Comprehensive modeling of temperature-dependent degradation mechanisms in lithium iron phosphate batteries
Open accessAbstract
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. 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%.
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Most existing studies model battery cyclic and calendar aging independently and combine the two to make predictions under a dynamic load profile.
“Most of the existing studies model the battery cyclic and calendar aging independently, and combine the two to make predictions under a dynamic load profile [6,94,95].”
From Data-driven health estimation and lifetime prediction of lithium-ion batteries: A review (2019) · cites this paper as [95]
The Abstract says several empirical studies model calendar or cycle aging without evaluating interdependencies, and some approaches combine the two by superposition. The Conclusions describe this paper’s validation against dynamic current profiles. Our copy does not establish that most existing studies use the combined approach to predict aging under dynamic loads. (LLM, conf=0.84)
Experimental — accuracy not yet measuredCurrent rate and DOD dependence on cyclic ageing can be modelled with exponential or polynomial functions.
“The current rate and DOD dependence on cyclic ageing can be modelled with exponential [95,102] or polynomial [102] functions.”
From Data-driven health estimation and lifetime prediction of lithium-ion batteries: A review (2019) · cites this paper as [95]
The Cycle aging model section models charge-current dependence with an exponential correlation (Eq. 17). But it explicitly says depth of discharge is not an input to the cycle model, and the cited passages do not support a polynomial dependence for either variable. Page numbers are unavailable in our copy. (LLM, conf=0.90)
Experimental — accuracy not yet measuredSOC dependence on calendar ageing lifetime is typically fitted by linear functions, exponential functions, or the Tafel equation.
“In contrast, the SOC dependence on calendar ageing lifetime is typically fitted by linear functions [100], exponential functions [99] or by the Tafel equation [95].”
From Data-driven health estimation and lifetime prediction of lithium-ion batteries: A review (2019) · cites this paper as [95]
Capacity loss due to calendar ageing is usually proportional to a power law relation with time, weighted by influences of temperature and storage SOC, represented by a stress factor.
“The capacity loss due to calendar ageing is usually proportional to a power law relation with time 𝑡, weighted by the influences of temperature 𝑇 and storage SOC, what can be represented by some stress factor 𝑘 [95]:”
From Data-driven health estimation and lifetime prediction of lithium-ion batteries: A review (2019) · cites this paper as [95]
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- Authors
- Schimpe, M., von Kuepach, M. E., Naumann, M., Hesse, H. C., Smith, K., & Jossen, A.
- Affiliations
- Technical University of Munich (DE)
- National Laboratory of the Rockies (US)
- Venue
- Journal of The Electrochemical Society
- Publisher
- The Electrochemical Society
- Published
- 2018
- Volume
- 165
- Issue
- 2
- Pages
- A181-A193
- ISSN
- 0013-4651 (ISSN-L)
- 1945-7111
- OpenAlex
- W2782996909
- Cited by
- 238
- References
- 26
- Citations by year
- 2026: 40 · 2025: 30 · 2024: 38 · 2023: 28 · 2022: 34 · 2021: 37 · 2020: 17 · 2019: 9 · 2018: 5
- FWCI
- 9.04
- Type
- journal article
- Language
- en
- Open access
- hybrid
- doi.org
- Licence
- cc-by
- Locations
- Journal of The Electrochemical Society (publishedVersion, cc-by)
- OSTI OAI (U.S. Department of Energy Office of Scientific and Technical Information) (submittedVersion)
- mediaTUM – the media and publications repository of the Technical University Munich (Technical University Munich) (submittedVersion, other-oa)
- Funders
- Bundesministerium für Wirtschaft und Energie (Federal Ministry for Economic Affairs and Energy) (03ET1205G)
- Department of Energy | National Renewable Energy Laboratory, Office of Energy Efficiency and Renewable Energy (NREL) (AC36-08GO28308)
- Topics
- Physical Sciences › Engineering › Automotive Engineering › Advanced Battery Technologies Research
- Physical Sciences › Engineering › Electrical and Electronic Engineering › Advancements in Battery Materials
- Physical Sciences › Engineering › Mechanical Engineering › Extraction and Separation Processes
- Keywords
- lithium iron phosphate batteries, battery degradation modeling, temperature-dependent degradation, capacity fade, calendar aging, cycle aging, battery lifetime prediction, semi-empirical model, stationary energy storage
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