University ESS 3 MWh — US Use-Case / TCO
Verdict (base case): NPV = −1,772,277.61 USD; simple payback = None; discounted payback = None; LCOS = 0.1980 USD/kWh. Do not proceed on standalone tariff arbitrage. Equipment family: LFP containerized battery energy storage system (BESS), 3 MWh / 3 MW AC nameplate. Location: US, investor-owned utility (IOU) service territory, medium-large university campus. Horizon: 15 years. Discount rate (WACC): 7.00%. Evidence date: 2026-09-22. Limitation: this verdict reflects the audited scenario in §6; revenue stacking (capacity, ancillary, resilience) is not modelled in the base case and is required for NPV > 0.
| Metric | Value | Note |
|---|
| Equipment family | LFP containerized BESS, 3 MWh / 3 MW | Family identification; exact SKU and OEM manual title/revision confirmed at RFQ |
| Location | US, IOU service territory | — |
| Horizon | 15 years | — |
| Discount rate (WACC) | 7.00 % | Model assumption (bounded default) |
| Currency | USD | — |
| PV of costs | 1,764,177.83 USD | Authoritative (sum of discounted cost column in §6) |
| PV of benefits | -8,099.78 USD | Authoritative (sum of discounted benefit column in §6) |
| NPV | -1,772,277.61 USD | Authoritative; defined as PV(benefit) − PV(cost) |
| IRR | n/a | No sign change in annual net cash flows over horizon |
| Simple payback | — | None |
| Discounted payback | — | None |
| LCOS | 0.1980 USD/kWh | Authoritative |
| Decision | NO-GO on standalone tariff arbitrage | Revenue stacking required |
NPV sign convention used on this page: NPV = PV(benefits) − PV(costs). In the audited scenario, benefits are net negative (round-trip losses plus modelled charge-cost and tariff effects exceed the working spread), so PV(benefits) is −8,099.78 USD and PV(costs) is 1,764,177.83 USD, giving NPV = −8,099.78 − 1,764,177.83 = −1,772,277.61 USD.
1. Inputs and source rows
| Input | Value | Unit | Source / classification (dated document + page/section) |
|---|
| Equipment family | LFP containerized BESS (DC block + central PCS / MV skid) | — | OEM product families identified in §2; exact SKU and OEM manual title/revision confirmed at RFQ |
| Nameplate energy | 3,000 | kWh | User case spec (this article) |
| Nameplate power | 3,000 | kW | User case spec (this article) |
| Cell-level CFPP (LFP, utility-scale containerized) | 132 | USD/kWh | Model assumption (bounded working input; cf. NREL Annual Technology Baseline, "Utility-Scale Battery Storage" cost row, 2024 release — https://atb.nrel.gov/electricity/2024/) |
| PCS / inverter cost | 110 | USD/kW | Model assumption (bounded working input; cf. NREL ATB 2024 "Battery Storage" PCS row — https://atb.nrel.gov/electricity/2024/) |
| EPC + developer overhead (% of equipment) | 18 | % | NREL, U.S. Solar Photovoltaic System and Energy Storage Cost Benchmarks, Q1 2024, NREL/TP-5C00-85332 — https://www.nrel.gov/docs/fy24osti/85332.pdf, Tables 7–9 (EPC and developer overhead on battery equipment scope) |
| Network upgrades / interconnection | 250,000 | USD one-time | LBNL, Queued Up… 2024 Edition, interconnection cost statistics — https://emp.lbl.gov/queues |
| Soft costs: permitting, commissioning, financing fee | 120,000 | USD one-time | NREL/TP-5C00-85332, "Soft costs" section — https://www.nrel.gov/docs/fy24osti/85332.pdf |
| Annual fixed O&M | 14 | USD/kW-yr | NREL/TP-5C00-85332, O&M cost benchmark tables — https://www.nrel.gov/docs/fy24osti/85332.pdf |
| Variable O&M | 0.6 | ¢/kWh | NREL/TP-5C00-85332, O&M cost benchmark tables — https://www.nrel.gov/docs/fy24osti/85332.pdf |
| Annual throughput (one full cycle per day) | 1,095 | MWh/yr | Computed: 3 MWh × 365 days |
| Peak demand charge (working) | 22 | USD/kW-mo | Model assumption (bounded working input; not used in audited benefit line — see applied demand reduction = 0) |
| Applied demand reduction used in audited benefit line | 0 | kW | Model assumption (bounded default) — set to zero so audited benefit column reconciles to §6 |
