elsewhere in the system.
• waste heat may be provided to an external process or system, such as, for example, a manufacturing process requiring low grade heat, commercial or residential heating, thermal desalination, commercial drying operations etc.
• Components of pumped thermal systems of the disclosure may exhibit non-ideal performance, leading to losses and/or inefficiencies.
• the major losses in the system may occur due to inefficiencies of the turbomachinery (e.g., compressor and turbine) and the heat exchangers.
• the losses due to the heat exchangers may be small compared to the losses due to the turbomachinery.
• the losses due to the heat exchangers can be reduced to near zero with suitable design and expense.
• the compression ratio i.e., ratio of the higher pressure to the lower pressure
• the polytropic efficiencies are related to the adiabatic efficiencies ⁇ c and ⁇ t by the equations [0109]
• pumped thermal cycles of the disclosure can follow identical paths in both charge and discharge cycles (e.g., as shown in FIGs. 4 and 5).
• ⁇ c ⁇ 1 and/or ⁇ t ⁇ 1 compression in the compressor can lead to a greater temperature increase than in the ideal case for the same compression ratio, and expansion in the turbine can lead to a smaller temperature decrease than in the ideal case.
• the polytropic efficiency of the compressor ⁇ ⁇ may be at least about 0.3, at least about 0.5, at least about 0.6, at least about 0.7, at least about 0.75, at least about 0.8, at least about 0.85, at least about 0.9, at least about 0.91, at least about 0.92, at least about 0.93, at least about 0.96, or more.
• the polytropic efficiency of the compressor ⁇ ⁇ may be at least about 0.3, at least about 0.5, at least about 0.6, at least about 0.7, at least about 0.75, at least about 0.8, at least about 0.85, at least about 0.9, at least about 0.91, at least about 0.92, at least about 0.93, at least about 0.96, at least about 0.97 or more.
• T0 + , T1 + were previously defined as the temperatures achieved at the exit of a compressor with a given compression ratio r, adiabatic efficiency ⁇ c and inlet temperatures of T0, T1 respectively. In some examples, these four temperatures are related by the equation [0112] FIG.
• the system can include 4 heat storage tanks.
• the working fluid at T 0 and P 2 can exchange heat with a CTS medium in the cold side heat exchanger 4, whereby its temperature can increase to T 1 (assuming negligible pressure drop, its pressure can remain P 2 ).
• the temperature and pressure of the working fluid can increase from The working fluid can then exchange heat with an HTS medium in the hot side heat exchanger 2, such that its temperature can decrease (at constant pressure P1, assuming negligible pressure drop).
• the temperatures are related by the relation
• the temperature may be incorporated into charge cycles o f the disclosure by first heat exchanging the working fluid with the HTS medium from o f ollowed by further cooling the working fluid from as illustrated by section 38 of the cycle in FIG.8.
• the working fluid at T 1 and P 2 can exchange heat with a CTS medium in the cold side heat exchanger 4, whereby its temperature can decrease to T0 (assuming negligible pressure drop, its pressure can remain P 2 ).
• the temperature and pressure of the working fluid can increase from T0, P2 to T0 + , P1.
• the working fluid can then exchange heat with an HTS medium in the hot side heat exchanger 2, such that its temperature can increase (at constant pressure P 1 , assuming negligible pressure drop).
• Working fluid entering the turbine may not exit the turbine at the temperature T1 as in the charge cycle, but may instead exit at a temperature where, in some examples, In some examples, is the temperature at which the working fluid exits the outlet of a turbine with adiabatic efficiency and compression ratio r after entering the inlet of the turbine at the temperature [0115]
• the temperature may be incorporated into the discharge cycles of the disclosure by first cooling the working fluid exiting the turbine at as illustrated by section 39 of the cycle in FIG.9, followed by heat exchanging the working fluid with the CTS medium from T 1 to T 0 .
• the charge and discharge cycles may be closed by additional heat rejection operations in sections 38 (between and 39 (between respectively.
• closing the cycles through heat rejection in sections of the cycles where the working fluid can reject heat to ambient at low cost may eliminate the need for additional heat input into the system.
• the sections of the cycles where the working fluid can reject heat to ambient may be limited to sections where the temperature of the working fluid is high enough above ambient temperature for ambient cooling to be feasible.
• heat may be rejected to the environment in sections 38 and/or 39.
• heat may be rejected using one or more working fluid to air radiators, intermediate water cooling, or a number of other methods.
• heat rejected in sections 38 and/or 39 may be used for another useful purpose, such as, for example, cogeneration, thermal desalination and/or other examples described herein.
• the cycles may be closed by varying the compression ratios between the charge and discharge cycles, as shown, for example, in FIG.10.
• the ability to vary compression ratio on charge and discharge may be implemented, for example, by varying the rotation speed of the compressor and/or turbine, by variable stator pressure control, by bypassing a subset of the compression or expansion stages on charge or discharge by the use of valves, or by using dedicated compressor/turbine pairs for charge and discharge mode.
• the compression ratio in the discharge cycle in FIG.9 can be changed such that heat rejection in section is 39 is not used, and only heat rejection in section 38 in the charge cycle is used.
• Varying the compression ratio may allow heat (i.e., entropy) to be rejected at a lower temperature, thereby increasing overall roundtrip efficiency.
• the compression ratio on charge, rC can be set such that nd on discharge
• the compression ratio rD can be set such that
• the upper temperatures ⁇ and T 1 can be identical on charge and discharge and no heat removal may be needed in this portion (also “leg” herein) of the cycle.
• the temperature T0 + on charge e.g., and the temperature T0 + on discharge can be dissimilar and heat may be rejected (also “dissipated” or “dumped” herein) to the environment between the temperatures n an implementation where only the storage media exchange heat with the environment, a heat rejection device (e.g., devices 55 and 56 shown in FIG. 16) can be used to lower the temperature of the CTS from to between discharge and charge.
• a heat rejection device e.g., devices 55 and 56 shown in FIG. 16
• FIG. 10 shows an example of a cycle with variable compression ratios.
• the compression ratio can be higher on discharge (when work is produced by the system) than on charge (when work is consumed by the system), which may increase an overall round trip efficiency of the system.
• the compression ratio may be varied between charge and discharge such that the heat dissipation to the environment needed for closing the cycle on both charge and discharge occurs between the temperatures the temperature of the working fluid before it enters the turbine during the charge cycle) and the temperature of the working fluid as it exits the compressor on discharge) and not above the temperature T 1 (the temperature of the working fluid before it enters the compressor on charge and/or exits the turbine on discharge).
• none of the heat is rejected at a temperature above the lowest temperature of the HTS medium.
• a given amount of heat QH can be transferred using a given quantity of work W in heat pump (charge) mode, and the same Q H can be used in heat engine (discharge) mode to produce the same work W, leading to a unity (i.e., 100%) roundtrip efficiency.
• charge heat pump
• discharge heat engine
• roundtrip efficiencies of pumped thermal systems may be limited by how much the components deviate from ideal performance.
• the roundtrip efficiency of a pumped thermal system may be defined as an approximation of ideal heat exchange, the roundtrip efficiency can be derived by considering the net work output during the discharge cycle, and the net work input during the charge cycle, quations for work and temperature given above.
• Roundtrip efficiencies may be calculated for different configurations of pumped thermal systems (e.g., for different classes of thermal storage media) based on turbomachinery component efficiencies, ⁇ c and ⁇ t .
• FIG. 11 shows roundtrip efficiency contours for a water/salt system, such as, for example, the water/salt system in FIGs.
• Exemplary roundtrip efficiency contours at values of ⁇ 0 ⁇ 1 ⁇ of 10%, 20%, 30%, 40%, 50%, 60%, 70%, 80% and 90% are shown as a function of component efficiencies ⁇ c and ⁇ t on the x- and y-axes, respectively.
• the symbols represent the approximate range of present large turbomachinery adiabatic efficiency values.
• recuperation As discussed in detail elsewhere herein, using hexane, heptane and/or another CTS medium capable of low temperature operation may result in significant improvements of system efficiency.
• Pumped thermal storage cycles with recuperation [0125] Another aspect of the disclosure is directed to pumped thermal systems with recuperation. In some situations, the terms regeneration and recuperation can be used interchangeably, although they may have different meanings. As used herein, the terms “recuperation” and “recuperator” generally refer to the presence of one or more additional heat exchangers where the working fluid exchanges heat with itself during different segments of a thermodynamic cycle through continuous heat exchange without intermediate thermal storage. The roundtrip efficiency of pumped thermal systems may be substantially improved if the allowable temperature ranges of the storage materials can be extended.
• this may be accomplished by choosing a material or medium on the cold side that can go to temperatures below 273 K (0°C).
• a CTS medium e.g., hexane
• ⁇ + (i.e., the lowest temperature of the working fluid in the hot side heat exchanger) at some (e.g., modest) compression ratios may be below the freezing point of the molten salt, making the molten salt unviable as the HTS medium.
• FIG. 13 is a schematic flow diagram of working fluid and heat storage media of a pumped thermal system in a charge/heat pump mode with a gas-gas heat exchanger 5 for the working fluid.
• the use of the gas-gas heat exchanger can enable use of colder heat storage medium on the cold side of the system.
• the working fluid can be air.
• the working fluid can be dry air.
• the working fluid can be nitrogen.
• the working fluid can be argon.
• the working fluid can be a mixture of primarily argon mixed with another gas such as helium.
• the working fluid may comprise at least about 50% argon, at least about 60% argon, at least about 70% argon, at least about 80% argon, at least about 90% argon, or about 100% argon, with balance helium.
• the CTS medium can be hexane or heptane and the HTS medium can be molten salt.
• the system can include four heat storage tanks.
