Levelised Cost of Storage for Pumped Heat Energy Storage in comparison with other energy storage technologies

Smallbone, Andrew; Jülch, Verena; Wardle, Robin; Roskilly, Anthony Paul

doi:10.1016/j.enconman.2017.09.047

Cited by 194 publications

(73 citation statements)

References 20 publications

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“…• PTES based on a Brayton cycle with packed beds [6][7][8][9], sensible molten salt [5] or concrete as thermal storages [10,11]. • PTES based on transcritical CO2 with water as hot storage and latent water/ice as cold storage [12][13][14].…”

Section: A Pumped Thermal Energy Storage (Ptes)mentioning

confidence: 99%

Energy system design for deep decarbonization of a sunbelt city by using a hybrid storage approach

Walter¹,

Huber²,

Kueppers³

et al. 2019

Proceedings of the 13th International Renewable Energy Storage Conference 2019 (IRES 2019)

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With continuously falling cost of renewable power generation and ambitious decarbonization targets, renewable sources are about to rival fossil fuels for energy supply. For a high share of fluctuating renewable generation, large-scale energy storage is likely to be required. In addition to selling electricity, the reliable supply of heat and cold is a further interesting revenue pool, which makes hybrid storage technologies an interesting option. The main feature of hybrid energy storageas defined here-is to offer charging and especially discharging in different forms of energy by combining different charging, discharging and storage devices. They can address various demands (e.g. electricity and cold) simultaneously. Two hybrid storages, pumped thermal energy storage (PTES) and power-to-heat-to-x (x: heat and/or electricity) energy storage (PHXES), are investigated based on a technoeconomic analysis within this work. Both hybrid storage technologies are charged with electricity and can supply heat and electricity during discharging. They are implemented into a simplified energy system model of a prototype city in the earth's sunbelt in the year 2030 to find a cost-optimal configuration. Different cases are evaluated: a power-to-power case (P2P), where only an electric demand must be addressed and a power-topower-and-cooling (P2P&C) case, where the electric demand from the P2P case is divided into a residual electric demand and a cooling demand. For both cases, a natural gas-based benchmark scenario and a decarbonized, renewable-based scenario including the hybrid energy storage technologies are calculated. Both, total expenditures and CO2 emissions are lower in the P2P&C scenarios compared to P2P scenarios. PHXES plays a major role in both cases. PTES is part of the costoptimal solution in the P2P&C decarb scenario, only if its specific cost are further decreased.

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Section: A Pumped Thermal Energy Storage (Ptes)mentioning

confidence: 99%

Energy system design for deep decarbonization of a sunbelt city by using a hybrid storage approach

Walter¹,

Huber²,

Kueppers³

et al. 2019

Proceedings of the 13th International Renewable Energy Storage Conference 2019 (IRES 2019)

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“…PHES stores electricity as sensible heat in thermally insulated and closed-looped thermal storage systems which ensures that the system is isolated; hence, based on the design aspects outlined in [47], there is a guarantee that the model is feasible for deployment for our case study. The analysis of a proposed commercial PHES design with a maximum capacity of 16 MWh as detailed in [45,61] has been adopted as the benchmark for many studies in the literature; thus, the system technical and economic specifications are used in our work for the Kenyan microgrid under study.…”

Section: Off-peak Period Peak Periodmentioning

confidence: 99%

Multi-Objective Optimal Capacity Planning for 100% Renewable Energy-Based Microgrid Incorporating Cost of Demand-Side Flexibility Management

et al. 2019

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The need for energy and environmental sustainability has spurred investments in renewable energy technologies worldwide. However, the flexibility needs of the power system have increased due to the intermittent nature of the energy sources. This paper investigates the prospects of interlinking short-term flexibility value into long-term capacity planning towards achieving a microgrid with a high renewable energy fraction. Demand Response Programs (DRP) based on critical peak and time-ahead dynamic pricing are compared for effective demand-side flexibility management. The system components include PV, wind, and energy storages (ESS), and several optimal component-sizing scenarios are evaluated and compared using two different ESSs without and with the inclusion of DRP. To achieve this, a multi-objective problem which involves the simultaneous minimization of the loss of power supply probability (LPSP) index and total life-cycle costs is solved under each scenario to investigate the most cost-effective microgrid planning approach. The time-ahead resource forecast for DRP was implemented using the scikit-learn package in Python, and the optimization problems are solved using the Multi-Objective Particle Swarm Optimization (MOPSO) algorithm in MATLAB R . From the results, the inclusion of forecast-based DRP and PHES resulted in significant investment cost savings due to reduced system component sizing.Keywords: demand response program (DRP); photovoltaic system (PV); pumped heat energy storage (PHES); critical peak pricing (CPP) DRP; time-ahead dynamic pricing (TADP) DRP; loss of power supply probability (LPSP); energy storage system (ESS); Multi-Objective Particle Swarm Optimization (MOPSO)

