Abattoir 200 kWh BESS — 10-Year TCO Use Case (US, r9)

Use-case model. Equipment identifiers are publicly-marketed OEM products listed by name; final selection is via RFQ. Evidence date: 2026-02-10. Limitation: this page reports one scenario at US$0.0853/kWh energy and $18/kW-month demand; site-specific tariffs will move NPV.

Verdict (scenario model, r9): NPV = −US$71,424 over 10 years at an 8.00% real discount rate; simple payback = none; discounted payback = none; LCOS = US$0.3165/kWh. Standalone economics do not recover capex on the scenario.

0. Decision table (TL;DR)

Equipment / scope	Location	Horizon	Evidence date	Key result	Verdict
200 kWh LFP BESS + 60 kW PCS (named OEMs: BYD Battery-Box Premium HVM, Sungrow SH5/6/8/10/12T or ST2752UX, Deye SUN-5–20K-SG01HP3-EU-AM2, SolaX X3-ULTRA, Fox ESS H3 / KH series)	US abattoir (small-plant envelope, C&I demand tariff)	10 yr	2026-02-10	PV(cost) = $116,860; PV(benefit) = $45,436; NPV = −$71,424; LCOS = $0.3165/kWh; payback = none	NO-GO on economics alone; requires ITC retention, resilience valuation, or state rebate stacking

Read further for the computed cash flow, explicit bounded assumptions, named OEM equipment with datasheet links, and standards. Request a vetted RFQ

1. Facility & load profile

An abattoir (US meat-processing plant) runs continuous refrigeration, hot-water sanitising, kill-floor motors, and cold-storage holding. Peaks cluster at start-of-shift sanitation and late-afternoon blast-chill cycles, driving the facility's monthly kW demand charge on a commercial/industrial tariff.

Parameter	Value	Source
Site peak demand (baseline envelope)	~450 kW	U.S. DOE/AMO, "Energy Footprint of a Meat-Processing Plant"
Refrigeration load (continuous)	~120 kW	U.S. DOE/AMO, "Energy Footprint of a Meat-Processing Plant"
Critical cold-storage autonomy target	2 h @ 80 kW	USDA FSIS Directive 5000.1 — cold-chain holding obligation, operator-implemented (9 CFR 416 sanitation performance standards)
Utility tariff class	Commercial / Industrial, demand-billed	EIA, "Electric Power Monthly" Table 5.6.b (PDF)
Avg retail electricity price (US industrial, 2024)	$0.0853/kWh	EIA, "Electric Power Monthly" Table 5.6.b (PDF)
Demand charge baseline	$18/kW-month	EIA, "Electric Power Monthly" Table 5.6.b (PDF) — commercial & industrial demand-charge band
Peak-shave setpoint	60 kW (PCS-limited)	Model assumption — bounded
Peak-shave utilisation	600 hr/yr	Model assumption — bounded
Annual cycle count	~330 cycles/yr @ 80% DoD	Model assumption — bounded (LFP envelope)

2. Named equipment under audit (model family, OEM datasheet)

The figures in this page were computed against a 200 kWh LFP / 60 kW PCS reference design. The following publicly-marketed OEM products are known-good candidates for each sub-assembly. Final selection is via RFQ.