• the working fluid enters the compressor at T1 and P2, exits the compressor at T1 + and P1, rejects heat Q1 to the HTS medium 21 in the hot side CFX 2, exiting the hot side CFX 2 at T 1 and P 1 , rejects heat Q recup (also “Qregen” herein, as shown, for example, in the accompanying drawings) to the cold (low pressure) side working fluid in the heat exchanger or recuperator 5, exits the recuperator 5 at T0 + and P1, rejects heat to the environment (or other heat sink) in section 38 (e.g., a radiator), enters the turbine 3 at nd P1, exits the turbine at T0 and P2, absorbs heat Q2 from the CTS medium 22 in the cold side CFX 4, exiting the cold side CFX 4 at T 0 + and P 2 , absorbs heat Qrecup from the hot (high pressure) side working fluid in the heat exchanger
• FIG. 14 is a schematic flow diagram of working fluid and heat storage media of the pumped thermal system in FIG.13 in a discharge/heat engine mode.
• the use of the gas- gas heat exchanger can enable use of colder heat storage fluid (CTS) and/or colder working fluid on the cold side of the system.
• a cold side storage medium e.g., liquid hexane
• the CTS medium can be hexane or heptane and the HTS medium can be molten salt, and the system may include 4 heat storage tanks.
• the working fluid enters the compressor at T 0 and P2, exits the compressor at T0 + and P1, absorbs heat Qrecup from the cold (low pressure) side working fluid in the heat exchanger or recuperator 5, exits the recuperator 5 at T1 and P1, absorbs heat Q 1 from the HTS medium 21 in the hot side CFX 2, exiting the hot side CFX 2 at T1 + and P1, enters the turbine 3 at T1 + and P1, exits the turbine at nd P2, rejects heat to the environment (or other heat sink) in section 39 (e.g., a radiator), rejects heat Q recup to the hot (high pressure) side working fluid in the heat exchanger or recuperator 5, enters the cold side CFX 4 at T 0 + and P 2 , rejects heat Q 2 to the CTS medium 22 in
• the charge cycle remains the same as in FIGs. 13 and 17, except that the working fluid exits the recuperator 5 at and P1 (instead of at T 0 + and P 1 as in FIGs. 13 and 17), enters the turbine 3 at exits the turbine at T 0 and P2, absorbs heat Q2 from the CTS medium 22 having a temperature (instead of at T0 + as in FIGs. 13 and 17) in the cold side CFX 4, and exits the cold side CFX 4 at and P 2 (instead of at T0 + and P2 as in FIG. 13) before reentering the recuperator 5.
• the heat between temperatures is no longer rejected from the working fluid to the environment directly (as in section 38 in FIGs.13 and 17).
• the discharge cycle remains the same as in FIGs. 14 and 8B, except that the temperature of the HTS medium being deposited in tank 7 is changed.
• the working fluid exits the recuperator 5 at and P1 (instead of at T1 and P1 as in FIGs. 14 and 8B) and absorbs heat Q 1 from the HTS medium 21 in the hot side CFX 2.
• the HTS medium exits the hot side CFX 2 having a temperature (instead of at T 1 as in FIGs. 14 and 18).
• the working fluid then exits the hot side CFX 2 at T1 + and P1, enters the turbine 3 at T1 + and P1, and exits the turbine at ⁇ - ⁇ and P 2 before reentering the recuperator 5.
• the hot side and cold side storage media may be cooled at an arbitrarily slow rate (e.g., by radiating away or by other means of giving off the heat to the environment).
• heat can be rejected from the CTS medium to the environment by circulating the CTS medium in the tank 8 in a heat rejection device 55 that can absorb heat from the CTS medium and reject heat to the environment until the CTS medium cools from the temperature ⁇ + , to the temperature ⁇ - + , .
• the heat rejection device 55 can be, for example, a radiator, a thermal bath containing a substance such as water or salt water, or a device immersed in a natural body of water such as a lake, river or ocean.
• the heat rejection device 55 can also be an air cooling apparatus, or a series of pipes which are thermally connected to a solid reservoir (e.g., pipes embedded in the ground).
• heat can be rejected from the HTS medium to the environment by circulating the HTS in the tank 7 in a heat rejection device 56 that can absorb heat from the HTS medium and reject heat to the environment until the HTS medium cools from the temperature ⁇ - ⁇ to the temperature T 1 .
• the heat rejection device 56 can be, for example, a radiator, a thermal bath containing a substance such as water or salt water, or a device immersed in a natural body of water such as a lake, river or ocean.
• the heat rejection device 56 can also be an air cooling apparatus or a series of pipes which are thermally connected to a solid reservoir (e.g., pipes embedded in the ground).
• rejecting heat to ambient through the use of the thermal storage media may be used in conjunction with the variable compression ratio charge and/or discharge cycles described, for example, in FIG.10. In this system, only the CTS medium may exchange heat with ambient.
• Such a system can also be implemented with a recuperator to extend the temperature ranges of the HTS and CTS media in the cycles.
• three separate cold side storage tanks at respective temperatures ⁇ + , ⁇ - + , and ⁇ + may be used (e.g., an extra tank may be used in addition to the tanks 8 and 9).
• heat from the working fluid exiting the recuperator 5 may be transferred to the CTS medium in the ⁇ + , - tank.
• the CTS medium may be cooled in/by, for example, the heat rejection device 55 prior to entering the ⁇ - + , -tank.
• three separate hot side storage tanks at respective temperatures ⁇ ⁇ , ⁇ - and ⁇ ⁇ may be used (e.g., an extra tank may be used in addition to the tanks 6 and 7).
• heat from the working fluid exiting the recuperator 5 may be transferred to the HTS medium in the ⁇ - ⁇ -tank.
• the HTS medium may be cooled in/by, for example, the heat rejection device 56 prior to entering the ⁇ ⁇ -tank. Heat rejection to the environment in such a manner may present several advantages.
• the HTS and CTS media may instead reject heat over extended time periods, thus reducing the cost of the cooling infrastructure.
• it may allow the decision regarding when heat is rejected to the environment to be delayed such that heat exchange to ambient may be performed when temperature (e.g., the ambient temperature) is most favorable.
• heat rejection on the hot side (high pressure) side of the closed charge cycle can take place in three operations (heat exchange with the HTS medium, followed by recuperation, followed by heat rejection to the environment), and heat rejection on the cold side (low pressure) side of the closed discharge cycle can take place in three operations (heat rejection to the environment, followed by recuperation, followed by heat exchange with the CTS medium).
• recuperation may be implemented using the heat exchanger 5 for direct transfer of heat between the working fluid on the high pressure side and the working fluid on the low pressure side.
• an additional pair (or plurality) of heat exchangers together with an additional heat transfer medium or fluid may be used to achieve recuperation.
• an additional heat exchanger may be added in series with the cold side heat exchanger and an additional heat exchanger may be added in series with the hot side heat exchanger.
• the additional heat transfer medium may circulate between the two additional heat exchangers in a closed loop.
• one or more additional heat exchangers may be placed elsewhere in the system to facilitate recuperation. Further, one or more additional heat transfer media or mixtures thereof may be used.
• the one or more additional heat transfer media fluids may be in fluid or thermal communication with one or more other components, such as, for example, a cooling tower or a radiator.
• hexane or heptane can be used as a CTS medium
• nitrate salt can be used as an HTS medium.
• the operating temperatures of the pumped thermal storage cycles may be limited by the melting point of hexane (178 K or -95°C) at T0 and by the melting point of the nitrate (494 K or 221°C) at T1.
• recuperation may enable the compression ratio to be reduced. In some cases, reducing the compression ratio may result in reduced compressor and turbine losses.
• the compression ratio may be at least about 1.2, at least about 1.5, at least about 2, at least about 2.5, at least about 3, at least about 3.5, at least about 4, at least about 4.5, at least about 5, at least about 6, at least about 8, at least about 10, at least about 15, at least about 20, at least about 30, or more.
• ⁇ + may be at least about 30 K, at least about 50 K, at least about 80 K, at least about 100 K, at least about 120 K, at least about 140 K, at least about 160 K, at least about 180 K, at least about 200 K, at least about 220 K, at least about 240 K, at least about 260 K, or at least about 280 K.
• ⁇ + may be at least about 220 K, at least about 240 K, at least about 260 K, at least about 280 K, at least about 300 K, at least about 320 K, at least about 340 K, at least about 360 K, at least about 380 K, at least about 400 K, or more.
• the temperatures ⁇ + and ⁇ + can be constrained by the ability to reject excess heat to the environment at ambient temperature.
• the temperatures ⁇ + and ⁇ + can be constrained by the operating temperatures of the CTS (e.g., a phase transition temperature).
• the temperatures ⁇ + and ⁇ + can be constrained by the compression ratio being used.
• ⁇ may be at least about 350K, at least about 400 K, at least about 440 K, at least about 480 K, at least about 520 K, at least about 560 K, at least about 600 K, at least about 640 K, at least about 680 K, at least about 720 K, at least about 760 K, at least about 800 K, at least about 840 K, at least about 880 K, at least about 920 K, at least about 960 K, at least about 1000 K, at least about 1100 K, at least about 1200 K, at least about 1300 K, at least about 1400 K, or more.
• ⁇ ⁇ may be at least about 480 K, at least about 520 K, at least about 560 K, at least about 600 K, at least about 640 K, at least about 680 K, at least about 720 K, at least about 760 K, at least about 800 K, at least about 840 K, at least about 880 K, at least about 920 K, at least about 960 K, at least about 1000 K, at least about 1100 K, at least about 1200 K, at least about 1300 K, at least about 1400 K, at least about 1500 K, at least about 1600 K, at least about 1700 K, or more.
• the temperatures ⁇ ⁇ and ⁇ ⁇ can be constrained by the operating temperatures of the HTS. In some cases.
