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Title: 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:
ORCiD logo [1];  [1];  [1];  [1]; ORCiD logo [2];  [1]
  1. Technical Univ. of Munich (TUM), Munich (Germany)
  2. National Renewable Energy Lab. (NREL), Golden, CO (United States)
Publication Date:
Research Org.:
National Renewable Energy Lab. (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:
Journal Article: 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. doi: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. doi: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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