Battery Storage Cost Trends: 2020-2024
Li-ion battery costs fell 89% from 2010 to 2024, but the path wasn't linear — a price spike in 2022 was followed by the sharpest annual decline ever. Here's what happened.
Key takeaway
Li-ion battery pack prices hit $115/kWh in 2024 — down from $137/kWh in 2020 and $1,200/kWh in 2010. Grid-scale system CAPEX (4h duration) is $196–475/kWh depending on source and geography. The LCOS for utility-scale storage is now $0.08–0.20/kWh, making storage competitive with gas peakers in most markets.
Li-ion pack price trend ($/kWh)
Post-COVID recovery, Li-ion pack average
Supply chain tightening begins
Lithium spike, first price increase since tracking began
Lithium crash (-80%), LFP gains share
LFP dominant, Chinese overcapacity drives prices down
Source: BloombergNEF Lithium-Ion Battery Pack Price Survey
Grid-scale system costs (2024)
| Source | CAPEX ($/kWh) | LCOS ($/kWh) | Duration |
|---|---|---|---|
| IRENA 2024 | 250–475 | 0.10–0.20 | 4h |
| Lazard LCOS 8.0 | 234–456 | 0.12–0.18 | 4h |
| BNEF 2024 | 196–340 | 0.08–0.15 | 4h |
| NREL ATB 2024 | 220–380 | 0.09–0.16 | 4h |
What's driving costs down (and up)
Chemistry shift: NMC to LFP
Lithium iron phosphate (LFP) has overtaken nickel-manganese-cobalt (NMC) as the dominant grid storage chemistry. LFP is 15-25% cheaper per kWh, has better cycle life (6,000+ cycles vs 3,000-4,000), and avoids cobalt/nickel supply risks. The trade-off is lower energy density, which matters less for stationary storage.
Lithium price volatility
Lithium carbonate spiked to $80,000/tonne in late 2022, driving the first-ever annual increase in pack prices. By late 2023, prices collapsed to $15,000/tonne due to new supply from Australia, Chile, and China. This 80% drop flowed through to a ~20% reduction in cell-level costs.
Chinese manufacturing overcapacity
CATL, BYD, EVE Energy, and other Chinese manufacturers expanded capacity aggressively in 2022-2023. By 2024, global LFP cell manufacturing capacity exceeded demand by ~2x. This overcapacity is pushing prices below production costs for some manufacturers, creating a buyer's market for project developers.
Duration premium is shrinking
The cost premium for longer-duration systems (6-8h vs 2-4h) has narrowed as cell costs fall. Cells now represent ~35-40% of total system cost (down from 50%+ in 2020). Balance-of-system costs (inverters, enclosures, EMS, installation) are increasingly the dominant cost component.
Augmentation and degradation
LCOS calculations depend heavily on assumed degradation rates and augmentation strategies. A system degrading at 2%/year over 15 years needs significant augmentation in years 8-15. BNEF uses a 1.5%/year assumption; Lazard uses 2.5%. This single assumption can shift LCOS by 20-30%.
Sources
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