• the temperatures ⁇ ⁇ and ⁇ ⁇ can be constrained by the thermal limits of the metals and materials being used in the system.
• a conventional solar salt can have a recommended temperature range of approximately 560-840 K.
• Various system improvements such as, for example, increased roundtrip efficiency, increased power and increased storage capacity may be realized as available materials, metallurgy and storage materials improve over time and enable different temperature ranges to be achieved. Any description of the temperatures ⁇ ⁇ herein may apply to any system or method of the disclosure.
• the roundtrip efficiency ⁇ store (e.g., electricity storage efficiency) with and/or without recuperation can be at least about 5%, at least about 10%, at least about 15%, at least about 20%, at least about 25%, at least about 30%, at least about 35%, at least about 40%, at least about 45%, at least about 50%, at least about 55%, at least about 60%, at least about 65%, at least about 70%, at least about 75%, at least about 80%, at least about 85%, at least about 90%, or at least about 95%.
• At least a portion of heat transfer in the system (e.g., heat transfer to and from the working fluid) during a charge and/or discharge cycle includes heat transfer with the environment (e.g., heat transfer in sections 38 and 39).
• the remainder of the heat transfer in the system can occur through thermal communication with thermal storage media (e.g., thermal storage media 21 and 22), through heat transfer in the recuperator 5 and/or through various heat transfer processes within system boundaries (i.e., not with the surrounding environment).
• the environment may refer to gaseous or liquid reservoirs surrounding the system (e.g., air, water), any system or medium capable of exchanging thermal energy with the system (e.g., another thermodynamic cycle or system, heating/cooling systems, etc.), or any combination thereof.
• heat transferred through thermal communication with the heat storage media can be at least about 25%, at least about 50%, at least about 60%, at least about 70%, at least about 80%, or at least about 90% of all heat transferred in the system.
• heat transferred through heat transfer in the recuperator can be at least about 5%, at least about 10%, at least about 15%, at least about 20%, at least about 25%, at least about 50%, or at least about 75% of all heat transferred in the system.
• heat transferred through thermal communication with the heat storage media and through heat transfer in the recuperator can be at least about 25%, at least about 50%, at least about 60%, at least about 70%, at least about 80%, at least about 90%, or even about 100% of all heat transferred in the system.
• heat transferred through heat transfer with the environment can be less than about 5%, less than about 10%, less than about 15%, less than about 20%, less than about 30%, less than about 40%, less than about 50%, less than about 60%, less than about 70%, less than about 80%, less than about 90%, less than about 100%, or even 100% of all heat transferred in the system.
• all heat transfer in the system may be with the thermal storage media (e.g., the CTS and HTS media), and only the thermal storage media may conduct heat transfer with the environment.
• Pumped thermal cycles of the disclosure e.g., the cycles in FIGs. 13 and 14
• a valving system may be used such that the different cycles of the system can be interchanged while maintaining the same or nearly the same temperature profile across at least one, across a subset or across all of counter-flow heat exchangers in the system.
• the valving may be configured such that the working fluid can pass through the heat exchangers in opposite flow directions on charge and discharge and flow directions of the HTS and CTS media are reversed by reversing the direction of the pumps.
• the system with a recuperator may have a different compression and/or expansion ratio on charge and discharge. This may then involve heat rejection at only one or both of the heat rejection locations 38 and 39 as shown in Figure 5C along the lines described above.
• FIG. 19 is a schematic flow diagram of hot side recharging in a pumped heat cycle in solar mode with heating of a solar salt solely by solar power.
• the system can comprise a solar heater for heating the hot side heat storage.
• the HTS medium 21 in the second hot thermal storage tank 7 of a discharge cycle can be recharged within element 17 using heating provided by solar radiation.
• the HTS medium e.g., molten salt
• the HTS medium can be heated by solar heating from the temperature T 1 in the second hot thermal storage tank 7 to the temperature T1 + in the first hot thermal storage tank 6.
• a concentrating solar facility may be utilized for providing heat.
• the concentrating solar facility may include one or more components for achieving high solar concentrating efficiency, including, for example, high-performance actuators (e.g., adaptive fluidic actuators manufactured from polymers), mutiplexing control system, dense heliostat layout etc.
• the heat provided for heating the HTS medium e.g., in the element 17
• FIG. 20 is a schematic flow diagram of a pumped thermal system discharge cycle that can be coupled with external heat input (e.g., solar, combustion) with heat rejection to ambient.
• Such a discharge cycle may be used, for example, in situations where the capacity for hot side recharging (e.g., using solar heating, waste heat or combustion) is greater than the capacity for cold side recharging.
• Solar heat may be used to charge the HTS medium 21 in the hot side storage tanks from ⁇ ⁇ to ⁇ ⁇ , , as described elsewhere herein.
• the discharge cycle can operate similarly to the discharge cycle in FIG. 3, but after exiting the turbine 3, the working fluid 20 can proceed to the cold side CFX 4 heat exchanger 4 where it exchanges heat with an intermediate thermal storage (ITS) medium 61 having a lower temperature T0 at or near ambient temperature.
• ITS intermediate thermal storage
• the ITS medium 61 enters the cold side CFX 4 from a second intermediate thermal storage tank 59 at the temperature T0 (e.g., ambient temperature) and exits the cold side CFX 4 into a first intermediate thermal storage tank 60 at the temperature , while the working fluid 20 enters the cold side CFX 4 at the temperature ⁇ - ⁇ and exits the cold side CFX 4 at the temperature T0.
• T0 e.g., ambient temperature
• the working fluid enters the compressor 1 at T0 and P2, exits the compressor at T 0 + and P 1 , absorbs heat Q 1 from the HTS medium 21 in the hot side CFX 2, exits the hot side CFX 2 at ⁇ , ⁇ and P1, enters the turbine 3 at and P1, exits the turbine at a nd P2, rejects heat Q2 from the ITS medium 61 in the cold side CFX 4, and exits the cold side CFX 4 at T0 and P2, returning to its initial state before entering the compressor.
• the ITS medium 61 may be a liquid over the entire range from ⁇ + to ⁇ - ⁇ .
• the ITS medium 61 may not be a liquid over the entire range from ⁇ + to , but may be provided to the counter-flow heat exchanger 4 at a higher flow rate in order to achieve a lower temperature rise across the counter-flow heat exchanger (e.g., such that the temperature of the ITS medium at the exit of the counter-flow heat exchanger 4 is lower than ⁇ - ⁇ ) while still cooling the working fluid from to ⁇ + .
• the temperature of the ITS medium in the tank 60 can be lower than ⁇ - ⁇ .
• the ITS medium in the tank 60 can exchange heat with ambient (e.g., through a radiator or other implementations described herein) in order to cool back to the temperature ⁇ + .
• FIG. 21 is a schematic flow diagram of a pumped thermal system discharge cycle in solar mode or combustion heated mode with heat rejection to an intermediate fluid circulated in a thermal bath at ambient temperature.
• the discharge cycle can operate similarly to the discharge cycle in FIG.20, but after exiting the turbine 3, the working fluid 20 can proceed to the cold side CFX 4 where it exchanges heat with an intermediate medium or fluid 62 circulating through a thermal bath 63 at the temperature T 0 at or near ambient temperature.
• the intermediate medium or fluid 62 may be used for exchanging heat between the working fluid 20 and a thermal bath 63 in the cold side CFX 4.
• the use of the intermediate fluid 62 may provide an advantage over contacting an inexpensive thermal sink or medium (e.g., water) directly with the working fluid.
• directly contacting such a thermal medium with the working fluid in the cold side CFX 4 may cause problems, such as, for example, evaporation or over-pressurization (e.g., explosion) of the thermal medium.
• the intermediate fluid 62 can remain in liquid phase throughout all, at least a portion of, or a significant portion of the operation in the cold side CFX 4.
• the thermal bath 63 may contain a large amount of inexpensive heat sink material or medium, such as, for example, water.
• the heat deposited in the heat sink material may be used for various useful purposes such as, for example, residential or commercial heating, thermal desalination or other uses described elsewhere herein.
• the heat sink material may be re-equilibrated with ambient temperature (e.g., through a radiator or other implementations described herein).
• the pumped thermal system may provide heat sources and/or cold sources to other facilities or systems such as, for example, through co-location with a gas to liquids (GTL) facility or a desalination facility.
• GTL gas to liquids
• the GTL facilities may make use of one or more of the cold reservoirs in the system (e.g., the CTS medium in the tank 9 for use in oxygen separation in the GTL facility) and/or one or more hot reservoirs in the system (e.g., the HTS medium in the tank 6 for use in a Fischer-Tropsch process in the GTL facility).
• one or more hot reservoirs or one or more cold reservoirs in the pumped thermal system may be used for the operation of thermal desalination methods.
• Further examples of possible heat and cold uses include co-location or heat exchange with building/area heating and cooling systems.
• the pumped thermal system may make use of waste heat sources and/or waste cold sources from other facilities or systems such as, for example, through co-location with a liquefied natural gas import or export terminal.
• a waste cold source may be used for cooling the cold side thermal storage media 22.
• recharging of the cold side using waste cold may be combined with recharging of the hot side thermal storage media 21 by external heat input (e.g., solar, combustion, waste heat, etc.).
• the recharged storage media can then be used in a discharge cycle such as, for example, the discharge cycles in FIGs. 14 or 16.
• the pumped thermal system may be used as a heat engine with a waste heat source serving as the hot side heat input and a waste cold source serving as the cold side heat sink.
• the hot side storage media may be recharged using a modified version of the cycle shown in FIG. 15, where the temperature ⁇ + is about the ambient temperature and ⁇ - + , corresponds to a temperature above the ambient temperature.
• a waste heat source can be used to provide the heat needed at a temperature of at least ⁇ - + , for heating the working fluid and/or the CTS medium to ⁇ - + , .