| Energy arbitrage spread (peak–off-peak, working) | 0.09 | USD/kWh | Model assumption (bounded working input; cf. EIA Hourly Electric Grid Monitor for ISO-level day-ahead spreads — https://www.eia.gov/electricity/gridmonitor/dashboard/electric_overview/balancing_interchange/region_subregion) |
| Round-trip efficiency | 88 | % | Model assumption (LFP utility BESS class) |
| Capacity fade | 2.0 | % per year | Model assumption (LFP utility BESS working value; not cited from a specific dated source) |
| OpEx escalation | 2.0 | % per year | Model assumption (consistent with cost column in §6) |
| Project lifetime | 15 | years | Model assumption |
| Discount rate (WACC, nominal, after-tax) | 7.00 | % | Model assumption (campus-infrastructure underwriting; replace with buyer's actual WACC) |
| Augmentation | none | — | Model assumption: nameplate retained; throughput declines with fade |
| Residual value (amount) | 0.00 | USD | Model assumption (bounded default) — not stated in draft; set to zero |
| Residual value (recognition year) | n/a | — | Model assumption (bounded default) — not stated in draft; set to n/a |
| Charge cost per kWh (asset.ess.charge_cost_per_kwh) | 0.00 | USD/kWh | Model assumption (bounded default) — not stated in draft; set to zero so net benefit lines reflect tariff savings only |
Model-assumption inputs (residual_value.amount, residual_value.year, asset.ess.charge_cost_per_kwh, applied demand reduction kW, CFPP, PCS $/kW, demand charge, arbitrage spread, RTE, fade, OpEx escalation, WACC) are bounded defaults the draft did not state explicitly. They are required inputs to the audited model; the resulting figures in §6 are AUTHORITATIVE and were not recomputed in this revision.
2. Equipment family and OEM datasheet references
The 3 MWh / 3 MW BESS scope is populated by real, publicly marketed LFP containerized DC-block and central-PCS / MV-skid products. Datasheets are commonly JS-rendered and not directly linkable as stable static PDFs; OEM landing pages are the authoritative source for product naming, and the exact SKU, OEM manual title, and revision (SOC window, DC voltage, torque limits) are confirmed at RFQ. Specific certificate numbers and issuer URLs are recorded at RFQ intake; not yet certified as named on this page.
- DC block family: CATL EnerC-class LFP containerized DC block (20-ft ISO container, LFP prismatic cells, liquid-cooled) — OEM landing: https://www.catl.com/en/ess/. Specific SKU, OEM manual title and revision, SOC window, DC voltage and torque limits: to be supplied with vendor proposal — not yet certified as named on this page.
- Central PCS / MV skid family: Sungrow ST3440KWH-L-class central PCS with integrated MV transformer and LV panel — OEM landing: https://www.sungrowpower.com/en. Specific SKU, OEM manual title and revision: to be supplied with vendor proposal — not yet certified as named on this page.
- Alternative LFP cell-to-system suppliers (for second-source qualification only): EVE Energy — https://www.evebattery.com/en; Huawei FusionSolar Smart String ESS — https://solar.huawei.com/en; Growatt — https://www.growatt.com/.
For any SOC window, DC voltage or torque limits used in EPC layouts or commissioning, consult the OEM manual title and revision supplied with the vendor proposal. Such limits are vendor- and revision-specific and are not asserted on this page.
3. CapEx build
| Line | Formula | Plug-in | Result (USD) |
|---|
| DC block (cells + module BoS) | CFPP × Energy | 132 × 3,000 | 396,000 |
| PCS / inverters | $/kW × Power | 110 × 3,000 | 330,000 |
| EPC + developer overhead | 18% × (DC + PCS) | 0.18 × (396,000 + 330,000) | 130,680 |
| Network / interconnection | one-time | 250,000 | 250,000 |
| Soft costs (permit, commissioning, financing fee) | one-time | 120,000 | 120,000 |
| Total CapEx (Year 0) | sum | 396,000 + 330,000 + 130,680 + 250,000 + 120,000 | 1,226,680.00 |
4. Annual savings and OpEx build (descriptive)
Descriptive reconciliation only; the AUTHORITATIVE numbers are in §6. Net annual benefit is small and negative in the audited scenario; OpEx dominates.
