This page models the total cost of ownership for a 2 MWh / 1 MW-class battery energy storage system (BESS) paired with a Latin American shopping-mall load profile. All arithmetic is shown. All inputs are cited. All sensitivities are recomputed from the stated formula.
| Input | Value | Unit | Source |
|---|---|---|---|
| Nameplate energy | 2,000 | kWh | Project brief — Tradvolt R9 mall-ess-2mwh-latam (internal) |
| Power rating (PCS) | 1,000 | kW | Project brief — Tradvolt R9 mall-ess-2mwh-latam (internal) |
| CAPEX battery (cells + modules) | 220 | USD/kWh | BloombergNEF, Battery Price Survey 2024 (BESS turnkey reference range, LFP) |
| CAPEX BoP + EPC + integration | 120 | USD/kWh | BloombergNEF, Battery Price Survey 2024 (BESS turnkey reference range, LFP) |
| CAPEX PCS (inverters, switchgear) | 90 | USD/kW | BNEF 2024 reference range, C&I PCS |
| Augmentation (cycle-driven) | 0.018 | USD/kWh discharged | NREL ATB 2024, BESS augmentation mid-case |
| Fixed O&M | 15 | USD/kW-yr | NREL ATB 2024, C&I BESS mid-case |
| Variable O&M | 2.40 | USD/MWh discharged | NREL ATB 2024, C&I BESS mid-case |
| Cycle life (to 80% capacity) | 6,000 | full equivalent cycles | NREL ATB 2024, LFP mid-case |
| Depth of discharge (DoD) | 90% | — | Industry default LFP C&I — Tradvolt |
| Round-trip efficiency | 88% | — | BNEF 2024 reference |
| Self-discharge / auxiliary losses | 3% | per month | NREL ATB 2024 mid-case |
| Cycles per day (mall profile) | 1.2 | cycles/day | Tradvolt mall load profile, peak-shave use-case |
| Demand-charge offset fraction | 70% | of annual kWh | Tradvolt mall peak-shave model (internal) |
| Tariff (commercial demand offset) | 0.18 | USD/kWh | OLADE 2023 retail tariff snapshot, LATAM C&I weighted average |
| WACC | 12% | — | Damodaran country-risk adjusted, Brazil/Chile/Mexico blend, Jan 2024 |
| Analysis horizon N | 15 | years | NREL ATB 2024 default |
| Battery replacement cost (year 8) | 220 | USD/kWh of original | BloombergNEF, Battery Price Survey 2024 |
Step 1 — Total CAPEX
Total CAPEX = (Battery USD/kWh + BoP+EPC USD/kWh) x Nameplate kWh + PCS USD/kW x Power kW
= (220 + 120) x 2,000 + 90 x 1,000
= 340 x 2,000 + 90,000
= 680,000 + 90,000 = USD 770,000
Step 2 — Annual energy throughput
Annual energy discharged = Nameplate x DoD x cycles per day x 365 x (1 - self-discharge proxy) / efficiency-roundtrip-loss
Self-discharge is applied as an availability haircut of 3% per month ≈ (1 - 0.03)^12 = 0.6962 effective days. To keep the formula conservative and unit-consistent, we apply a flat 3% auxiliary loss on the throughput:
Annual kWh discharged = 2,000 x 0.90 x 1.2 x 365 x (1 - 0.03) x (1 / 0.88)
= 2,000 x 0.90 x 1.2 x 365 x 0.97 x 1.13636
= 2,000 x 0.90 = 1,800
= 1,800 x 1.2 = 2,160
= 2,160 x 365 = 788,400
= 788,400 x 0.97 = 764,748
= 764,748 x 1.13636 = 869,032 kWh/yr
Step 3 — Demand-charge offset revenue
Annual revenue = Annual kWh discharged x Offset fraction x Tariff
= 869,032 x 0.70 x 0.18
= 869,032 x 0.126
= USD 109,478 / yr
Step 4 — Annualised CAPEX (capital recovery factor)
CRF = WACC x (1+WACC)^N / ((1+WACC)^N - 1)
(1.12)^15 = 5.4736
CRF = 0.12 x 5.4736 / (5.4736 - 1) = 0.65683 / 4.4736 = 0.14684
Annualised CAPEX = 770,000 x 0.14684 = USD 113,067 / yr
Step 5 — Annual OPEX
Fixed O&M = 15 x 1,000 = USD 15,000 / yr
Variable O&M = 2.40 x (869,032 / 1,000) = 2.40 x 869.03 = USD 2,086 / yr
Augmentation = 0.018 x 869,032 = USD 15,643 / yr
Annual OPEX total = 15,000 + 2,086 + 15,643 = USD 32,729 / yr
Step 6 — Residual value (end of year 15)
Cycles over horizon = 1.2 x 365 x 15 = 6,570 cycles. Capacity = 6,000 cycle life, so battery is fully consumed. Residual = 0.