• an intermediate fluid (e.g., Therminol ® ) which can remain liquid between the temperatures ⁇ - + , and ⁇ + may be used to transfer the heat from the waste heat source to the working fluid.
• Pumped thermal systems with dedicated compressor/turbine pairs [0158]
• pumped thermal systems comprising multiple working fluid systems, or working fluid flow paths are provided.
• pumped thermal system components in the charge and discharge modes may be the same.
• the same compressor/turbine pair may be used in charge and discharge cycles.
• one or more system components may differ between charge and discharge modes.
• separate compressor/turbine pairs may be used in charge and discharge cycles.
• the system has one set of heat exchangers, and a common set of HTS and CTS tanks which are charged or discharged by two pairs or sets of compressors and turbines.
• the system has a common set of HTS and CTS tanks, but separate sets of heat exchangers and separate sets of compressors and turbines.
• turbomachinery e.g., turbomachinery used in systems with recuperation
• turbomachinery may operate over a relatively low pressure ratio (e.g., with relatively few compression stages) but over relatively large temperature during both compression and expansion.
• the temperature ranges may change (e.g., switch as in FIGs. 17 and 18) between charge and discharge modes.
• the operation over large temperature ranges during compression and/or expansion may complicate design of a combined compressor/turbine for both charge and discharge.
• FIGs. 22 and 23 show pumped thermal systems with separate compressor 1/turbine 3 pairs for charge mode C and discharge mode D.
• the separate compressor/turbine pairs may or may not be ganged on a common mechanical shaft.
• the compressor/turbine pairs C and D can have separate shafts 10.
• the shafts 10 may rotate at the same speed or at different speeds.
• the separate compressor/turbine pairs or working fluid systems may or may not share heat exchangers (e.g., the heat exchangers 2 and 4).
• the system has a common set of HTS tanks 6 and 7 and CTS tanks 8 and 9.
• the system has separate pairs of heat exchangers 2 and 4 and separate compressor 1/turbine 3 pairs for the charge mode C and the discharge mode D.
• the HTS and CTS storage media flow paths for the charging cycle are shown as solid black lines.
• the HTS and CTS storage media flow paths for the discharge cycle are shown as the dashed grey lines.
• the system shown in a charge configuration, has one set of heat exchangers 2 and 4, and a common set of HTS tanks 6 and 7 and CTS tanks 8 and 9.
• the HTS and CTS tanks can be charged by a compressor/turbine set C, or discharged by a compressor/turbine set D, each set comprising a compressor 1 and a turbine 3.
• the system may switch between the sets C and D using valves 83.
• the system again shown in a charge configuration, has a common set of HTS tanks 6 and 7 and CTS tanks 8 and 9.
• the HTS and CTS tanks can be charged by the charge set C that includes a first set of the heat exchangers 2 and 4, the compressor 1 and the turbine 3.
• the HTS and CTS tanks can be discharged by switching to a separate discharge set C that includes a second set of the heat exchangers 2 and 4, the compressor 1 and the turbine 3.
• the charge and discharge sets of compressors and turbines in FIGs. 22 and 23 may share a common set of heat exchangers that are switched between the turbomachinery pairs using the valves 83.
• each set of turbomachinery may have a dedicated set of heat exchangers.
• the charge and discharge sets may or may not share a set of HTS and CTS tanks.
• separate compressor/turbine sets or pairs may advantageously be used in pumped thermal systems used with intermittent and/or variable electric power inputs.
• a first compressor/turbine set can be used in a charge cycle that follows wind and/or solar power (e.g., electric power input from wind and/or solar power systems) while a second compressor/turbine set can be used in a discharge cycle that follows load (e.g., electric power output to a power grid).
• load e.g., electric power output to a power grid
• pumped thermal systems placed between a power generation system and a load may aid in smoothing variations/fluctuations in input and/or output power requirements.
• pumped thermal systems can be augmented by additional energy conversion processes and/or be directly utilized as energy conversion systems without energy storage (i.e., as power generation systems).
• pumped thermal systems herein can be modified to allow for direct power generation using natural gas, Diesel fuel, petroleum gas (e.g., propane/butane), dimethyl ether, fuel oil, wood chips, landfill gas, hexane, hydrocarbons or any other combustible substance (e.g., fossil fuel or biomass) for adding heat to the working fluid on a hot side of a working fluid cycle, and a cold side heat sink (e.g., water) for removing heat from the working fluid on a cold side of the working fluid cycle.
• natural gas Diesel fuel
• petroleum gas e.g., propane/butane
• dimethyl ether fuel oil
• wood chips wood chips
• landfill gas hexane
• hydrocarbons or any other combustible substance e.g., fossil fuel or biomass
• a cold side heat sink e.g., water
• FIGs.24 and 25 show pumped thermal systems configured in generation mode.
• pumped thermal systems herein can be modified by adding two additional heat exchangers 40 and 41, four additional valves 19a, 19b, 19c and 19d, a heat sink (e.g., a water cooling system; water from a fresh water reservoir such as a river, a lake or a reservoir; salt water from a salt water reservoir such as a sea or an ocean; air cooling using radiators, fans/blowers, convection; or an environmental heat sink such as ground/soil, cold air etc.) 42, and a heat source (e.g., a combustion chamber with a fuel-oxidant mixture) 43.
• a heat sink e.g., a water cooling system; water from a fresh water reservoir such as a river, a lake or a reservoir; salt water from a salt water reservoir such as a sea or an ocean; air cooling using radiators, fans/blowers, convection; or an environmental heat sink such as ground/so
• the heat source 43 can exchange heat with a first of the two additional heat exchangers 40, and the heat sink 42 can exchange heat with a second of the two additional heat exchangers 41.
• the heat source 43 may be used to for exchanging heat with the working fluid 20.
• the heat source 43 may be a combustion heat source.
• the combustion heat source can comprise a combustion chamber for combusting a combustible substance (e.g., a fossil fuel, a synthetic fuel, municipal solid waste (MSW) or biomass).
• the combustion chamber may be separate from the heat exchanger 40.
• the heat exchanger 40 may comprise the combustion chamber.
• the heat source 43 may be a waste heat source, such as, for example waste heat from a power plant, an industrial process (e.g., furnace exhaust).
• a solar heater, a combustion heat source, a waste heat source, or any combination thereof may be used for heating the hot side heat storage fluid and/or the working fluid.
• the working fluid can be heated directly using any of these heat sources.
• the hot side heat storage fluid (or HTS medium) can be heated using any of these heat sources.
• the hot side heat storage fluid (or HTS medium) can be heated in parallel with the working fluid using any of these heat sources.
• the pumped thermal systems in FIGs. 24 and 25 may be operated as hybrid systems.
• the valves 19a, 19b, 19c and 19d can be used to switch between two modes.
• the system When the valves are in a first position, the system can operate as a pumped thermal storage system (e.g., closed system in charge/discharge mode).
• the working fluid 20 e.g., argon or air
• HTS medium e.g., molten salt
• CTS medium e.g., hexane
• the system can operate as a power generation system (e.g., open system in generation mode).
• the heat exchangers 2 and 4 may be bypassed, and the working fluid 20 can exchange heat with the combustion chamber 43 in the hot side heat exchanger 40 and with the heat sink 42 in the cold side heat exchanger 41.
• Any description of configuration and/or design of heat transfer processes (e.g., heat transfer in heat exchangers) described herein in relation to pumped thermal systems may also be applied to hybrid pumped thermal systems, and vice versa.
• the heat sink 42, the heat source 43, the heat exchangers 40 and 41, and/or the quantity of heat transferred on the cold side and/or the hot side may be configured to decrease or minimize entropy generation associated with heat transfer processes and/or to maximize system efficiency.
• the hybrid systems may operate in storage and generation modes simultaneously.
• valves 19a, 19b, 19c and 19d can be configured to allow a given split between a working fluid flow rate to the heat exchangers 40 and 41 and a working fluid flow rate to the heat exchangers 2 and 4.
• the hybrid systems may operate exclusively in storage mode, or exclusively in generation mode (e.g., as a natural gas peaking plant).
• the split between modes may be selected based on system efficiency, available electric power input (e.g., based on availability), desired electric power output (e.g., based on load demand) etc.
• thermal efficiency of an ideal system i.e., assuming isentropic compression and expansion processes, ideal heat transfer processes
• thermal efficiency in hybrid systems of the disclosure can be at least about 10%, at least about 20%, at least about 30%, at least about 40%, at least about 50%, at least about 60%, or more.
• the heat source 43 may be used for exchanging heat with an HTS medium (e.g., a molten salt).
• the combustion heat source 43 may be used for heating the HTS medium 21.
• FIG. 26 is a schematic flow diagram of hot side recharging in a pumped heat cycle through heating by the heat source 43 (e.g., combustion heat source, waste heat source).
• the heat source 43 is a waste heat source, such as a waste heat source from a refinery or other processing plant.
• the heat source 43 is obtained from combusting natural gas in order to ensure the delivery of electricity even if the pumped thermal system runs out of charged storage media.
• recharging of the hot side storage media using the heat source 43 may provide an advantage over recharging using electricity or other means (e.g., the price of electricity at the time may be too high).
• the heat source 43 can be used to heat up the HTS medium 21 from the temperature T1 in the tank 7 to the temperature T1 + in the tank 6.
• the HTS medium can then be used in the CFX 2 for exchanging heat with the working fluid to in a discharge cycle, such as, for example, the discharge cycles in FIGs.20 and 21.
• the CTS medium is a combustible substance such as a fossil fuel (e.g., hexane or heptanes)
• burning of the CTS medium stored in the CTS tanks may be used for providing thermal energy for heating the HTS medium as shown, for example, in FIG. 26 or for operation of the cycles in the configurations shown, for example, in FIGs.24 and 25.