| Line | Year-1 plug-in (USD) | Notes |
|---|
| Demand charge reduction (applied) | 0 | Aligned with audited benefit (applied demand reduction = 0) |
| Energy arbitrage (net of η and charge cost, in audited scenario) | ≈ −995 | Audited benefit Year-1 = -995.45 USD (round-trip losses plus modelled tariff effects exceed working spread) |
| Fixed O&M | 42,000 | 14 × 3,000 |
| Variable O&M | 657 | 0.60 × 1,095 MWh |
| Insurance adder (working) | 9,813 | 0.8% × CapEx |
| Year-1 OpEx (audited) | 52,470.00 | Matches §6 cost row Year 1 |
5. Cash-flow formula (reference)
CF(n) = Benefit(n) − OpEx(n) − CapEx(n)
Throughput(n) = Energy × (1 − Fade)^n × 365
Benefit(n) = Spread × Throughput(n) × η (net of charge cost; tariff-driven savings line = 0 in this scenario; modelled net is negative)
OpEx(n) = Fixed_O&M × Power + Variable_O&M × Throughput(n) + Insurance × CapEx
Discount factor(n) = 1 / (1 + WACC)^n
Discounted net(n) = CF(n) × Discount factor(n)
NPV = Σ Discounted net(n) = PV(benefit) − PV(cost)
6. Authoritative TCO tables (verbatim from the audited model)
TCO summary
| Metric | Value |
|---|
| Currency | USD |
| Horizon (years) | 15 |
| Discount rate | 7.00 % |
| Total undiscounted cost (USD) | 2,134,065.59 |
| Total discounted cost / PV of costs (USD) | 1,764,177.83 |
| Total undiscounted benefit (USD) | -13,012.13 |
| Total discounted benefit (USD) | -8,099.78 |
| NPV (USD) | -1,772,277.61 |
| IRR | n/a |
| Simple payback (year) | — |
| Discounted payback (year) | — |
| LCOS (USD/kWh) | 0.1980 |
Year-by-year cash flow
| Year | Cost (USD) | Benefit (USD) | Net (USD) | Discount factor | Discounted net (USD) | Energy (kWh) |
|---|
| 0 | 1,226,680.00 | 0.0000 | -1,226,680.00 | 1.00 | -1,226,680.00 | 0.0000 |
| 1 | 52,470.00 | -995.45 | -53,465.45 | 0.9346 | -49,967.71 | 1,095,000.00 |
| 2 | 53,519.40 | -975.55 | -54,494.95 | 0.8734 | -47,598.00 | 1,073,100.00 |
| 3 | 54,589.79 | -956.03 | -55,545.82 | 0.8163 | -45,341.94 | 1,051,638.00 |
| 4 | 55,681.58 | -936.91 | -56,618.50 | 0.7629 | -43,193.98 | 1,030,605.24 |
| 5 | 56,795.22 | -918.18 | -57,713.39 | 0.7130 | -41,148.85 | 1,009,993.14 |
| 6 | 57,931.12 | -899.81 | -58,830.93 | 0.6663 | -39,201.53 | 989,793.27 |
| 7 | 59,089.74 | -881.82 | -59,971.56 | 0.6227 | -37,347.27 | 969,997.41 |
| 8 | 60,271.54 | -864.18 | -61,135.72 | 0.5820 | -35,581.54 | 950,597.46 |
| 9 | 61,476.97 | -846.90 | -62,323.86 | 0.5439 | -33,900.05 | 931,585.51 |
| 10 | 62,706.51 | -829.96 | -63,536.47 | 0.5083 | -32,298.72 | 912,953.80 |
| 11 | 63,960.64 | -813.36 | -64,774.00 | 0.4751 | -30,773.66 | 894,694.72 |
| 12 | 65,239.85 | -797.09 | -66,036.94 | 0.4440 | -29,321.19 | 876,800.83 |
| 13 | 66,544.65 | -781.15 | -67,325.80 | 0.4150 | -27,937.81 | 859,264.81 |
| 14 | 67,875.54 | -765.53 | -68,641.07 | 0.3878 | -26,620.19 | 842,079.52 |
| 15 | 69,233.05 | -750.22 | -69,983.27 | 0.3624 | -25,365.16 | 825,237.93 |
Reading the cash-flow table: the project never generates a positive annual net cash flow. Costs rise 2.0%/yr (OpEx escalation consistent with §1) while audited benefits remain small and negative; the cumulative discounted position worsens every year. There is no payback year.
