Comprehensive Modeling of Temperature-Dependent Degradation Mechanisms in Lithium Iron Phosphate Batteries

Thursday, 5 October 2017: 08:40
National Harbor 8 (Gaylord National Resort and Convention Center)
M. Schimpe, M. Edler von Kuepach, M. Naumann, H. C. Hesse (Technical University of Munich, Germany), K. Smith (National Renewable Energy Laboratory), and A. Jossen (Technical University of Munich)
Today, stationary energy storage systems utilizing lithium-ion batteries account for the majority of new storage capacity installed. In order to meet technical and economic requirements, the specified system’s lifetime has to be ensured.

For reliable lifetime predictions, models for cell degradation are necessary. Physicochemical models that include ageing mechanisms are based on a detailed set of parameters, which are often not available, and require parametrization of the degradation rates. Instead, purely empirical models can be parametrized without knowledge of internal cell setup through extensive testing, however are prone to extrapolation errors due to the utilized mathematical functions. In this work, a semi-empirical model based on a reduced set of internal cell parameters and physically supported degradation functions is used (1).

Due to the limited knowledge about degradation mechanisms, purely empirical models as well as semi-empirical models tend to lump multiple degradation effects into single functions. This leads to prediction errors when deviating from the parametrization test conditions. E.g. for cycle ageing, Waldmann et al. reported a transition of dominating ageing mechanisms at 25°C (2). The ageing above 25°C was attributed to SEI-growth and cathode degradation, for temperatures below 25°C to lithium plating. Model development therefore should aim for a separation of the degradation mechanisms where possible. The respective mechanisms then can be modelled through functions that are suitable for the degradation driving factors, which is the focus of this work:

A semi-empirical cell degradation model is developed that separates one calendar and several cycle ageing effects. Emphasis is placed on the varying degradation at different temperatures. Degradation for cycle ageing at high and low temperatures is thus calculated separately, a novel approach in semi-empirical models.

As such models require parametrization, a lifetime test study is conducted. Cell type and experimental parameters are in accordance with an application in stationary systems. Lithium iron phosphate batteries have shown capacity retention for more than 5,000 full cycles before usable capacities fall below 80%, which is suitable for stationary applications (3). The parametrization is based on a commercial 26650 lithium iron phosphate cell with a nominal capacity of 3 Ah. The lifetime study is separated into parametrization and validation tests. Validation tests are excluded from model parametrization and thus show the model performance in deviating, more realistic conditions.

Temperatures in the tests are 0°C, 10°C, 15°C, 25°C, 35°C, 45°C and 55°C to accurately describe varying degradation mechanisms. Parametrization for calendar ageing consists of storage tests of cells at varying State of Charge (SOC) in steps of 12.5%. Cycle ageing parametrization is based on constant current full cycle tests at C-Rates of 0.5C, 1C and 1.7C with and without CV-phases at the end of charging. For validation, a dynamic profile representative for a summer and a winter day of a residential photovoltaic-battery system is tested. Regular characterization tests were performed at 25°C. As experimental results for the degradation in terms of capacity loss showed to be more severe than an impedance increase, we focused on modelling the battery capacity.

Calendar ageing is modelled with temperature and anode-potential dependency based on the storage tests. Figure 1a shows the Arrhenius-dependency of the capacity loss rate at SOC of 100% for temperatures between 10°C and 45°C. Figure 1b shows the relation between anode open circuit potential and calendar ageing at a storage temperature of 25°C for SOC between 0% and 100%.

For cycle ageing, degradation mechanisms are separated in low and high temperature effects and parametrized based on the constant-current tests. Cell degradation can thus be given as the linear combination of separate mechanisms. Figure 2 shows the cycle-induced capacity loss rate occurring additionally to comparative storage tests over temperatures from 0°C to 55°C. High and low temperature mechanisms are separately calculated.

Summarizing, the model enables a cell degradation simulation over a wide temperature range. Through independent, yet temperature-dependent calculation of calendar and cycle ageing effects detailed studies on the effect of thermal management are enabled.

Details on the prediction performance against the validation tests and model limitations are given in the presentation. Finally, model results for real-world grid applications as well as strategies for optimized operation temperatures are presented and evaluated.


1. S. Santhanagopalan, K. Smith, J. Neubauer, G.-H. Kim, A. Pesaran and M. Keyser, Design and analysis of large lithium-ion battery systems, Artech House (2014).

2. T. Waldmann, M. Wilka, M. Kasper, M. Fleischhammer and M. Wohlfahrt-Mehrens, Journal of Power Sources, 262, 129–135 (2014).

3. Masayuki Yasuda, in OREBA 1.0 - International Conference on Olivines for Rechargeable Batteries (2014).