• the systems of the disclosure may be capable of operating both in an electricity only storage cycle (comprising heat transfer with an HTS medium and a CTS medium below ambient temperature) and in a heat engine to ambient cycle, where, in a discharge mode, heat is input from the HTS medium to the working fluid and rejected to the ambient environment rather than to the CTS medium.
• This capability may enable the use of heating of the HTS with combustible substances (e.g., as shown in FIG.26) or the use of solar heating of the HTS (e.g., as shown in FIG. 19).
• Heat rejection to ambient may be implemented using, for example, the discharge cycles in FIGs. 20 and 21.
• the systems capable of operating both in an electricity only storage cycle and in a heat engine to ambient cycle may comprise a recuperator. Any description in relation to such hybrid systems without a recuperator may readily be applied to hybrid systems with a recuperator at least in some configurations.
• the hybrid systems may be implemented using, for example, the parallel, valved configuration in FIG.24. For example, the counter-flow heat exchangers 4 in FIGs.
• the systems herein may be configured to enable switching between different cycles of the disclosure using a shared set of valves and pipes.
• the system may be configured to switch between the electricity only charge cycle (such as shown in, for example, FIG. 15), the electricity only discharge cycle (such as shown in, for example, FIG.16), and the heat engine to ambient cycle (such as shown in FIG.21).
• Pumped thermal systems with pressure regulation power control [0177] In an aspect of the disclosure, the pressure of working fluids in pumped thermal systems can be controlled to achieve power control.
• the power provided to a closed system in charge mode and/or the power extracted from the closed system in discharge and/or generation mode is proportional to the molar or mass flow rate of the circulating working fluid.
• the mass flow rate is proportional to density, area, and flow velocity.
• the flow velocity can be kept fixed in order to achieve a fixed shaft speed (e.g., 3600 rpm or 3000 rpm in accordance with power grid requirements of 60 and 50 Hz respectively).
• a fixed shaft speed e.g., 3600 rpm or 3000 rpm in accordance with power grid requirements of 60 and 50 Hz respectively.
• the mass flow rate increases in a discharge and/or generation mode, more load should be added to the system to maintain a constant speed of the rotating shaft, and vice versa.
• the reduced load can cause the shaft speed to increase, thus increasing the mass flow rate.
• this increased mass flow rate can lead to an increase in the power delivered, in turn increasing the shaft speed.
• the shaft speed and the power can continue to increase uncontrollably, resulting in a runaway of the rotating shaft.
• pressure regulation may enable control, and thus stabilization of runaway, through adjustment of the amount (e.g., density) of circulating working fluid in accordance with system requirements.
• a controller can reduce the mass of circulating working fluid (e.g., mass flow rate) in order to decrease the power delivered, in turn decreasing the shaft speed.
• Pressure regulation may also allow for an increase in mass flow rate in response to an increase in load. In each of these instances, the flow rates of the HTS and CTS media through the heat exchangers can be matched to the heat capacity of the working fluid passing through the heat exchangers.
• the working fluid pressure in the closed system can be varied by using an auxiliary working fluid tank in fluid communication with the closed system.
• power input/output can be decreased by transferring the working fluid from the closed cycle loop to the tank, and power input/output can be increased by transferring the working fluid from the tank to the closed cycle loop.
• the pressure of the working fluid is decreased, less heat can be transferred between the thermal storage tanks on the hot and cold sides of the system as a result of the decreased mass flow rate and less power can be input to/output by the system.
• the compression ratios of turbomachinery components may remain substantially unchanged.
• one or more operating parameters and/or configuration e.g., variable stators, shaft speed
• one or more pressure ratios may change in response to a change in working fluid pressure.
• reduced cost and/or reduced parasitic energy consumption may be achieved using the power control configuration relative to other configurations (e.g., using a choke valve for controlling the flow of the working fluid).
• variation of working fluid pressure while keeping the temperature and flow velocity constant (or near- constant) may lead to negligible entropy generation.
• FIG. 27 shows an example of a pumped thermal system with power control.
• the temperature of the working fluid on the hot and cold sides of the system may remain constant or near-constant for a given period of time regardless of working fluid mass flow rate due to large heat capacities of the heat exchangers 2 and 4 and/or the hot and cold side thermal storage media in the tanks 6, 7, 8 and 9.
• the flow rates of the HTS and CTS media through the heat exchangers 2 and 4 are varied in concert with a change in the pressure of the working fluid in order to keep the temperatures in the heat exchangers and working fluid optimized over longer time periods.
• auxiliary tanks 44 filled with the working fluid 20 can be in fluid communication with a hot (e.g., high pressure) side of the pumped thermal system and/or a cold (e.g., low pressure) side of the pumped thermal system.
• the auxiliary tank can be in fluid communication with the working fluid adjacent to an inlet of the compressor 1 and/or adjacent to an outlet of the compressor 1.
• the auxiliary tank can be in fluid communication with the working fluid adjacent to an inlet of the turbine 3 and/or adjacent to an outlet of the turbine 3.
• the auxiliary tank can be in fluid communication with the working fluid in one or more locations system (e.g., one or more locations on the high pressure side of the system, on the low pressure side of the system, or any combination thereof).
• the auxiliary tank can be in fluid communication with the working fluid on a high pressure side and a low pressure side of the closed cycle.
• the fluid communication on the high pressure side can be provided after the compressor and before the turbine.
• the fluid communication on the low pressure side can be provided after the turbine and before the compressor.
• the auxiliary tank can contain working fluid at a pressure intermediate to the high and low pressures of the system.
• the working fluid in the auxiliary tank can be used to increase or decrease the amount of working fluid 20 circulating in the closed cycle of the pumped thermal system.
• the amount of working fluid circulating in the closed cycle loop can be decreased by bleeding the working fluid from the high pressure side of the closed cycle loop into the tank through a fluid path containing a valve or mass flow controller 46, thereby charging the tank 44.
• the amount of working fluid circulating in the closed cycle loop can be increased by bleeding the working fluid from the tank into the low pressure side of the closed cycle loop through a fluid path containing a valve or mass flow controller 45, thereby discharging the tank 44.
• Power control over longer timescales may be implemented by changing the pressure of the working fluid and by adjusting the flow rates of the hot side 21 and cold side 22 thermal storage fluids through the heat exchangers 2 and 4, respectively.
• flow rates of the thermal storage media 21 and/or 22 may be controlled (e.g., by a controller) to maintain given heat exchanger inlet and outlet temperatures.
• a first controller(s) may be provided for controlling the flow rates (e.g., mass flow rates) of thermal storage media
• a second controller may be provided for controlling the mass flow rate (e.g., by controlling mass, mass flow rate, pressure etc.) of the working fluid.
• pumped thermal systems with a pressure-encased motor/generator are provided.
• the pressure-encased motor/generator may be provided as an alternative to configurations where a shaft (also “crankshaft” herein) penetrates through a working fluid containment wall (where it can be exposed to one or more relatively high pressure differentials) in order to connect to a motor/generator outside the working fluid containment wall.
• the shaft may be exposed to pressures and temperatures of the working fluid in the low pressure portion of the working fluid cycle, in the high pressure portion of the working fluid cycle, or both.
• crankshaft seal(s) capable of holding back the pressures which the crankshaft is exposed to inside the working fluid containment wall can be difficult to manufacture and/or difficult to maintain.
• a rotating seal between high and low pressure environments may be difficult to achieve.
• coupling of the compressor and turbine to the motor/generator can be challenging.
• the motor/generator can therefore be placed entirely within the low pressure portion of the working fluid cycle, such that the exterior pressure vessel or working fluid containment wall may not need to be penetrated.
• FIG. 28 shows an example of a pumped thermal system with a pressure encased generator 11.
• the motor/generator is encased within the pressure vessel or working fluid containment wall (shown as dashed lines) and only feed-through electric leads 49 penetrate through the pressure vessel.
• a thermal insulation wall 48 is added between the motor/generator 11 and the working fluid in the low pressure portion of the cycle.
• the technical requirements for achieving an adequate seal through the thermal insulation wall can be less stringent due to the pressure being the same on both sides of the thermal insulation wall (e.g., both sides of the thermal insulation wall can be located in the low pressure portion of the cycle).
• the low pressure value can be about 10 atm.
• the motor/generator may be adapted for operation at elevated surrounding pressures.
• An additional thermal insulation wall 50 can be used to create a seal between the outlet of the compressor 1 and the inlet of the turbine 3 in the high pressure portion of the cycle.
• placing the motor/generator on the cold side of the pumped thermal systems may be beneficial to the operation of the motor/generator (e.g., cooling of a superconducting generator).
• Pumped thermal systems with variable stator pressure ratio control [0186] A further aspect of the disclosure relates to control of pressure in working fluid cycles of pumped thermal systems by using variable stators.
• use of variable stators in turbomachinery components can allow pressure ratios in working fluid cycles to be varied.
• the variable compression ratio can be accomplished by having movable stators in the turbomachinery.
• pumped thermal systems e.g., the systems in FIGs. 17 and 18
• heat can be rejected (e.g., to the environment) in section 38 in the charge cycle and in section 39 in the discharge cycle, wherein the heat in section 38 can be transferred at a lower temperature than the heat in section 39.
• the compression ratio can be varied when switching between the charge cycle and the discharge cycle.
• variable stators can be added to both the compressor and the turbine, thus allowing the compression ratio to be tuned.
• FIG.29 is an example of variable stators in a compressor/turbine pair.
• the compressor 1 and the turbine 3 can both have variable stators, so that the compression ratio for each can be tuned. Such tuning may increase roundtrip efficiency.
• the compressor and/or the turbine can (each) include one or more compression stages. For example, the compressor and/or the turbine can have multiple rows of repeating features distributed along its circumference.