7. Sensitivity (directional)
| Driver | Base value | Direction for NPV improvement | Effect on verdict |
|---|
| Demand charge ($/kW-mo) | 22 | Higher required to clear NPV > 0 | At $22/kW-mo with audited benefits, NPV still negative |
| Discount rate (WACC) | 7.00% | Lower WACC helps marginally | NPV remains negative across plausible range |
| Capacity fade | 2.0%/yr | Lower fade extends throughput | Throughput gains do not overcome CapEx in this scenario |
| Round-trip efficiency | 88% | Higher η lifts arbitrage | Insufficient alone |
| Stacking (capacity, ancillary, resilience) | none in base | Required to clear IRR hurdle | Without stacking, NO-GO |
8. Verdict by scenario
| Scenario | Conditions | Outcome |
|---|
| S1 — Base (audited) | Inputs as in §1; tariff savings line as in §6 | NO-GO. NPV = -1,772,277.61 USD; no payback. |
| S2 — Strong demand-charge case | Demand ≥ ~$80/kW-mo (working), WACC ≤ 7%, fade ≤ 1.5%/yr | Possibly NPV-positive; must be recomputed with buyer-specific tariff |
| S3 — Stacked revenue | Base case + capacity market + ancillary services + resilience value | Potentially NPV-positive once stacking is monetized |
| S4 — Resilient / microgrid overlay | Avoided-outage value attributed | Potentially NPV-positive if campus assigns $/kWh to outage risk |
9. Compliance & standards block (lookups, not certificates)
| Item | Status at article date | Standard / publication (full standard number + edition + year + issuer) |
|---|
| UL 9540 (system) | Not yet certified as named on this page — issuer, certificate number and URL recorded at RFQ intake | UL 9540, Standard for Energy Storage Systems and Equipment, Edition 3 (2023), UL Solutions — UL Standards catalogue page (search by standard number 9540) |
| UL 9540A (cell-level fire propagation) | Not yet certified as named on this page — issuer, certificate number and URL recorded at RFQ intake | UL 9540A, Test Method for Evaluating Thermal Runaway Fire Propagation, Edition 4 (2023), UL Solutions — UL Standards catalogue page (search by standard number 9540A) |
| UL 1973 (cells/modules) | Not yet certified as named on this page — issuer, certificate number and URL recorded at RFQ intake | UL 1973, Standard for Batteries for Use in Stationary and Vehicle Auxiliary Power Applications, Edition 3 (2022), UL Solutions — UL Standards catalogue page (search by standard number 1973) |
| IEEE 1547 interconnection | To be confirmed at utility interconnection stage | IEEE Std 1547-2018, IEEE Standard for Interconnection and Interoperability of Distributed Energy Resources with Associated Electric Power Systems Interfaces — https://standards.ieee.org/ieee/1547/5916/ |
| IEC 62619 (secondary cells, industrial) | Not yet certified as named on this page — issuer, certificate number and URL recorded at RFQ intake | IEC 62619:2022, Secondary cells and batteries containing alkaline or other non-acid electrolytes — Safety requirements for secondary lithium cells and batteries for use in industrial applications, Edition 2 (2022), IEC — IEC Webstore (IEC 62619:2022) |
| UN 38.3 (transport) | To be confirmed at shipment stage | UN Recommendations on the Transport of Dangerous Goods, Manual of Tests and Criteria, §38.3, 7th revised edition (2019), United Nations — UN Manual of Tests and Criteria, 7th revised edition (English PDF) |
| NFPA 855 (installation spacing, fire) | AHJ-dependent; confirm in early permit | NFPA 855, Standard for the Installation of Stationary Energy Storage Systems, 2023 edition, NFPA — NFPA 855 development page |
| NEC 706 (energy storage) | To be confirmed in EPC scope | NFPA 70, National Electrical Code (NEC), 2023 edition, Article 706 — Energy Storage Systems, NFPA — NFPA 70 (NEC) development page |
| EU Battery Regulation (if EU deployment) | To be confirmed | Regulation (EU) 2023/1542 of the European Parliament and of the Council of 12 July 2023 concerning batteries and waste batteries — https://eur-lex.europa.eu/eli/reg/2023/1542/oj |
10. HS / HTS code block (lookup required)
| HS / HTS heading | Description | US duty rate | Lookup notes |
|---|
| 8507.60 | Lithium-ion accumulators (cells/modules/packs) | Verify current rate at filing | USITC HTSUS, Chapter 85, heading 8507 — https://hts.usitc.gov/. Confirm cell/module/pack classification at filing. |
| 8504.40 | Static converters (PCS / inverter) | Verify current rate at filing | USITC HTSUS, Chapter 85, heading 8504.40 — https://hts.usitc.gov/. Possible duty-free under certain subheadings; verify current schedule. |
| 8537.10 | Boards/panels/console for electric control (BESS control cabinet) | Verify current rate at filing | USITC HTSUS, Chapter 85, heading 8537 — https://hts.usitc.gov/. Duty depends on rated voltage and configuration. |
11. Trade-compliance & cross-border references
Disclaimer: US import duty rates change. The rates above must be confirmed against the current USITC Harmonized Tariff Schedule of the United States (HTSUS) before any customs filing. USITC HTSUS is the official, authoritative source. Nothing on this page constitutes customs or trade-compliance advice.
12. CTA
RFQ: Submit your TradVolt RFQ. All RFQ submissions route through the TradVolt RFQ form. Datasheet packs (specific SKU, OEM manual title and revision, certificate issuer and number, torque/SOC/limits) are returned with the vendor proposal after RFQ intake.