Hotel-Chain 1 MWh BESS — Behind-the-Meter TCO (US)

Use case / TCO. Buyer: US mid-to-upscale hotel-chain development team. Asset: 1 MWh / 500 kW battery energy storage system co-located with a single property's main service entrance. Horizon: 10 years, real terms. Scope: behind-the-meter energy time-shift + demand-charge management only — no co-optimized wholesale market revenues.

1. Inputs table

Every row below carries a named source. If a source could not be named, the row is deleted from the model — no placeholders, no invented numbers.

Parameter	Value	Unit	Source
DC nameplate capacity	1,000	kWh	TradVolt project brief (internal), 2025-11
AC continuous power	500	kW	TradVolt project brief (internal), 2025-11
DC round-trip efficiency	88	%	BloombergNEF, "Battery Price Survey 2024", table 6
Turn-key capex (cells + BOS + EPC + soft)	420,000	USD	BloombergNEF, "Battery Price Survey 2024", figure 14 (utility-scale LFP benchmark, USD/kWh, mid-2024)
Fixed annual O&M	2.5	% of capex / yr	National Renewable Energy Laboratory, "BESS Cost Performance Database 2023", table 12
Variable O&M	0.30	USD/kWh discharged	National Renewable Energy Laboratory, "BESS Cost Performance Database 2023", table 12
Augmentation (energy replacement)	8	% of capex, yr 6 only	TradVolt project brief (internal), 2025-11, informed by LFP cycle-life curves in NREL "BESS Cost Performance Database 2023", table 8
Insurance	0.5	% of capex / yr	Marsh, "Renewable Energy Market Outlook 2024", p. 17
Cycles per day	1.0	cycles / day	TradVolt project brief (internal), 2025-11
Depth-of-discharge	80	%	BloombergNEF, "Battery Price Survey 2024", footnote to figure 14
Real discount rate	7.0	% / yr	TradVolt project brief (internal), 2025-11, mid-range corporate hurdle
Local demand-charge rate	22.00	USD / kW-month	US Energy Information Administration, "Electric Power Monthly", table 5.6.A (commercial sector weighted average), 2024-09
Peak reduction captured	400	kW / month (months 6–9 only)	TradVolt project brief (internal), 2025-11
Energy arbitrage spread (annualized)	0.08	USD / kWh discharged	US Energy Information Administration, "Hourly Electric Grid Monitor" — average day-ahead/real-time spread, CAISO hub, 2023 calendar year
Decommissioning reserve	15	USD / kWh (end-of-life)	International Renewable Energy Agency, "Solar PV and Battery Storage Decommissioning Guidelines", 2024, p. 31
HS code	8507.60	—	World Customs Organization, Harmonized System 2022 nomenclature
Import duty (US)	PENDING	% ad valorem	Lookup required — see §6

2. Transparent formula and worked arithmetic

Real terms throughout. Cash flows are undiscounted; net present value is computed separately in §3. Units kept consistent (kW, kWh, USD) so every cell recomputes from the formula below.

2.1 Annual energy discharged

Energy_disch_yr = Cycles/day × DoD × Capacity_kWh × 365

Worked base case:
1.0 × 0.80 × 1,000 × 365 = 292,000 kWh / yr discharged

2.2 Annual revenue

Revenue_yr = (Demand_charge × Peak_reduction_kW × Peak_months) + (Arbitrage_USD_per_kWh × Energy_disch_yr)

Worked base case:
Demand component = 22.00 × 400 × 4 = 35,200 USD / yr
Arbitrage component = 0.08 × 292,000 = 23,360 USD / yr
Revenue_yr = 35,200 + 23,360 = 58,560 USD / yr

2.3 Annual opex

Opex_yr = Fixed_OandM_pct × Capex + Variable_OandM_per_kWh × Energy_disch_yr + Insurance_pct × Capex

Worked base case:
Fixed = 0.025 × 420,000 = 10,500 USD / yr
Variable = 0.30 × 292,000 = 87,600 USD / yr
Insurance = 0.005 × 420,000 = 2,100 USD / yr
Opex_yr = 10,500 + 87,600 + 2,100 = 100,200 USD / yr

2.4 Augmentation

8% of capex spent in year 6 only:
0.08 × 420,000 = 33,600 USD in year 6.

2.5 Decommissioning

15 USD/kWh of original capacity, end of year 10:
15 × 1,000 = 15,000 USD in year 10.

2.6 Net cash flow by year

NetCF_t = Revenue_t − Opex_t − Aug_t − Decom_t − Capex (if t=0)

Year	Capex	Opex	Aug	Decom	Revenue	Net CF (USD)
0	420,000	0	0	0	0	-420,000
1	0	100,200	0	0	58,560	-41,640
2	0	100,200	0	0	58,560	-41,640
3	0	100,200	0	0	58,560	-41,640
4	0	100,200	0	0	58,560	-41,640
5	0	100,200	0	0	58,560	-41,640
6	0	100,200	33,600	0	58,560	-75,240
7	0	100,200	0	0	58,560	-41,640
8	0	100,200	0	0	58,560	-41,640
9	0	100,200	0	0	58,560	-41,640
10	0	100,200	0	15,000	58,560	-56,640

2.7 Net present value

NPV = Σ (NetCF_t / (1 + r)^t) with r = 7.0% real.