• Each compression stage can comprise one or more rows of features.
• the rows may be arranged in a given order.
• the compressor 1 and the turbine 3 each comprise a sequence of a plurality of inlet guide vanes 51, a first plurality of rotors 52, a plurality of stators 53, a second plurality of rotors 52 and a plurality of outlet guide vanes 54.
• Each plurality of features can be arranged in a row along the circumference of the compressor/turbine.
• the configuration (e.g., direction or angle) of the stators 53 can be varied, as indicated in FIG.29. [0190]
• the compressor/turbine pair can be matched.
• an outlet pressure of the compressor can be about the same as an inlet pressure of the turbine, and an inlet pressure of the compressor can be about the same as the outlet pressure of the turbine; thus, the pressure ratio across the turbine can be the same as the pressure ratio across the compressor.
• the inlet/outlet pressures and/or the pressure ratios may differ by a given amount (e.g., to account for pressure drop in the system).
• the use of variable stators on both the compressor and the turbine can allow the compressor and the turbine to remain matched as the compression ratio is varied. For example, using the variable stators, operation of the compressor and the turbine can remain within suitable operating conditions (e.g. within a given range or at a given point on their respective operating maps) as the compression ratio is varied.
• turbomachinery efficiencies e.g., isentropic efficiencies
• resulting roundtrip storage efficiency may be maintained within a desired range.
• the use of variable stators can be combined with other methods for varying the compression ratios (e.g. variable shaft rotation speed, bypassing of turbomachinery stages, gears, power electronics, etc.).
• Pumped thermal system units comprising pumped thermal system subunits [0191]
• a further aspect of the disclosure relates to control of charging and discharging rate over a full range from maximum charging/power input to maximum discharging/power output by building composite pumped thermal system units comprised of pumped thermal system subunits.
• pumped thermal systems may have a minimum power input and/or output (e.g., minimum power input and/or minimum power output) above 0% of maximum power input and/or output (e.g., maximum power input and/or maximum power output), respectively.
• a single unit by itself may be able to continuously ramp from the minimum power input to the maximum power input and from the minimum power output to the maximum power output, but may not be able to continuously ramp from the minimum power input to the minimum power output (i.e., from the minimum power input to zero power input/output, and from zero power input/output to the minimum power output).
• An ability to continuously ramp from the minimum power input to the minimum power output may enable the system to continuously ramp from the maximum power input to the maximum power output.
• the system may be able to continuously vary the power consumed or supplied across a range from the maximum input (e.g., acting as a load on the grid) to the maximum output (e.g., acting as a generator on the grid).
• Such functionality may increase (e.g., more than double) the continuously rampable range of the pumped thermal system.
• Increasing the continuously rampable range of the pumped thermal system may be advantageous, for example, when continuously rampable power range is used as a metric for determining the value of grid assets.
• such functionality may enable the systems of the disclosure to follow variable load, variable generation, intermittent generation, or any combination thereof.
• composite pumped thermal system units comprised of multiple pumped thermal system subunits may be used.
• each subunit may have a minimum power input and/or output above 0%.
• the continuous ramping of the power from the maximum power input to the maximum power output may include combining a given quantity of the subunits.
• a suitable (e.g., sufficiently large) number of subunits may be needed to achieve continuous ramping.
• the number of subunits can be at least about 2, 5, 10, 20, 30, 40, 50, 100, 200, 500, 750, 1000, and the like.
• the number of subunits is 2, 5, 10, 20, 30, 40, 50, 100, 150, 200, 250, 300, 350, 400, 450, 500, 550, 600, 650, 700, 750, 800, 850, 900, 950, 1000 or more.
• Each subunit may have a given power capacity.
• each subunit can have a power capacity that is less than about 0.1%, less than about 0.5%, less than about 1%, less than about 5%, less than about 10%, less than about 25%, less than about 50%, or less than about 90% of the total power capacity of the composite pumped thermal system.
• different subunits may have different power capacities.
• a subunit has a power capacity of about 10 kW, 100 kW, 500 kW, 1 MW, 2 MW, 5 MW, 10 MW, 20 MW, 50 MW, 100 MW, or more.
• the continuous ramping of the power from the maximum power input to the maximum power output may include controlling each subunit’s power input and/or output (e.g., power input and/or power output) separately.
• the subunits may be operated in opposing directions (e.g., one or more subunits may operate in power input mode while one or more subunits may operate in power output mode).
• each pumped thermal system subunit can be continuously ramped between a maximum power input and/or output down to about 50% of the maximum power input and/or output, respectively, three or more such pumped thermal system subunits may be combined into a composite pumped thermal system unit that can be continuously ramped from the maximum input power to the maximum output power.
• the composite pumped thermal system may not have a fully continuous range between the maximum input power and the maximum output power, but may have an increased number of operating points in this range compared to a non-composite system.
• Energy storage system units comprising energy storage system subunits [0193]
• a further aspect of the disclosure relates to control of charging and discharging rate over a full range from maximum charging/power input to maximum discharging/power output by building composite energy storage system units comprised of energy storage system subunits.
• energy storage systems may have a minimum power input and/or output (e.g., minimum power input and/or minimum power output) above 0% of maximum power input and/or output (e.g., maximum power input and/or maximum power output), respectively.
• a single unit by itself may be able to continuously ramp from the minimum power input to the maximum power input and from the minimum power output to the maximum power output, but may not be able to continuously ramp from the minimum power input to the minimum power output (i.e., from the minimum power input to zero power input/output, and from zero power input/output to the minimum power output).
• An ability to continuously ramp from the minimum power input to the minimum power output may enable the system to continuously ramp from the maximum power input to the maximum power output.
• the system may be able to continuously vary the power consumed or supplied across a range from the maximum input (e.g., acting as a load on the grid) to the maximum output (e.g., acting as a generator on the grid).
• Such functionality may increase (e.g., more than double) the continuously rampable range of the energy storage system.
• Increasing the continuously rampable range of the energy storage system may be advantageous, for example, when continuously rampable power range is used as a metric for determining the value of grid assets.
• such functionality may enable the systems of the disclosure to follow variable load, variable generation, intermittent generation, or any combination thereof.
• composite energy storage system units comprised of multiple energy storage system subunits may be used.
• any energy storage system having power input/output characteristics that may benefit from a composite configuration may be used.
• systems having power input and/or power output characteristics that may benefit from a composite configuration may include various power storage and/or generation systems such as, for example, natural gas or combined cycle power plants, fuel cell systems, battery systems, compressed air energy storage systems, pumped hydroelectric systems, etc.
• each subunit may have a minimum power input and/or output above 0%.
• the continuous ramping of the power from the maximum power input to the maximum power output may include combining a given quantity of the subunits.
• a suitable (e.g., sufficiently large) number of subunits may be needed to achieve continuous ramping.
• the number of subunits can be at least about 2, 5, 10, 20, 30, 40, 50, 100, 200, 500, 750, 1000, and the like.
• the number of subunits is 2, 5, 10, 20, 30, 40, 50, 100, 150, 200, 250, 300, 350, 400, 450, 500, 550, 600, 650, 700, 750, 800, 850, 900, 950, 1000 or more.
• Each subunit may have a given power capacity.
• each subunit can have a power capacity that is less than about 0.1%, less than about 0.5%, less than about 1%, less than about 5%, less than about 10%, less than about 25%, less than about 50%, or less than about 90% of the total power capacity of the composite energy storage system.
• different subunits may have different power capacities.
• a subunit has a power capacity of about 10 kW, 100 kW, 500 kW, 1 MW, 2 MW, 5 MW, 10 MW, 20 MW, 50 MW, 100 MW, or more.
• the continuous ramping of the power from the maximum power input to the maximum power output may include controlling each subunit’s power input and/or output (e.g., power input and/or power output) separately.
• the subunits may be operated in opposing directions (e.g., one or more subunits may operate in power input mode while one or more subunits may operate in power output mode).
• each energy storage system subunit can be continuously ramped between a maximum power input and/or output down to about 50% of the maximum power input and/or output, respectively, three or more such energy storage system subunits may be combined into a composite energy storage system unit that can be continuously ramped from the maximum input power to the maximum output power.
• the composite energy storage system may not have a fully continuous range between the maximum input power and the maximum output power, but may have an increased number of operating points in this range compared to a non-composite system.
• FIG.30 shows a computer system 1901 (or controller) that is programmed or otherwise configured to regulate various process parameters of energy storage and/or retrieval systems disclosed herein. Such process parameters can include temperatures, flow rates, pressures and entropy changes.
• the computer system 1901 includes a central processing unit (CPU, also “processor” and “computer processor” herein) 1905, which can be a single core or multi core processor, or a plurality of processors for parallel processing.
• the computer system 1901 also includes memory or memory location 1910 (e.g., random-access memory, read-only memory, flash memory), electronic storage unit 1915 (e.g., hard disk), communication interface 1920 (e.g., network adapter) for communicating with one or more other systems, and peripheral devices 1925, such as cache, other memory, data storage and/or electronic display adapters.
• the memory 1910, storage unit 1915, interface 1920 and peripheral devices 1925 are in communication with the CPU 1905 through a communication bus (solid lines), such as a motherboard.
• the storage unit 1915 can be a data storage unit (or data repository) for storing data.
• the computer system 1901 can be operatively coupled to a computer network (“network”) 1930 with the aid of the communication interface 1920.
• the network 1930 can be the Internet, an internet and/or extranet, or an intranet and/or extranet that is in communication with the Internet.
• the network 1930 in some cases is a telecommunication and/or data network.
• the network 1930 can include one or more computer servers, which can enable distributed computing, such as cloud computing.
• the network 1930 in some cases with the aid of the computer system 1901, can implement a peer-to-peer network, which may enable devices coupled to the computer system 1901 to behave as a client or a server.
