Optimal planning of electricity storage to minimize operating reserve requirements in an isolated island grid
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Optimal planning of electricity storage to minimize operating reserve requirements in an isolated island grid Pavlos Nikolaidis1 · Sotirios Chatzis1 · Andreas Poullikkas2 Received: 28 February 2019 / Accepted: 13 August 2019 © Springer-Verlag GmbH Germany, part of Springer Nature 2019
Abstract Electrical energy storage (EES) constitutes a potential candidate capable of regulating the power generation to match the loads via time-shifting. Optimally planned, EES facilities can meet the increasing requirement of reserves to manage the variability and uncertainty of renewable energy sources (RES) whilst improving the system operation efficiency and economics. In this work, the impact of intermittent RES on total production cost (TPC) is evaluated in the presence and absence of storage, using annual data regarding the non-interconnected power system of the island of Cyprus. Performing weekly simulations for the entire year of 2017, TPC is computed by solving the unit commitment based on a constrained Lagrange Relaxation method. Seven selected EES technologies are modeled and evaluated via a lifecycle cost analysis, based on the most realistic technical and cost data found in the literature. The results derived from the uncertainty analysis performed, show that zinc-air (Zn-air) battery offers the highest net present value (NPV). Lead-acid (Pbacid) and sodium-sulfur (Na-S) are considered viable solutions in terms of mean NPV and investment risk. Lithium-ion (Li-ion) battery exhibits a particularly expensive choice. Dominated by its increased capital cost which still governs its overall cost performance Li-ion achieves a negative mean NPV far below zero. However, to strengthen the benefits derived from EES integration, further research and development is needed improving the performance and costs of storage. The uncertainty governing the majority of EES technologies, in turn, will be reduced, increasing their participation and RES contribution in autonomous power system operations. Keywords Electrical energy storage · Non-interconnected power system · Lagrange Relaxation · Life-cycle cost analysis · Uncertainty analysis · Autonomous power systems
* Andreas Poullikkas [email protected] Extended author information available on the last page of the article
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Abbreviations APR Annual profitable return CBM Base maintenance cost CBOP Balance of plant cost CE Emission cost CENS Cost of energy not served CESM Cost of energy storage medium CF Fuel cost CfO&M Fixed operation and maintenance cost CIM Incremental maintenance cost CM Maintenance cost CO&M Annual operation and maintenance cost CPCS Cost of power conversion system CSD Shut-down cost CSU Start-up cost CSU Cold start-up cost CvO&M Variable operation and maintenance cost DoD Depth of discharge Ecap Energy capacity Ed-y Total discharging energy per year hs Storage duration HSU Hot start-up cost iR Discount rate IPC Initial project cost J* Total relaxed cost λ Lagrange multiplier LCC Life-cycle cost of s
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