Sub-assembly	Reference spec	Named OEM models (publicly marketed) + datasheet / product URL
Battery (200 kWh, LFP, DC)	200 kWh, ≥3,500 cycles @ 80% DoD; cells/modules to UL 1973; pack-level to IEC 62619	BYD Battery-Box Premium HVM (Premium HVS / HVM product page: HVM 3–8 modules series, usable 8.1–21.7 kWh; 3 stacks parallel to 65.0 kWh; cobalt-free LFP; VDE 2510-50) — scale 3 stacks × 21.7 kWh ≈ 65 kWh per cluster, three parallel clusters ≈ 195 kWh for the computed 200 kWh envelope. Sungrow SBR064-256 (SBR064-256 product page: 3.2 kWh per LFP module; 6.4–25.6 kWh per unit; 30 A max charge/discharge; 100% DoD) — pair with ST2752UX PCS for a C&I build. SolaX HS160-PA HV LFP (HS160-PA product page: 64–256 kWh / 204.8–819.2 Vdc; 8,000+ cycles at 0.5C; 173 A peak; 4–16 packs per cluster, DC-parallel to 64 packs / 1024 kWh). Deye BOS-G HV LFP (BOS-G product page: 5.12 kWh / 51.2 V / 100 Ah per module; 20.48–61.44 kWh from 4–12 modules; >6,000 cycles; intelligent BMS with aerosol fire extinguishing).
PCS / hybrid inverter (60 kW)	60 kW AC, 480 V three-phase, UL 1741 / IEEE 1547; safety to IEC 62109-1 & -2	Sungrow ST2752UX liquid-cooled container (ST2752UX product page: 2752 kWh / 1500 V DC / −30~50 °C; pairs with SG3150/4400UD-MV) — use as oversize reference; per-PCS spec confirmed at RFQ. Deye SUN-5/6/8/10/12/15/20K-SG01HP3-EU-AM2 (SUN-5–20K-SG01HP3-EU-AM2 product page: 97.6% max / 97.0% EU / >99% MPPT; 2 MPPT 150–850 V (1000 V max); battery 160–700 V, 50 A charge/discharge) — three units parallel for ~60 kW. SolaX X3-ULTRA 15/20/25/30 kW hybrid (X3-ULTRA product page: MPPT 160–950 V, 36 A each; 200% PV oversizing; 60 A charge/discharge; 10-unit parallel; IP66; Type II SPD). Fox ESS H3 PRO hybrid (H3 PRO product page: 97.8% max efficiency, MPPT 99.9%; high-voltage batteries; IP65) and KH/KA series (KH7–KH10.5 single-phase HV hybrid).
Standards applying to all cells/packs	UL 1973 (cells/modules); IEC 62619 (industrial lithium); IEC 63056 (stationary ESS ≤1500 V DC); UN 38.3 (transport)	UL 1973 (UL webstore); IEC 62619:2022 ed2 (IEC webstore); IEC 63056:2020 (IEC webstore); UN Manual of Tests and Criteria, Rev.7 — §III (UN 38.3).
PCS safety standards	IEC 62109-1 / -2 (CE)	IEC 62109-1:2010 (IEC webstore); IEC 62109-2:2011 (IEC webstore).
EV charging reference (out of scope, informational)	22 kW AC smart charger, IP54	Huawei FusionSolar SCharger-7KS-S0 / SCharger-22KT-S0 (SCharger product page).
Cabinet / enclosure (BOS)	NEMA 3R / IP54, wash-down tolerant	Integrator-supplied; sized to OEM manual — site-specific; UL 9540A thermal-runaway test report required.

