Journal of Power Sources

This data is from a comprehensive cycle aging study on a lithium-ion battery with a test duration of 29 months: Naumann, M. et al.; Analysis and modeling of cycle aging of a commercial LiFePO4/graphite cell; Journal of Power Sources (2020), Volume 451; DOI: 10.1016/j.jpowsour.2019.227666 This aging study presents cycle aging results of a commercial lithium-ion cell from a comprehensive, 29 month aging study and follows up on calendar aging results published previously [1]. We use a widely used commercial LiFePO 4 /graphite cell from Sony/Murata, which promises long calendar and cycle lifetime, that would make it suitable for stationary battery applications. The evolution of the cells’ capacity and impedance are shown in a static cycle aging study for 19 test points with different combinations of temperature, C-rate, depth of discharge and state of charge. Based on the measurement data shown herein and the calendar aging model presented in the previous paper, a semi-empirical combined aging model is presented for the capacity loss and resistance increase. Two dynamic load profiles are used to experimentally validate the combined aging model. Absolute model errors below 1% for the capacity loss and below 2% for the resistance increase in both dynamic load profiles demonstrate that the combined aging model can predict the lifetime of LiFePO 4 /graphite battery cells for different applications and varying operation conditions adequately. In the cycle experiments, an unexpectedly strong, but partly reversible capacity loss is observed with shallow cycles at medium states of charge.

The file includes the test data at flooding and dehydration states, from two different PEMFC systems (PEMFC 1 and PEMFC 2).

Step-wise computation of the electron transfer paramerters and the respective probability of reaction.

Simulink model of the thyristor rectifier

Fig. 4. Average temperature of battery cells over time for the simulated cases: (a) cases with 4 mm thick PCM, (b) cases with 5 mm thick PCM, (c) cases with 6 mm thick PCM. Fig. 5. Liquid fraction of PCM over time for the simulated cases: (a) cases with 4 mm thick PCM, (b) cases with 5 mm thick PCM, (c) cases with 6 mm thick PCM. Fig. 8. Maximum temperature difference among cells over time for the simulated cases: (a) cases with 4 mm thick PCM, (b) cases with 5 mm thick PCM, (c) cases with 6 mm thick PCM.

This data includes: 1. The battery dynamic stress test (DST) raw data recorded by battery test system (Neware BTS-4008 battery test system); 2. Experiment voltage and current of DST after removing the repetition time points; 3. Offline model identification results of time-varying model based on first-order RC battery model; 4. Simulative battery Vp and current for simulation verification for identification biases under noise corruptions; 5. Simulative battery voltage and current for assessing the co-estimation algorithms under noise corrupted measurements; 6. Experiment battery voltage and current for assessing the co-estimation algorithms under noise corrupted measurements.

Raw data for all tests cited in Table 2.

PEM fuel cell stack test data including both stack flooding and humidification sensor fault

Cell (m,n), where m represents the testing condition ID, n represents the cell ID in testing condition "m"; In each cell, the first column is the cycle number, the second column is the capacity.

The two files contain the heat release and peak parameters for anode (Graphite) and cathode (NMC11).