Comprehensive Modeling of Temperature-Dependent Degradation Mechanisms in Lithium Iron Phosphate Batteries
Abstract
For reliable lifetime predictions of lithium-ion batteries, models for cell degradation are required. A comprehensive semi-empirical model based on a reduced set of internal cell parameters and physically justified degradation functions for the capacity loss is developed and presented for a commercial lithium iron phosphate/graphite cell. One calendar and several cycle aging effects are modeled separately. Emphasis is placed on the varying degradation at different temperatures. Degradation mechanisms for cycle aging at high and low temperatures as well as the increased cycling degradation at high state of charge are calculated separately. For parameterization, a lifetime test study is conducted including storage and cycle tests. Additionally, the model is validated through a dynamic current profile based on real-world application in a stationary energy storage system revealing the accuracy. Tests for validation are continued for up to 114 days after the longest parametrization tests. In conclusion, the model error for the cell capacity loss in the application-based tests is at the end of testing below 1% of the original cell capacity and the maximum relative model error is below 21%.
- Authors:
-
[1];
[2];
- Technical Univ. of Munich (TUM), Munich (Germany)
- National Renewable Energy Lab. (NREL), Golden, CO (United States)
- Publication Date:
- Research Org.:
- National Renewable Energy Laboratory (NREL), Golden, CO (United States)
- Sponsoring Org.:
- USDOE Office of Energy Efficiency and Renewable Energy (EERE), Vehicle Technologies Office (EE-3V)
- OSTI Identifier:
- 1421782
- Report Number(s):
- NREL/JA-5400-70616
Journal ID: ISSN 0013-4651
- Grant/Contract Number:
- AC36-08GO28308
- Resource Type:
- Accepted Manuscript
- Journal Name:
- Journal of the Electrochemical Society
- Additional Journal Information:
- Journal Volume: 165; Journal Issue: 2; Journal ID: ISSN 0013-4651
- Publisher:
- The Electrochemical Society
- Country of Publication:
- United States
- Language:
- English
- Subject:
- 25 ENERGY STORAGE; lithium-ion battery; life model; degradation; aging; energy storage
Citation Formats
Schimpe, Michael, von Kuepach, M. E., Naumann, M., Hesse, H. C., Smith, Kandler A., and Jossen, A. Comprehensive Modeling of Temperature-Dependent Degradation Mechanisms in Lithium Iron Phosphate Batteries. United States: N. p., 2018.
Web. doi:10.1149/2.1181714jes.
Schimpe, Michael, von Kuepach, M. E., Naumann, M., Hesse, H. C., Smith, Kandler A., & Jossen, A. Comprehensive Modeling of Temperature-Dependent Degradation Mechanisms in Lithium Iron Phosphate Batteries. United States. https://doi.org/10.1149/2.1181714jes
Schimpe, Michael, von Kuepach, M. E., Naumann, M., Hesse, H. C., Smith, Kandler A., and Jossen, A. Fri .
"Comprehensive Modeling of Temperature-Dependent Degradation Mechanisms in Lithium Iron Phosphate Batteries". United States. https://doi.org/10.1149/2.1181714jes. https://www.osti.gov/servlets/purl/1421782.
@article{osti_1421782,
title = {Comprehensive Modeling of Temperature-Dependent Degradation Mechanisms in Lithium Iron Phosphate Batteries},
author = {Schimpe, Michael and von Kuepach, M. E. and Naumann, M. and Hesse, H. C. and Smith, Kandler A. and Jossen, A.},
abstractNote = {For reliable lifetime predictions of lithium-ion batteries, models for cell degradation are required. A comprehensive semi-empirical model based on a reduced set of internal cell parameters and physically justified degradation functions for the capacity loss is developed and presented for a commercial lithium iron phosphate/graphite cell. One calendar and several cycle aging effects are modeled separately. Emphasis is placed on the varying degradation at different temperatures. Degradation mechanisms for cycle aging at high and low temperatures as well as the increased cycling degradation at high state of charge are calculated separately. For parameterization, a lifetime test study is conducted including storage and cycle tests. Additionally, the model is validated through a dynamic current profile based on real-world application in a stationary energy storage system revealing the accuracy. Tests for validation are continued for up to 114 days after the longest parametrization tests. In conclusion, the model error for the cell capacity loss in the application-based tests is at the end of testing below 1% of the original cell capacity and the maximum relative model error is below 21%.},
doi = {10.1149/2.1181714jes},
journal = {Journal of the Electrochemical Society},
number = 2,
volume = 165,
place = {United States},
year = {Fri Jan 12 00:00:00 EST 2018},
month = {Fri Jan 12 00:00:00 EST 2018}
}
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