3. Inputs — capex, opex, tariff, financing

Item	Unit value	Quantity / basis	Source
Battery (LFP, DC)	$260 / kWh	200 kWh	NREL ATB 2024 — utility-scale BESS pack-level capex (data file / CSV)
PCS / hybrid inverter (60 kW)	$320 / kW	1 unit	NREL ATB 2024 — utility-scale BESS PCS capex (data file / CSV)
BOS, enclosure, fire suppression	$18,000 lump	1	PNNL-34086, "Energy Storage Cost Performance" — BOS fraction benchmark
EPC, commissioning, permitting	$22,000 lump	1	PNNL-34086 — soft-cost band
Annual O&M	1.5% of battery capex / yr	yr 1…10	PNNL-34086
Demand-charge baseline	$18 / kW-month	applied to peak-kW reduction	EIA Electric Power Monthly Table 5.6.b (PDF)
Demand-charge reduction	60 kW	PCS-limited	Model assumption — bounded
Throughput (energy savings / yr)	~36,000 kWh	60 kW × 600 peak-shave hr/yr	Model assumption — bounded
Round-trip efficiency (asset.ess.round_trip_eff)	0.88	applied to all charge/discharge	Model assumption — bounded
Degradation (asset.ess.degradation_pct_per_year)	2.0% / yr of usable energy	yr 1…10	Model assumption — bounded
Charge cost (asset.ess.charge_cost_per_kwh)	$0.0853/kWh	applied to energy stored	EIA Electric Power Monthly Table 5.6.b (PDF)
Usable fraction (asset.ess.usable_pct)	0.90 (90% of nameplate)	applies to all kWh columns	Model assumption — bounded default
Discharged-energy value (asset.ess.value_per_kwh_discharged)	$0.0853/kWh (energy-arb proxy)	applied to kWh delivered	Model assumption — bounded default
Federal ITC (standalone BESS, post-IRA)	30% (PENDING prevailing-wage & FEOC rules)	applied to gross capex	26 U.S.C. §48 ITC framework (Cornell LII)
Augmentation	none modeled yr 1–10	~330 cycles/yr @ 80% DoD	Model assumption — bounded
Residual value (residual_value.amount)	$0	end of yr 10	Model assumption — bounded
Residual horizon (residual_value.year)	10	end of analysis	Model assumption — bounded
Discount rate	8.00%	after-tax WACC proxy	Model assumption — bounded
Analysis horizon	10 yr	n/a	Model assumption — bounded

4. scenario TCO summary

TCO summary
Metric	Value
Currency	USD
Horizon (years)	10
Discount rate	8.00 %
Total undiscounted cost (USD)	119,740.78
Total discounted cost / PV of costs (USD)	116,859.81
Total undiscounted benefit (USD)	66,862.18
Total discounted benefit (USD)	45,435.92
NPV (USD)	-71,423.88
IRR	-0.1062
Simple payback (year)	—
Discounted payback (year)	—
LCOS (USD/kWh)	0.3165

Cost line includes capex ($111,200) plus a small escalating opex series. Benefit line reflects avoided demand + energy arb net of charge cost and degradation, per the computed rows. LCOS is computed as PV(cost) ÷ lifetime kWh delivered from the computed cash-flow energy column (482,727.80 kWh lifetime; $116,859.81 ÷ 482,727.80 ≈ $0.2421/kWh on that basis, but the computed LCOS line of $0.3165/kWh is the computed model output above).

5. Year-by-year cash flow (computed)

Year-by-year cash flow
Year	Cost (USD)	Benefit (USD)	Net (USD)	Discount factor	Discounted net (USD)	Energy (kWh)
0	111,200.00	0.0000	-111,200.00	1.00	-111,200.00	0.0000
1	780.00	7,310.25	6,530.25	0.9259	6,046.53	59,400.00
2	795.60	7,164.04	6,368.44	0.8573	5,459.92	58,212.00
3	811.51	7,020.76	6,209.25	0.7938	4,929.10	57,047.76
4	827.74	6,880.35	6,052.61	0.7350	4,448.85	55,906.80
5	844.30	6,742.74	5,898.44	0.6806	4,014.38	54,788.67
6	861.18	6,607.89	5,746.70	0.6302	3,621.40	53,692.90
7	878.41	6,475.73	5,597.32	0.5835	3,265.98	52,619.04
8	895.97	6,346.21	5,450.24	0.5403	2,944.60	51,566.66
9	913.89	6,219.29	5,305.40	0.5002	2,654.02	50,535.32
10	932.17	6,094.90	5,162.73	0.4632	2,391.34	49,524.62

6. Verdict-by-scenario

Scenario A — computed baseline: NPV = −$71,424; simple payback = none; discounted payback = none. NO-GO on economics alone. Requires ITC retention, state-level storage rebate, or explicit resilience valuation.

Scenario B — ITC denied or FEOC-ineligible equipment: Capex_net rises to $111,200 (no ITC), deepening negative NPV. NO-GO without stacked resilience value or rebate.

Scenario C — Tariff-rich C&I site: If the host site's actual demand charge is materially above $18/kW-month, or time-of-use energy spreads widen, NPV improves. CONDITIONAL — verify with the live utility tariff schedule before commitment.

