Techno-economic analysis of recuperated Joule-Brayton pumped thermal energy storage

McTigue, Joshua D.; Farres-Antunez, Pau; J, Kavin Sundarnath; Markides, Christos N.; White, Abraham

doi:10.1016/j.enconman.2021.115016

Cited by 65 publications

(12 citation statements)

References 40 publications

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“…38 Typically, energy densities are significantly less than that of water – e.g., accounting for discharge losses, the storage density of VP-1 at 220°C is about 14 kWh e /m 3 , so to store 10% of the output from a 1 GW plant for a day would require roughly 175,000 m 3 (e.g., 28 tanks of 20 m diameter by 20 m high). The cost of VP-1 lies in the range 0.4 to 2.6 £/kg 39 giving a contribution to capital cost from the storage fluid alone in the range 25 to 155 £/kWh e capacity. The upper end of this range is probably not viable.…”

Section: Thermal Storage Optionsmentioning

confidence: 99%

A feedheat-integrated energy storage system for nuclear-powered steam plant

Lazenby,

Shwageraus,

White

2023

Proceedings of the Institution of Mechanical Engineers, Part A:

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The paper provides thermodynamic analysis of an energy storage concept in which thermal stores are coupled with the feedwater heating train of nuclear-powered steam plant. This allows the electrical output of the plant to be flexed whilst maintaining constant reactor power, thereby providing the equivalent of an electricity storage system and facilitating the adoption of a load-following role for nuclear plant. The concept falls under the umbrella of ‘generation-integrated energy storage’, which exploits existing hardware required for generation to reduce storage costs, and benefits also from fewer energy transformations when compared to ‘electricity-in-electricity-out’ forms of storage. This means that a high (effective) round-trip efficiency can be achieved at low cost. An important feature of the proposed system is that the turbine bleed flows (at their various pressures and temperatures) automatically provide good thermal matching with the feedwater temperature profile, so that heat can ultimately be transferred to and from sensible-heat thermal-storage media with high exergetic efficiency. Various options are discussed for the thermal stores, including pressurised water tanks, thermal oils and packed beds. The analysis also includes consideration of the off-design behaviour of cycle components.

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Section: Thermal Storage Optionsmentioning

confidence: 99%

A feedheat-integrated energy storage system for nuclear-powered steam plant

Lazenby,

Shwageraus,

White

2023

Proceedings of the Institution of Mechanical Engineers, Part A:

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“…Heat exchanger models that capture real fluid behavior were developed [33]. As an example, consider heat transfer between supercritical CO2 and a mineral oil in the cold storage system of an sCO2 PTES cycle, see Figure 2 for reference.…”

Section: Heat Exchanger Modelsmentioning

confidence: 99%

Integrated Heat Pump Thermal Storage and Power Cycle for CSP (Final Technical Report)

McTigue

Farres-Antunez

White

et al. 2022

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Pumped thermal energy storage (PTES) is a storage system that stores electricity in thermal reservoirs. In this project, methods of integrating PTES with concentrating solar power (CSP) systems were investigated and their feasibility evaluated. Hybrid "solar-PTES" devices can provide both flexible renewable power generation as well as a variety of electricity storage services.Techno-economic models of PTES and solar-PTES were developed and used to assess their performance, cost, and commercial viability. Systems were optimized using multi-objective optimization techniques. The value that these storage devices provide to the grid was estimated using production cost modeling.Key advances made in this project include the development of detailed techno-economic models that improve state-of-the-art assessments of these technologies. Off-design models were developed and used in grid-analysis models. This work describes for the first time how PTES and solar-PTES behave over a range of operating points and assesses the value that these systems can provide to the electrical grid. Feedback was obtained from experts in the field, which clarified key technological and economic barriers that must be addressed to improve the feasibility of these devices.Several PTES and solar-PTES systems were investigated, using a variety of power cycles, working fluids, and storage fluids. The main technologies discussed in this report are (1) a PTES system that uses an ideal-gas Joule-Brayton cycle with nitrate molten salt storage (2) a solar-PTES system where an existing CSP plant is retrofitted with a Joule-Brayton heat pump that can "top up" the shared molten salt storage. Other cycles that use supercritical CO2 are also discussed and evaluated.Simple thermodynamic models were first developed of a variety of PTES and solar-PTES concepts. Results were used to determine which systems were the most promising and merited further research. More detailed techno-economic models were then built. The technical models captured the performance of each component in the system. In particular, quality representations of heat exchangers were required, and the models were successfully validated against experimental results taken from the literature. The off-design performance of each component was modeled which enabled evaluation of PTES and solar-PTES performance at variable part load and ambient temperature. The system capital cost and levelized cost of storage (LCOS) were estimated by obtaining cost correlations for each component from the literature. Several correlations were used for each component, which enabled the use of a Monte-Carlo technique to calculate the likely cost and its uncertainty. This analysis emphasized the importance of heat exchanger design on the system performance, and high values of effectiveness (over 90%) are required to achieve reasonable round-trip efficiencies. It was found that this high effectiveness also minimized the lifetime cost (LCOS).The techno-economic models were integrated with a stochastic multi-objective opt...

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“…Note that a number of minor losses have been ignored, including mechanical (friction) losses, fan and circulating pump work, and motor/generator losses. Quantifying these accurately requires much more detailed design but, based on other studies [27], they might be expected to reduce the efficiency by a further 5-10%.…”

Section: Thermodynamic Indicatorsmentioning

confidence: 99%

“…In order to benefit from the low marginal energy costs described above (and recognising that unit power costs are likely to be high due to the high HWR and low power density), Z P is estimated for a nominal design with 100 MWh e / 5 MW capacity (i.e., with 20 hrs discharge duration). McTigue et al [27] present a compilation of cost correlations of process equipment often employed in PTES systems, many of which are also used in this work. In particular, cost correlations for compressors and turbines are taken from Refs.…”

Section: Estimate Of Marginal Power Cost Z Pmentioning

confidence: 99%