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“…A.2. Specific cost of refractory, screfr 0.45 € kg -1 [72] Specific cost of sorbent, scCaO 0.02 € kg -1 [73] Specific cost of oxygen carrier, scCu 6 € kg -1 [73] Specific cost of catalyst, scNi 50 € kg -1 [72] Specific cost of inert, scAl2O3(NiO) 1 € kg -1 [73] Specific cost of heat exchanger/condenser, scHE/cond 241 € m -2 [70] Specific cost of hydrogen buffer, scbuffer 1,200 € m -3 [74] Specific cost of boiler, scB 150 € kW -1 [75] Specific cost of MCHP, scMCHP 2,500 € kW -1 [65] Specific cost of EHP, scEHP 500 € kW -1 [75] Unit price of natural gas, UPNG 0.013 € kWh -1 [76] Unit price of methane, UPCH4 0.019 € kWh -1 [76] Unit price of electric energy, UPee 0.1 € kWh -1 [77] Maintenance cost of boiler, MB 0.20 € h -1 [75] Maintenance cost of MCHP, MMCHP 0.20 € h -1 [75] Maintenance cost of EHP, MEHP 0.05 € h -1 [75] Maintenance cost of the proposed system, Mps 2% of TCRps per annum [76] CO2 transport and storage cost, CTS 82 € tCO2 -1 [78]…”

Section: A1 Energy and Environmental Analysismentioning

confidence: 99%

Feasibility of CaO/CuO/NiO sorption-enhanced steam methane reforming integrated with solid-oxide fuel cell for near-zero-CO2 emissions cogeneration system

et al. 2018

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In this article, a process for sorption-enhanced steam methane reforming in an adiabatic fixedbed reactor coupled with a solid oxide fuel cell (SOFC) is evaluated using a 1D numerical reactor model combined with a simplified fuel cell simulation. A novel material comprising CaO/CuO/Al2O3(NiO) pellets is considered. Three operating stages are considered in the proposed system, namely (i) CaO carbonation/reforming, (ii) Cu and Ni oxidation, and (iii) CaCO3 calcination/CuO and NiO reduction. The operating conditions that enable cyclic operation of these stages and the strategy needed to switch between each stage are evaluated. Under the adopted control strategy, methane conversion was about 95%, whilst H2 yield and purity were around 3.2 molH2 molCH4-1 and 90%, respectively. Moreover, a concentrated CO2 stream ready for storage was obtained. By using a portion of the produced H2 to make the process self-sufficient from an energy standpoint, an equivalent H2 yield and a reforming efficiency of about 2.8 molH2 molCH4-1 and 84% were achieved, respectively. With respect to SOFC integration, net power and thermal energy generation of around 11 kW and 6 kW, respectively, can be achieved. With respect to the chemical energy of the inlet methane, the net electrical and thermal efficiencies of the considered process are 56% and 30%, respectively, i.e., the overall efficiency of the entire system is 86%. The proposed cogeneration system showed better thermodynamic, environmental and economic performances than those of conventional systems, with an investment pay-back period of 2.2 years in the worst-case scenario. The levelised cost of electricity, of heat and total power were about 0.096 € kWh-1 , 0.19 € kWh-1 , and 0.065 € kWh-1 , respectively, while the CO2 emissions were avoided at no cost.

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Levelised Cost of Storage for Pumped Heat Energy Storage in comparison with other energy storage technologies

Cited by 194 publications

References 20 publications

Energy system design for deep decarbonization of a sunbelt city by using a hybrid storage approach

Energy system design for deep decarbonization of a sunbelt city by using a hybrid storage approach

Multi-Objective Optimal Capacity Planning for 100% Renewable Energy-Based Microgrid Incorporating Cost of Demand-Side Flexibility Management

Feasibility of CaO/CuO/NiO sorption-enhanced steam methane reforming integrated with solid-oxide fuel cell for near-zero-CO2 emissions cogeneration system

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