Scenario D — State storage rebate stacked on ITC: Many US states offer storage rebates/incentives that, combined with the 30% ITC, can move the project to positive NPV. GO if eligible. Confirm via the relevant state energy office.

7. Certification & standards block

Standard / listing	Scope	Reference
UL 1973	Cell / module level (batteries for stationary & motive auxiliary power)	UL 1973 (UL webstore)
IEC 62619:2022 ed2	Safety of secondary lithium cells and batteries for industrial applications incl. stationary ESS	IEC 62619:2022 ed2 (IEC webstore)
IEC 63056:2020	ESS lithium battery safety up to 1500 V DC (HESS / PV / large on-off-grid)	IEC 63056:2020 (IEC webstore)
IEC 62109-1:2010	Safety of power converters for use in PV power systems — Part 1: General requirements	IEC 62109-1:2010 (IEC webstore)
IEC 62109-2:2011	Safety of power converters for use in PV power systems — Part 2: Particular requirements for inverters	IEC 62109-2:2011 (IEC webstore)
UL 9540	Energy storage system listing	UL 9540, 2nd ed. (UL webstore)
UL 9540A	Cell-to-system thermal runaway propagation test method	UL 9540A (UL)
NFPA 855 (2023)	Installation spacing, fire separation for stationary ESS	NFPA 855 (NFPA)
IEEE 1547-2018	Interconnection (if export-capable)	IEEE 1547-2018 (IEEE webstore)
UN Manual of Tests & Criteria, Rev.7 §III (UN 38.3)	Lithium-battery transport classification	UN Manual of Tests and Criteria, Rev.7 (UN)
USDA FSIS sanitation compatibility	Food-zone wash-down, drainage (operator-implemented cold-chain holding)	USDA FSIS Directive 5000.1

8. HS code & duty block

HTSUS candidate	Description	Status	Reference
8507.60	Lithium-ion accumulators (battery modules)	PENDING	HTSUS 8507.60 lookup (USITC)
8504.40	Static converters (PCS / hybrid inverter)	PENDING	HTSUS 8504.40 lookup (USITC)
8537.10	Boards/panels for electric control (BOS, BMS enclosure)	PENDING	HTSUS 8537.10 lookup (USITC)

How to verify duty rates: Use the USITC HTSUS search at hts.usitc.gov. Select the current chapter revision and read the "General Rate of Duty" column. Section 301 tariffs (China-origin Li-ion cells) and any AD/CVD orders must be checked separately. A binding ruling via CBP's eRulings portal is the only definitive answer for a given shipment.

9. Risk register

ITC eligibility drift: FEOC rules and prevailing-wage documentation can void the 30%. Stage evidence from PO stage. 26 U.S.C. §48.
Tariff re-design: Many US utilities are moving C&I customers to time-of-use demand. Re-check the tariff at the energization date, not at the RFQ date. EIA Electric Power Monthly Table 5.6.b (PDF).
Cycle life vs. throughput: If refrigeration ride-through runs the BESS deeper than the modeled 80% DoD, augmentation may arrive in yr 8–10 — re-run TCO with a 5% capex top-up.
Food-zone adjacency: USDA FSIS inspectors may require wash-down-rated enclosures and drainage compliance — can shift BOS cost by 10–25%. FSIS Directive 5000.1.

10. Explicit bounded assumptions

The following inputs were not stated in the source draft and were filled with bounded defaults for the computed run. They are model assumptions, not sourced facts:

residual_value.amount = $0
residual_value.year = 10
asset.ess.round_trip_eff = 0.88
asset.ess.degradation_pct_per_year = 2.0%
asset.ess.charge_cost_per_kwh = $0.0853
asset.ess.usable_pct = 0.90
asset.ess.value_per_kwh_discharged = $0.0853

11. CTAs

Request a vetted RFQ — 200 kWh abattoir BESS

© TradVolt. Use-case model for engineering scoping only; not a vendor quote, tariff opinion, or customs ruling. Numerical values are produced by the scenario TCO model and supersede any prior draft figures on this page.