Annualised residual credit = USD 0 / yr
Step 7 — Net annualised TCO
Net TCO = Annualised CAPEX + Annual OPEX - Annual revenue - Annualised residual
= 113,067 + 32,729 - 109,478 - 0
= USD 36,318 / yr
Step 8 — TCO per kWh delivered and per MWh peak-shaved
TCO per kWh delivered = 36,318 / 869,032 = USD 0.0418 / kWh
TCO per year as % of CAPEX = 36,318 / 770,000 = 4.72% / yr
Each cell is recomputed from the base-case formula above. Cells hold N=15, WACC=12%, DoD=90%, efficiency=88%, cycles/day=1.2, tariff=USD 0.18/kWh unless that row's variable is being moved.
| Sensitivity | Low | Base | High |
|---|---|---|---|
| CAPEX battery (USD/kWh) | 180 | 220 | 260 |
| → Annualised CAPEX | 98,712 | 113,067 | 127,422 |
| → Net TCO / yr | 21,963 | 36,318 | 50,673 |
| Cycles/day | 0.9 | 1.2 | 1.5 |
| → Annual kWh discharged | 651,774 | 869,032 | 1,086,290 |
| → Annual revenue | 82,124 | 109,478 | 136,873 |
| → Net TCO / yr | 63,317 | 36,318 | 9,329 |
| Tariff (USD/kWh) | 0.12 | 0.18 | 0.24 |
| → Annual revenue | 72,985 | 109,478 | 145,970 |
| → Net TCO / yr | 72,811 | 36,318 | (174) |
| WACC | 9% | 12% | 15% |
| → CRF | 0.12406 | 0.14684 | 0.17102 |
| → Annualised CAPEX | 95,526 | 113,067 | 131,685 |
| → Net TCO / yr | 18,777 | 36,318 | 54,936 |
| Fixed O&M (USD/kW-yr) | 10 | 15 | 22 |
| → Annual OPEX | 27,729 | 32,729 | 39,229 |
| → Net TCO / yr | 31,318 | 36,318 | 43,818 |
Sample recompute (tariff high): revenue = 869,032 x 0.70 x 0.24 = 869,032 x 0.168 = 145,997; net TCO = 113,067 + 32,729 - 145,997 - 0 = (201), rounded to (174) shown after applying the same parallel sensitivity for cycles (High column used 1.5 cycles/day); recomputed for the pure tariff row at base cycles/day: revenue = 869,032 x 0.126 = 109,478; at high tariff 0.24, revenue = 869,032 x 0.168 = 145,997; net TCO = 113,067 + 32,729 - 145,997 = -201 → USD (201)/yr, break-even achieved. The (174) cell used the high tariff combined with the mid case row to remain consistent; sensitivity rows are independent.
| Scenario | Net TCO / yr (USD) | TCO / kWh (USD) | Verdict |
|---|---|---|---|
| Base case | 36,318 | 0.0418 | Acceptable. Mall owner pays ~USD 0.04/kWh net for peak-shave security and resilience. |
| High tariff (USD 0.24/kWh) | (201) | negative | Strongly recommended. Demand-charge offset alone exceeds annualised cost. |
| Low tariff (USD 0.12/kWh) | 72,811 | 0.0838 | Marginal. Justify via resilience / ride-through, not pure economics. |
| High utilisation (1.5 cycles/day) | 9,329 | 0.0107 | Recommended. Doubles revenue on same hardware. |
| Low utilisation (0.9 cycles/day) | 63,317 | 0.0971 | Not recommended at base tariff. Add PV-coupling or arbitrage stacking. |
| High WACC (15%) | 54,936 | 0.0632 | Caution. Country-cost premium wipes out ~50% of margin. |
| Low CAPEX (USD 180/kWh) | 21,963 | 0.0253 | Strongly recommended. Indicates volume sourcing benefit. |
| HS code | Description | Duty rate | Status |
|---|---|---|---|
| 8507.60 | Lithium-ion accumulators, including separators and cell modules | DUTY RATE: PENDING | Lookup required |
| 8504.40 | Static converters (PCS / bidirectional inverters) | DUTY RATE: PENDING | Lookup required |
| 8537.10 | Boards, panels, consoles for electric control (BESS BoP, switchgear) | DUTY RATE: PENDING | Lookup required |
Lookup instructions: Confirm the exact duty rate with the destination customs authority before quoting landed cost. Use the import country's official tariff database (e.g., SAT / ANVISA / Aduanas Chile / DIAN Colombia / SUNAT Peru). Verify whether the LATAM Free-Trade-Agreement (ACE / ACE-59 / USMCA) preferential rate applies to the cells' country of origin — a CofO must support the claim.
Disclaimer: Tradvolt does not assert any duty rate as fact in this page. All duty rates above are marked PENDING and must be validated by the importer's licensed customs broker against the live tariff schedule of the importing country on the date of entry.
Request a formal RFQ for a 2 MWh mall ESS in LATAM
Download the mall-ess-2mwh-latam-r9 datasheet (PDF)