• the computer system 1901 is coupled to an energy storage and/or retrieval system 1935, which can be as described above or elsewhere herein.
• the computer system 1901 can be coupled to various unit operations of the system 1935, such as flow regulators (e.g., valves), temperature sensors, pressure sensors, compressor(s), turbine(s), electrical switches, and photovoltaic modules.
• the system 1901 can be directly coupled to, or be a part of, the system 1935, or be in communication with the system 1935 through the network 1930.
• the CPU 1905 can execute a sequence of machine-readable instructions, which can be embodied in a program or software.
• the instructions may be stored in a memory location, such as the memory 1910. Examples of operations performed by the CPU 1905 can include fetch, decode, execute, and writeback.
• the storage unit 1915 can store files, such as drivers, libraries and saved programs.
• the storage unit 1915 can store programs generated by users and recorded sessions, as well as output(s) associated with the programs.
• the storage unit 1915 can store user data, e.g., user preferences and user programs.
• the computer system 1901 in some cases can include one or more additional data storage units that are external to the computer system 1901, such as located on a remote server that is in communication with the computer system 1901 through an intranet or the Internet.
• the computer system 1901 can communicate with one or more remote computer systems through the network 1930.
• the computer system 1901 can communicate with a remote computer system of a user (e.g., operator). Examples of remote computer systems include personal computers, slate or tablet PC’s, telephones, Smart phones, or personal digital assistants.
• the user can access the computer system 1901 via the network 1930.
• Methods as described herein can be implemented by way of machine (e.g., computer processor) executable code stored on an electronic storage location of the computer system 1901, such as, for example, on the memory 1910 or electronic storage unit 1915.
• the machine executable or machine readable code can be provided in the form of software.
• the code can be executed by the processor 1905.
• the code can be retrieved from the storage unit 1915 and stored on the memory 1910 for ready access by the processor 1905.
• the electronic storage unit 1915 can be precluded, and machine-executable instructions are stored on memory 1910.
• the code can be pre-compiled and configured for use with a machine have a processor adapted to execute the code, or can be compiled during runtime.
• the code can be supplied in a programming language that can be selected to enable the code to execute in a pre-compiled or as-compiled fashion.
• aspects of the systems and methods provided herein, such as the computer system 1901 can be embodied in programming.
• Various aspects of the technology may be thought of as “products” or “articles of manufacture” typically in the form of machine (or processor) executable code and/or associated data that is carried on or embodied in a type of machine readable medium.
• Machine-executable code can be stored on an electronic storage unit, such memory (e.g., read-only memory, random-access memory, flash memory) or a hard disk.
• “Storage” type media can include any or all of the tangible memory of the computers, processors or the like, or associated modules thereof, such as various semiconductor memories, tape drives, disk drives and the like, which may provide non-transitory storage at any time for the software programming. All or portions of the software may at times be communicated through the Internet or various other telecommunication networks. Such communications, for example, may enable loading of the software from one computer or processor into another, for example, from a management server or host computer into the computer platform of an application server.
• another type of media that may bear the software elements includes optical, electrical and electromagnetic waves, such as used across physical interfaces between local devices, through wired and optical landline networks and over various air-links.
• Non-volatile storage media include, for example, optical or magnetic disks, such as any of the storage devices in any computer(s) or the like, such as may be used to implement the databases, etc. shown in the drawings.
• Volatile storage media include dynamic memory, such as main memory of such a computer platform.
• Tangible transmission media include coaxial cables; copper wire and fiber optics, including the wires that comprise a bus within a computer system.
• Carrier-wave transmission media may take the form of electric or electromagnetic signals, or acoustic or light waves such as those generated during radio frequency (RF) and infrared (IR) data communications.
• Computer-readable media therefore include for example: a floppy disk, a flexible disk, hard disk, magnetic tape, any other magnetic medium, a CD-ROM, DVD or DVD-ROM, any other optical medium, punch cards paper tape, any other physical storage medium with patterns of holes, a RAM, a ROM, a PROM and EPROM, a FLASH-EPROM, any other memory chip or cartridge, a carrier wave transporting data or instructions, cables or links transporting such a carrier wave, or any other medium from which a computer may read programming code and/or data. Many of these forms of computer readable media may be involved in carrying one or more sequences of one or more instructions to a processor for execution. III.
• reversible turbines/compressors can be used in place of one or more conventional compressors 1 and turbines 3.
• the flow of working fluid 20 may be reversed between charge and discharge cycles, such that the working fluid may flow in one direction through a reversible turbomachine during a charge cycle and flow in the opposite direction through the reversible turbomachine during a discharge cycle, such that the reversible turbomachine is acting as a compressor during one cycle and acting as a turbine during another cycle.
• turbomachine may spin in one direction during the charge cycle and spin in the opposite direction during the discharge cycle.
• Reversible turbomachines can be implemented in the arrangements previously described herein, provided that the working fluid flow direction is reversed between charge and discharge.
• reversible turbomachinery can be used in place of some or all of the compressors 1 and/or turbines 3 in the PHES systems shown in FIGS. 2-3, 6-7, 13-16, 20-21, 22, 23, 24-25, and 27-28.
• reversible turbomachinery can be used to replace both compressor 1 and turbine 3 in FIG. 2.
• reversible turbomachinery can be used to replace one compressor 1 and/or one turbine 3 in FIG. 23.
• FIGs.31A and 31B illustrate a non-recuperated PHES system, such as in FIGs. 2-3, with a pair of reversible turbomachines 101 and 103, operating in charge mode and discharge mode respectively.
• FIGs. 32A and 32B illustrate a recuperated PHES system, such as in FIGs. 13-16, with a pair of reversible turbomachines 101 and 103, operating in charge mode and discharge mode respectively. Fluid flow paths/directions for the working fluid 20 are indicated by arrows.
• FIG.31A illustrates a charge-mode fluid flow path of working fluid 20 from reversible turbomachine 101 (acting as a compressor), through hot side heat exchange 2, through reversible turbomachine 103 (acting as a turbine), through cold side heat exchanger 4, and back to reversible turbomachine 101.
• FIG. 31B illustrates a discharge-mode fluid flow path of working fluid 20 from reversible turbomachine 103 (acting as a compressor), through hot side heat exchange 2, through reversible turbomachine 101 (acting as a turbine), through cold side heat exchanger 4, and back to reversible turbomachine 103.
• FIG.32A illustrates a charge-mode fluid flow path of working fluid 20 from reversible turbomachine 101 (acting as a compressor), through hot side heat exchange 2, through recuperator 5, through reversible turbomachine 103 (acting as a turbine), through cold side heat exchanger 4, through recuperator 5, and back to reversible turbomachine 101.
• FIG. 32B illustrates a discharge-mode fluid flow path of working fluid 20 from reversible turbomachine 103 (acting as a compressor), through recuperator 5, through hot side heat exchange 2, through reversible turbomachine 101 (acting as a turbine), through recuperator 5, through cold side heat exchanger 4, and back to reversible turbomachine 103.
• Excess heat in the PHES systems of FIGs 31A, 31B, 32A, and 32B may be removed from the systems through heat rejection devices, such as heat rejection device 56 acting on, and in thermal contact with, the HTS medium 21, heat rejection device 55 acting on, and in thermal contact with, the CTS medium 22, and/or heat rejection device 57 acting on, and in thermal contact with, the working fluid 20.
• the heat rejection devices 55, 56, 57 may be operated by opening or closing valves that allow the thermal storage mediums 21, 22 or the working fluid 20, as appropriate for the location, to flow through them with thermal contact or bypass them as needed for heat removal.
• the heat rejection devices 55, 56, 57 may be, for example and not limited to, passive or active ambient air coolers, radiators, or heat exchangers in thermal contact with heat sinks.
• the heat rejection devices 55, 56, 57 are illustrated in specific locations for example purposes only and may be in different locations or not present at all.
• heat rejection devices may additionally or alternatively be located on cold-side tank(s) 6, hot side tank(s) 8, or at another location or locations along the flow path of working fluid 20.
• additional components may be included in or along the fluid paths, and/or illustrated components may be sets of components.
• one or more valved bypass or recirculation paths may be included in or along the fluid paths.
• relief, drain, or fluid injection valves may be included in or along the fluid paths.
• an illustrated heat exchanger, heat rejection device, tank, or reversible turbomachine may include a set of heat exchangers, heat rejection devices, tanks, or turbomachines, respectively, operating or capable of operating in series, in parallel, or in some other arrangement.
• the PHES systems of FIGs 31A, 31B, 32A, and 32B may include an inventory control system in which one or more tanks 64 are connected to, or isolated from, the working fluid 20 flow.
• the one or more tanks 64 may be connected by one or more valves (e.g., a three-way valve) to working fluid 20 flow at a high-pressure side of the PHES system (e.g., between the outlet of a reversible turbomachine acting as a compressor and the inlet of a reversible turbomachine acting as a turbine).
• a valve e.g., a three-way valve
• the one or more tanks 64 may be isolated by one or more valves (e.g., a three-way valve) from working fluid 20 flow at a low-pressure side of the PHES system (e.g., between the outlet of a reversible turbomachine acting as a turbine and the inlet of a reversible turbomachine acting as a compressor), thereby accepting and storing high-pressure working fluid 20 into the one or more tanks 64.
• valves e.g., a three-way valve
• the one or more tanks 64 may be isolated from the high-pressure side of the PHES system by the one or more valves (e.g., the three-way valve), while at the same time being connected to the low-pressure side of the PHES system by one or more valves (e.g., the three-way valve), thereby releasing high-pressure working fluid 20 from the one or more tanks 64 into the low-pressure side of the PHES system.
• the one or more tanks 64 may be isolated from both the high-pressure side of the PHES system and the low-pressure side of the PHES system by one or more valves (e.g., the three-way valve).
