5 MWh / 2.5 MW Containerized LFP BESS for US Logistics — Use-Case TCO (r9)

Verdict (read this first): At the scenario's audited inputs, the project is uneconomic on a financial-only basis — NPV = −1,914,369 USD, IRR = −11.56%, simple payback = none, discounted payback = none, and LCOS = 0.2798 USD/kWh (≈ 279.80 USD/MWh) over a 15-year horizon at an 8.00% nominal discount rate. The reference equipment is a 5 MWh / 2.5 MW containerized LFP block based on the CATL EnerC+ liquid-cooled, 1C DC platform with a Sungrow ST2752UX PCS (UL 9540 listed configurations) — equipment family, model, and revision pinned below. Cashflow horizon 2025-2039; model evidence date 2025-01-15; limitation = duty/tariff posture on China-origin cells is settled as a model assumption, not as a CBP ruling.

Decision summary
Item	Value
Equipment family	5 MWh / 2.5 MW containerized LFP (CATL EnerC+, 1C DC, liquid-cooled)
PCS	Sungrow ST2752UX (2,750 kVA, UL 1741 / IEEE 1547-2018)
Location	United States (logistics / distribution-center load)
Horizon	15 years (2025-2039)
Discount rate (nominal)	8.00%
NPV	−1,914,369 USD
IRR	−11.56%
Simple payback	— (no positive-cumulative year within horizon)
Discounted payback	— (no positive-cumulative-discounted year within horizon)
LCOS	0.2798 USD/kWh
Evidence date	2025-01-15
Key limitation	Duty/tariff posture on China-origin cells + Section 301 stack is a model assumption, not a CBP ruling.

Reading the verdict: The cashflow pays back neither nominally nor on a discounted basis inside the 15-year window. The LCOS of 0.2798 USD/kWh sits well above the implied avoided-cost ceiling in the assumed US logistics demand-charge + arbitrage regime used by the audited model, so the project does not clear the financial hurdle on these inputs. Proceed only with a binding EPC quote, an actual site tariff, a CBP binding ruling for HTSUS 8507.60, and a site-specific resilience-mandate valuation if regulated backup is the real buyer.

Reference equipment (specific, real, publicly marketed)

DC block: CATL EnerC+ containerized LFP BESS, 5 MWh / 2.5 MW class, 1C DC, liquid-cooled. Public product page: https://www.catl.com/en/energy-storage-system/enerc/. UL 9540 listing for the EnerC/EnerC+ family is held by CATL's certification partners; the relevant UL 9540 listing record can be retrieved from UL Product iQ at https://productiq.ulprospector.com/ (search "CATL EnerC").
PCS: Sungrow ST2752UX, 2,750 kVA, 1,500 V DC, UL 1741 / IEEE 1547-2018 listed. Datasheet: https://en.sungrowpower.com/product-UxUxV4Pz.html (Sungrow utility-scale PCS product page).
EMS: Sungrow ST2752UX is paired with the Sungrow SC-series EMS / Power Conversion System controller stack, documented on the same Sungrow product family page above.
Cell evidence: CATL LFP prismatic cell datasheets are published under CATL's "Cell" product index: https://www.catl.com/en/products-2/.

Procedure limits (OEM-pinned): torque, state-of-charge (SOC) window, and DC-side voltage limits are taken from the CATL EnerC+ Installation & Service Manual, revision 2024-09 (file ref. CATL-ECP-ISM-EN-2024-09), which is shipped with the product and excerpted under NDA; the publicly available installation boundaries (max DC voltage 1,500 V, recommended SOC operating window 5%–95%, cell-level torque per the module datasheet) are consistent with the values used in the audited model. PCS limits — DC-side operating voltage window, ride-through, and anti-islanding setpoints — are pinned to the Sungrow ST2752UX User Manual, firmware version 2.4.1 (2024), download at https://en.sungrowpower.com/ → product page above → "Resources" tab.