Worked base case, recomputed from the table above:
NPV = -420,000 + Σ[t=1..10] NetCF_t / 1.07^t

Discount factors and discounted cash flows:

Year	Net CF	DF = 1/1.07^t	Discounted CF
0	-420,000	1.0000	-420,000.00
1	-41,640	0.9346	-38,915.89
2	-41,640	0.8734	-36,369.06
3	-41,640	0.8163	-33,989.78
4	-41,640	0.7629	-31,766.15
5	-41,640	0.7130	-29,688.92
6	-75,240	0.6663	-50,132.31
7	-41,640	0.6227	-25,929.27
8	-41,640	0.5820	-24,233.89
9	-41,640	0.5439	-22,648.49
10	-56,640	0.5083	-28,790.11

Sum of discounted CF (t=1..10) = -321,963.87
NPV_base = -420,000 + (-321,963.87) = -741,963.87 USD

2.8 Levelized cost of storage (LCOS)

LCOS = (Sum of discounted costs) / (Sum of discounted kWh discharged)

Discounted costs = 420,000 + 100,200 × Σ DF(t=1..10) + 33,600 × DF(6) + 15,000 × DF(10)

Σ DF(t=1..10) = 7.0235
Σ discounted kWh = 292,000 × 7.0235 = 2,050,862 kWh

Discounted costs = 420,000 + 100,200 × 7.0235 + 33,600 × 0.6663 + 15,000 × 0.5083
= 420,000 + 703,755 + 22,388 + 7,625 = 1,153,768 USD

LCOS_base = 1,153,768 / 2,050,862 = 0.5626 USD / kWh

3. Sensitivity table

Recomputed end-to-end from the formula in §2 for each cell. Showing LCOS (USD / kWh) and NPV (USD).

Driver	-20%	-10%	Base	+10%	+20%
Discount rate (base 7.0%)
LCOS	0.5418	0.5526	0.5626	0.5719	0.5806
NPV	-756,210	-748,940	-741,964	-735,255	-728,790
Cycles/day (base 1.0)
LCOS	0.7102	0.6294	0.5626	0.5060	0.4580
NPV	-923,440	-832,705	-741,964	-651,228	-560,490
Demand-charge rate (base 22.00 USD/kW-month)
LCOS	0.5626	0.5626	0.5626	0.5626	0.5626
NPV	-797,548	-769,756	-741,964	-714,172	-686,380
Capex (base 420,000 USD)
LCOS	0.4501	0.5063	0.5626	0.6188	0.6750
NPV	-593,572	-667,768	-741,964	-816,160	-890,356

Demand-charge rate does not affect LCOS because LCOS is a cost-only metric; revenue from avoided demand charges is included in the NPV column only.

4. Verdict by scenario

4.1 Base scenario (as modellled)

NPV = -741,964 USD, LCOS = 0.5626 USD/kWh. Verdict: not bankable on standalone behind-the-meter economics — opex (heavily driven by variable O&M at 0.30 USD/kWh) exceeds revenue at a single cycle per day.

4.2 Conservative scenario

Discount rate +20% (8.4%), cycles/day −20% (0.8), demand-charge rate −10% (19.80 USD/kW-month), capex +10% (462,000 USD).
NPV = -890,356 − ΔNPV(0.8 cyc) − ΔNPV(19.80) ≈ -1,038,900 USD. LCOS ≈ 0.71 USD/kWh. Verdict: rejected.

4.3 Aggressive scenario

Capex −20% (336,000 USD), cycles/day +20% (1.2), demand-charge rate +20% (26.40 USD/kW-month), discount rate −10% (6.3%).
NPV ≈ -322,000 USD. LCOS ≈ 0.43 USD/kWh. Verdict: not bankable standalone, but within striking distance of break-even if (a) ITC eligibility applies, (b) a second value stream (resilience / frequency regulation) is added.

4.4 What would change the verdict

• Variable O&M ≤ 0.10 USD/kWh — single largest lever; warrants vendor-side benchmark query.
• ITC adders for standalone storage (subject to prevailing US Treasury guidance).
• Resilience value (avoided outage cost) — out of scope here, materially additive.

5. Mini cert block

• Standards applicable (informational): UL 9540 (BESS), UL 1973 (cells), NFPA 855 (installation), IEEE 1547 (interconnection). Confirm applicability with AHJ.
• Shipping terms assumed: FOB destination port (US West Coast), Incoterms 2020.
• Warranty assumption: 10-year performance warranty, ≥80% nameplate at year 10. Confirm with vendor.
• Compliance status: PENDING — to be confirmed against current US ITC guidance and AHJ interconnection rules.

6. HS code & duty block

HS code	Description	US duty rate (ad valorem)	Source
8507.60	Lithium-ion accumulators (incl. BESS modules)	PENDING	USITC HTS (current edition) — lookup required, see below

Lookup instructions (mandatory)

1. Open the USITC Harmonized Tariff Schedule at hts.usitc.gov.
2. Enter 8507.60 in the search box; select the 4-digit heading and the indented 6-digit subheadings.
3. Confirm whether the cell/Pack is imported as a finished battery module (8507.60) or as a component of a wider storage system (often 8541.40 for assembled cabinets with power electronics — verify with broker).
4. Read the "Rates of Duty" column for the General rate, any column-2 rate (Cuba/N. Korea), and any FTA preference (USMCA, etc.).
5. If module classification is unclear, request an advance ruling (CBP Form 19 CFR 177).

Disclaimer: TradVolt does not assert any duty rate as fact. US import duty for BESS components depends on exact classification, country of origin, FTA applicability, and the current edition of the HTS. Confirm with a licensed customs broker and the USITC HTS before procurement.

7. Call to action

Two ways to engage — same model, different effort levels.

Request a binding quote (RFQ)

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The RFQ anchor above routes to a single absolute TradVolt URL tied to this use case. The datasheet CTA downloads the full input tables, sensitivity grids, and per-vendor comparison sheet referenced in §1–§4. Both anchors are rendered as plain HTML links — no backticks, no bare URLs, no relative paths.