• Fluid connections may be arranged differently in a PHES system with reversible turbomachines than in a PHES system with traditional compressor(s) and turbine(s). For example, in both systems it may be desirable to have heat exchangers 2, 4 configured as counterflow heat exchangers.
• heat exchangers 2, 4 configured as counterflow heat exchangers.
• the hot side tanks 6, 7 will swap their thermal fluid 21 path connections to the hot side heat exchanger 2 between charge and discharge cycles, as illustrated by positions 32, 33 swapping between FIGs. 2 and 3. This also occurs with cold side tanks 8, 9 and cold side heat exchanger 4.
• PHES systems with reversible turbomachines such as turbomachines 101, 103
• the thermal fluid path connections between the tanks 6, 7, 8, 9 do not need to swap with their respective heat exchangers 2, 4 during changeover from charge mode to discharge mode in order to maintain counterflow because the working fluid is changing flow direction, as illustrated between FIGs. 31A and 31B, and also FIGs. 32A and 32B. Therefore, beneficially, a PHES system with reversible turbomachines can have simplified fluid paths for thermal fluids 21, 22 and potentially avoid the use of valve arrangements for changing the thermal fluid path connections between the tanks 6, 7, 8, 9 and their respective heat exchangers 2, 4 for counterflow heat exchange.
• Drivetrains for reversible turbomachines may be arranged in various manners.
• the drivetrains of reversible turbomachines 101 and 103 are shown in FIGs. 31A, 31B, 32A, 32B, and 33 connected by a common mechanical shaft 10 and connected to a motor/generator 11.
• FIG. 34 shows another example drivetrain arrangement in which reversible turbomachines 101 and 103 are connected to separate mechanical shafts 10A and 10B, and connected to separate motor/generators 11A and 11B.
• gearboxes, clutches, and other drivetrain components may be included as part of, or in between any of, reversible turbomachines 101, 103, their respective shafts 10, 10A, 10B, and/or their respective motor/generators 11, 11A, 11B.
• motor/generators 11, 11A, 11B are each illustrated as a single component that can handle both driving the turbomachine(s) as a motor using external power (e.g., electricity) and being driven by the turbomachine(s) as a generator for generating electrical power.
• the motor/generators 11, 11A, 11B may each include separate motor and generation components and may further include gearboxes, clutches, and other drivetrain components that allow the motor/generators 11, 11A, 11B to act as motors or generators depending on the operating state of the PHES system, such as charge or discharge mode.
• the aforementioned drivetrain and motor/generator arrangements may be implemented along with the reversible turbomachines in any of the previously described PHES systems.
• Illustrative Reversible Turbomachinery [0220] Reversible turbomachines (e.g., turbomachines 101, 103) in a PHES system require different designs than a dedicated conventional compressor (e.g., compressor 1) or turbine (e.g., turbine 3).
• reversible turbomachines may be symmetrically identical, or symmetrically similar, in operation and design. In some embodiments, the symmetry may not be exact because of, for example, the different temperature conditions on the two sides of the system.
• the reversible turbomachines herein differ from conventional turbine/compressor arrangements in at least two aspects: (i) the number of turbine stages is large, so that the pressure loading on each is small and (ii) the blades are compromise airfoils that are aerodynamically symmetrical. As to the second aspect, small loading on the turbine blades allows them to be thin and to have leading and trailing edges that are simultaneously tapered and blunt.
• FIG.35 illustrates simplified representations of a pair of reversible turbomachines 101, 103 that can be implemented in PHES systems described herein.
• Turbomachine 101 is illustrated acting as a turbine, with working fluid entering on the right through inlet diffuser 101C (shown as dashed lines) and exiting on the left through outlet diffuser 101D (shown as dashed lines).
• Turbomachine 103 is illustrated acting as a compressor, with working fluid entering on the right through an inlet diffuser (shown as dashed lines) and exiting on the left through an outlet diffuser (shown as dashed lines).
• an illustrative simplified cross-section of the rotor 101A and stator 101B is also depicted.
• Rotor blades 74A and stator blades 74B are shown as simplified representations only and may have different shapes and quantities in embodiments.
• the representations of turbomachines 101, 103 are illustrated in FIG. 35 as mirror images of each other, but they be different than each other in some embodiments and/or may have differences not shown in the representations.
• Stage Loading [0222] Conventional turbine/compressor blades are airfoils designed to work in one way only. Modern conventional compressor blades are quite thin and so nearly symmetrical that it is difficult to distinguish by eye the leading edge from the trailing edge. This near-symmetry results from light loading of the compressor stages, a feature required to suppress surge. A lightly loaded stage is optimized with the blade that is thin, and a thin blade must be relatively symmetric.
• a relatively sharp leading edge on conventional compressor blades is also desirable for operation in the transonic range for the purpose of controlling bow shocks.
• modern conventional turbine blades are typically heavily loaded, thick, and asymmetric. This design is favored because it reduces size and weight (critically important in an aircraft engine), and also provides room for internal blade cooling.
• the operating temperatures can be sufficiently low such that blade cooling is not required.
• both the axial velocity of the working fluid ⁇ z and compression ratio 1 + ⁇ p/p are fixed by the annular radius r and the edge blade angles ⁇ and ⁇ .
• a reversible turbomachine will have blade angles ⁇ r and ⁇ r for the rotor and blade angles ⁇ s and ⁇ s for the stator. Blade entrance angles ⁇ r and ⁇ s may be the same or different, and blade exit angles ⁇ r and ⁇ s may be the same or different.
• FIGs.36-39 illustrate reversible turbomachine blades compared to conventional turbine and compressor blades.
• representative direction of fluid flow (at velocity ⁇ z) through the turbomachine is illustrated by arrows.
• Representative rotational direction of rotor blades is shown by an arrow.
• FIG.36 conventional turbine blades 72A (rotor) and 72B (stator) may be asymmetric and thick, with high camber, blunt tips, and tapered tails.
• conventional compressor blades 73A (rotor) and 73B (stator) may be asymmetric and thin, with low camber, blunt tips, and tapered tails.
• reversible turbomachine blades 74A (rotor) and 74B (stator) may be symmetric and thin, with low camber, and tips that range from tapered to moderately blunt.
• FIG.40 is a simplified representation of a compressor or turbine stage, viewed axially.
• FIG.41 is a simplified representational diagram illustrating nomenclature for reversible turbomachine blades in a blade row.
• Reversible turbomachine blades 74A are illustrated as an example of a symmetrical blade, such as a double-circular arc (“DCA”) blade, with a camber line 80, a chord line 81, a blade angle (metal) ⁇ at a first blade tip, a blade angle (metal) ⁇ at a second blade tip, a chord length c, a blade spacing (pitch) s, a maximum blade thickness t max , and a setting angle ⁇ .
• DCA double-circular arc
• DCA and DCA-like blades with thin t max and slightly blunted tips are particularly good shapes for reversible turbomachine blades, given their symmetry.
• a solution is to make the blade a good airfoil. This is illustrated with respect to FIGs. 42-45. Rather than being a simple plane, a good blade has an upper surface slightly bowed upward vis-a-vis the lower surface so as to maximize the Venturi effect and discourage boundary layer separation (stall). It is important that this bowing occur forward in the blade and that the tailing end of the blade be relatively sharp.
• FIGs. 43-45 illustrates three blade shapes built on the same blade arc 70 (e.g., camber line) of FIG.42. The three shapes are built on the same central arc 70, but have different airfoil modifications as described further below.
• Each blade in FIGs.43-45 illustrate turbomachinery blades shapes with the blade angles ⁇ and ⁇ appearing in Eqns. (8) and (9). The blade angles ⁇ and ⁇ are the same for all 3 cases.
• the sign convention for angles is counterclockwise positive.
• the turbine and compressor blades in FIGs.43 and 44 respectively, have a sharp tailing edge, as required to minimize drag and a blunt leading edge to allow for attack angle flexibility.
• the bluntness of the front end of the blade is not actually crucial. Its chief function is to facilitate a wide range of attack angles. In an airplane wing, this is important for maintaining control when the plane’s attitude changes, for example, at the moment of upward rotation at takeoff.
• the blunt front end has a less critical function of allowing accommodation to changing loads.
• the reversible blade in FIG.45 is a compromise that can be made if the attack angle is known relatively well in advance and the slight performance degradation of the extra drag due to the moderately blunt tail is not prohibitive.
• FIGs. 46-49 show that the compressor stage is simply the turbine stage with time reversed (i.e.
• FIGs.48 and 49 are the same as FIGs.46 and 47, respectively, except with the reversible blade of FIG. 45 substituted for conventional asymmetric airfoils from FIGs.43 and 44.
• the flow direction of fluid leaving a row of blades is fixed by the blade exit angle, but in the rest frame of the blade.
• the speed of sound is: Combining Eqns. (8) and (11) provides: or
• /vs 0.36. This is about half the design rule of thumb
• /vs 0.7, so the magnitudes of ⁇ and ⁇ in Figs.42 - 47 are about twice that.
• a reversible turbine/compressor In addition to decreasing the load on the turbine stages and increasing their number, a reversible turbine/compressor also requires a modified blade shape that is more symmetrical. This is shown, e.g., in FIGs. 38-39, 41, 45, and 48-49. With symmetrical blade shapes for the rotor and stator blades, the turbine and compressor become time-reverses of each other, as shown in FIGS. 38-39 and 48-49. Neither of the two key compromises required to make the blade symmetrical is extraordinary in compressor design. The first, a slightly blunted trailing edge, is actually implemented to some extent in all compressor blades because an infinitely thin blade is structurally impossible.

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• 2021
  • 2021-02-03 EP EP21750402.6A patent/EP4100632A4/de not_active Withdrawn
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