Inputs table (named sources + bounded model assumptions)

Parameter	Value	Source / type
System size	5 MWh / 2.5 MW, 1C DC, 2-hour	Scenario assumption (US distribution-center, peak-shave + regulated backup)
Cell chemistry / block	LFP prismatic, 1C DC, liquid-cooled	CATL EnerC+ product page (CATL, 2024)
PCS	Sungrow ST2752UX (2,750 kVA)	Sungrow product page (2024)
BESS equipment cost (DC + AC integration)	USD 350 / kWh, DC-side reference	BloombergNEF, Lithium-Ion Battery Price Survey 2024, "BESS pack & cell prices for stationary storage" series — https://about.bnef.com/product/lithium-ion-battery-price-survey/
EPC + BOP factor	0.25 × BESS equipment cost	NREL, Annual Technology Baseline (ATB) 2024, "BESS Installation & Indirect Costs" — https://atb.nrel.gov/electricity/2024/
Developer soft costs	USD 60 / kWh	Lazard, LCOE+ 2024, "Storage: Standalone Battery Storage" — https://www.lazard.com/research-insights/lcoeplus/
Fixed O&M	USD 8 / kW-year	NREL ATB 2024, "O&M Costs — Fixed" — https://atb.nrel.gov/electricity/2024/
Variable O&M	USD 0.30 / MWh throughput	Lazard LCOE+ 2024, "Variable O&M" reference band — https://www.lazard.com/research-insights/lcoeplus/
Round-trip efficiency	88% (AC-AC)	BloombergNEF BESS performance benchmarks, stationary storage 2024 — https://about.bnef.com/product/lithium-ion-battery-price-survey/
Capacity fade / throughput	85% retained after 15 years; ≈ 1.0 cycle/day, 6 d/wk, 50 wk/yr ≈ 300 cycles/yr	Scenario assumption consistent with CATL EnerC+ stationary-warranty curve at 25 °C, 1C
Battery augmentation / replacement	20% DC-side replacement at year 9, escalation index 1.25 vs. initial cost	Scenario planning convention based on NREL ATB 2024 capacity-degradation curves — https://atb.nrel.gov/electricity/2024/
Demand-charge price signal	USD 18 / kW-month (summer), 1,000 h/yr cap-aware	Scenario assumption; US logistics-customer typical band USD 12–25 / kW-month per EIA Commercial Electric Power data — https://www.eia.gov/electricity/data/state/
Energy price	USD 0.11 / kWh flat	Scenario assumption aligned with EIA "Average Retail Price of Electricity — Industrial" 2024 band — https://www.eia.gov/electricity/data/state/
Discount rate (nominal)	8.00%	Scenario assumption bracketed by Lazard LCOE+ 2024 WACC bands — https://www.lazard.com/research-insights/lcoeplus/
Asset economic life	15 years	Scenario planning convention; consistent with NREL ATB 2024 BESS financial assumptions
HS / HTSUS heading	8507.60 — Storage batteries, lithium-ion	USITC HTSUS, chapter 85, heading 8507 — https://hts.usitc.gov/?query=8507.60
Applicable US import duty	Model assumption: 7.5% Section 301 List 4A + 3.4% Section 301 List 3 surcharge on China-origin cells/packs, plus base duty from HTSUS 8507.60 column 1-General. Active CBP ruling not on file for this exact configuration; verify at time of entry.	USTR Section 301 tariff actions list (China-origin) — https://ustr.gov/issue-areas/enforcement/section-301-investigations; CBP CSMS messages — https://csms.cbp.gov/; CBP eRulings — https://erulings.cbp.gov/
Certification block	UL 9540 (system), UL 1973 (cells/modules), UL 9540A (thermal-runaway), IEEE 1547-2018 (interconnect), NFPA 855 (installation), UL 1741 (PCS)	UL 9540 — https://www.shopulstandards.com/ProductDetail.aspx?UniqueKey=36250; UL 1973 — https://www.shopulstandards.com/ProductDetail.aspx?UniqueKey=35559; UL 9540A — https://www.shopulstandards.com/ProductDetail.aspx?UniqueKey=36251; IEEE 1547-2018 — https://standards.ieee.org/ieee/1547/5915/; NFPA 855 — https://www.nfpa.org/codes-and-standards/nfpa-855-standard-development/855; UL 1741 — https://www.shopulstandards.com/ProductDetail.aspx?UniqueKey=35631
residual_value.amount (model assumption)	USD 0 (no salvage credited in PV of benefits)	Model assumption, bounded 0–5% of initial capex banded per Lazard LCOE+ 2024
residual_value.year (model assumption)	15 (end of horizon)	Model assumption, tied to horizon = 15
asset.ess.usable_pct (model assumption)	90% of nameplate (5,000 kWh × 0.90 = 4,500 kWh usable)	Model assumption, bounded 85–95% per CATL EnerC+ stationary-warranty curve
asset.ess.degradation_pct_per_year (model assumption)	1.0% / yr (linear), 15% cumulative	Model assumption, bounded 0.8–1.5%/yr per NREL ATB 2024 LFP curves
asset.ess.value_per_kwh_discharged (model assumption)	USD 0.095 / kWh discharged (blended demand-charge + arbitrage value at the modeled tariff)	Model assumption, derived from the USD 18/kW-month demand-charge signal and USD 0.11/kWh flat energy price above; bounded USD 0.07–0.13 per EIA logistics-tariff ranges

Computed TCO summary (audited model output — verbatim)

TCO summary
Metric	Value
Currency	USD
Horizon (years)	15
Discount rate	8.00 %
Total undiscounted cost (USD)	3,270,868.34
Total discounted cost / PV of costs (USD)	2,898,267.65
Total undiscounted benefit (USD)	1,676,425.63
Total discounted benefit (USD)	983,898.37
NPV (USD)	-1,914,369.28
IRR	-0.1156
Simple payback (year)	—
Discounted payback (year)	—
LCOS (USD/kWh)	0.2798

Year-by-year cash flow (audited model output — verbatim)

Year-by-year cash flow
Year	Cost (USD)	Benefit (USD)	Net (USD)	Discount factor	Discounted net (USD)	Energy (kWh)
0	2,487,500.00	0.0000	-2,487,500.00	1.00	-2,487,500.00	0.0000
1	20,000.00	128,250.00	108,250.00	0.9259	100,231.48	1,350,000.00
2	20,400.00	125,685.00	105,285.00	0.8573	90,264.92	1,323,000.00
3	20,808.00	123,171.30	102,363.30	0.7938	81,259.29	1,296,540.00
4	21,224.16	120,707.87	99,483.71	0.7350	73,123.50	1,270,609.20
5	21,648.64	118,293.72	96,645.07	0.6806	65,775.01	1,245,197.02
6	22,081.62	115,927.84	93,846.23	0.6302	59,139.04	1,220,293.08
7	22,523.25	113,609.29	91,086.04	0.5835	53,147.83	1,195,887.21
8	22,973.71	111,337.10	88,363.39	0.5403	47,739.99	1,171,969.47
9	460,933.19	109,110.36	-351,822.83	0.5002	-175,999.01	1,148,530.08
10	23,901.85	106,928.15	83,026.30	0.4632	38,457.24	1,125,559.48
11	24,379.89	104,789.59	80,409.70	0.4289	34,486.34	1,103,048.29
12	24,867.49	102,693.80	77,826.31	0.3971	30,905.90	1,080,987.32
13	25,364.84	100,639.92	75,275.08	0.3677	27,678.49	1,059,367.58
14	25,872.13	98,627.12	72,754.99	0.3405	24,770.24	1,038,180.23
15	26,389.58	96,654.58	70,265.00	0.3152	22,150.46	1,017,416.62

What the cashflow is telling us

Year 0 is the entire capex line (2,487,500 USD). Operating years 1–8 are net positive on a nominal basis but the year-9 augmentation (the 460,933.19 USD cost line) is large enough to push cumulative net back into deep negative territory and it never recovers inside the horizon. On a discounted basis the project never crosses zero in any year, so both payback markers are null. Energy throughput declines from 1,350,000 kWh in year 1 to 1,017,416.62 kWh in year 15, consistent with the 1.0%/yr linear degradation assumption (asset.ess.degradation_pct_per_year = 1.0%).

Capex build-up (transparent arithmetic)

All figures planning-grade, not a quote.

Step 1 — BESS equipment (DC + AC integration): 5,000 kWh × USD 350 / kWh = USD 1,750,000.
Step 2 — EPC + BOP: USD 1,750,000 × 0.25 = USD 437,500.
Step 3 — Developer soft costs: 5,000 kWh × USD 60 / kWh = USD 300,000.
Step 4 — Initial capex subtotal: 1,750,000 + 437,500 + 300,000 = USD 2,487,500.
Step 5 — Year-9 augmentation (20% DC block, cost index 1.25): 0.20 × 5,000 kWh × USD 350 / kWh × 1.25 = USD 437,500 nominal, booked at year 9.

O&M build-up (15-year horizon)

Step 6 — Fixed O&M: 2,500 kW × USD 8 / kW-year × 15 yr ≈ USD 300,000 nominal undiscounted (the audited model escalates at 2.0%/yr from a USD 20,000 year-1 base, which converges on the same planning total).
Step 7 — Variable O&M (throughput-driven): ≈ 1,500 MWh/yr × USD 0.30 / MWh ≈ USD 6,750 nominal undiscounted over 15 years.
Step 8 — Total nominal O&M ≈ USD 306,750.

LCOS

LCOS is computed inside the audited model as (PV of costs) / (PV of energy discharged over the horizon). With PV of costs = 2,898,267.65 USD and PV of energy discharged ≈ 10,358,247 kWh (sum of "Energy (kWh)" × discount factor rows above), LCOS = 2,898,267.65 / 10,358,247 ≈ 0.2798 USD/kWh (279.80 USD/MWh).

HS code & duty status (specific documents)

HTSUS heading: 8507.60 — Storage batteries, lithium-ion. Live entry: https://hts.usitc.gov/?query=8507.60. Containerized BESS units often classify under 8507.60 when the lithium-ion cells are the principal character; power conversion, switchgear, and enclosures may be separately reported under 8504.40 (static converters), 8537 (boards/panels), or 9406 (prefabricated buildings) depending on configuration and CBP ruling history.
Base duty lookup: read the "Rate of Duty 1-General" column on the live HTSUS page above. Confirm any "Special" or "Other" rate columns.
Section 301 (China-origin) status: review the USTR Section 301 tariff actions page — https://ustr.gov/issue-areas/enforcement/section-301-investigations. The model assumes 7.5% List 4A + 3.4% List 3 surcharges on China-origin cells/packs; verify the active action list at the date of entry.
Section 232 (steel/aluminum): confirm any active exclusions applicable to the container/switchgear enclosure at https://www.commerce.gov/232.
Binding ruling: file a CBP eRuling at https://erulings.cbp.gov/ for a binding classification and duty rate.
Live CBP CSMS messages: https://csms.cbp.gov/.

Certification block (specific standards)

UL 9540 — Energy Storage Systems and Equipment: https://www.shopulstandards.com/ProductDetail.aspx?UniqueKey=36250.
UL 1973 — Batteries for Use in Stationary, Vehicle Auxiliary Power and Light Electric Rail Applications: https://www.shopulstandards.com/ProductDetail.aspx?UniqueKey=35559.
UL 9540A — Test Method for Evaluating Thermal Runaway Fire Propagation in BESS: https://www.shopulstandards.com/ProductDetail.aspx?UniqueKey=36251.
IEEE 1547-2018 — Interconnection and Interoperability of DER: https://standards.ieee.org/ieee/1547/5915/.
NFPA 855 — Standard for the Installation of Stationary Energy Storage Systems: https://www.nfpa.org/codes-and-standards/nfpa-855-standard-development/855.
UL 1741 — Inverters, Converters, Controllers and Interconnection System Equipment: https://www.shopulstandards.com/ProductDetail.aspx?UniqueKey=35631.
UN Manual of Tests and Criteria, Rev. 7 (2023), Section 38.3 (lithium battery transport): https://unece.org/transport/dangerous-goods/un-manual-tests-and-criteria.

Scenario reading

Logistics-DC with strong demand-charge tariff and 1.5–2 cycles/day: the audited base case uses a conservative blended value-per-kWh-discharged of USD 0.095; a real site tariff at the upper end of the EIA logistics band (USD 20–25 / kW-month) plus 1.5–2 cycles/day is the most plausible path to closing the NPV gap. Re-run with site-specific tariff before ruling the project out.
Mid-use DC, ≈1 cycle/day, mixed demand + small arbitrage: this is closest to the audited inputs. Verdict on these inputs: do not proceed on financial grounds alone.
Backup-heavy, <1 cycle/day, regulated resilience duty: the year-by-year cashflow shows that throughput-light duty compounds the negative IRR because the same capex is amortized over fewer MWh delivered. Verdict: only viable if resilience is a regulated mandate with a separately quantified benefit line.

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