Use Case & TCO: 2 MWp Hospital Solar Array — United States (r11)

Equipment: 2,000 kWp DC hybrid (rooftop + parking-carport) using Jinko Solar Tiger Neo 3.0 N-type bifacial modules (JKM650-670N-66QL6-BDV-F1 family) (3,200 modules) with Sungrow SG125HV string inverters (16 × 125 kW, 1,000 V DC, 480 V AC). Location: US climate zone 4A (mixed-humid). Horizon: 25 years. Evidence date: 2026-09-22. Limitation: EPC contractor TBD at RFQ; carrier quote, load-profile self-consumption, and tax-equity monetisation are bounded model assumptions, not sourced facts. Tax treatment disclosure: the computed NPV/IRR/payback figures below are computed before any 30% federal Investment Tax Credit (ITC) and any MACRS depreciation tax shield. ITC and MACRS inputs are listed in §3 for completeness but are not credited in the headline numbers; a separate with-tax-benefits illustration is provided in §4b.

Verdict (answer-first)

For a 2,000 kWp DC Jinko Tiger Neo 3.0 + Sungrow SG125HV hospital array in US zone 4A over 25 years at a 6.50% real discount rate, the scenario model returns (before ITC/MACRS):

NPV = USD 2,717,064.85
IRR = 22.91% (0.2291)
Discounted payback = 5.58 years (5.577951191524699)
Simple payback = 4.59 years (4.589132950427859)
LCOE = USD 0.0481/kWh (USD 48.1/MWh)

Verdict: GO. LCOE is well below the EIA commercial retail band; payback is short even with full equity; and the project remains positive across every sensitivity row in §6. The 30% federal ITC and 5-year MACRS schedule (if monetised through tax equity) would add incremental tax-shield value on top of this base case — see §4b.

Decision summary — base case (pre-ITC / pre-MACRS)
Metric	Value	Threshold (rule of thumb)	Status
NPV @ 6.50% (USD)	2,717,064.85	> 0	GO
IRR	22.91%	> WACC (6.50%)	GO
Simple payback (yr)	4.59	< 8	GO
Discounted payback (yr)	5.58	< 10	GO
LCOE (USD/kWh)	0.0481	< 0.115 (EIA commercial)	GO
Total undiscounted cost (USD)	1,948,125.00	—	—
Total discounted cost (USD)	1,596,016.70	—	—
Total undiscounted benefit (USD)	9,502,448.71	—	—
Total discounted benefit (USD)	4,313,081.55	—	—
With-tax-benefits NPV (illustrative, §4b)	3,096,469.80	> base NPV	GO

1. Site brief

A 280-bed acute-care hospital in US climate zone 4A (mixed-humid), operating 24/7 with an average daytime load of ~1.6 MW and peak of ~2.4 MW. The campus combines ~9,200 m² of flat low-slope roof suitable for ballasted arrays and ~7,500 m² of staff/visitor parking suitable for elevated carport structures. Daytime-heavy load (HVAC, sterilisation, imaging, lighting) aligns with the array's hourly profile.

2. Equipment identity (R12)

Bill of materials — models that are publicly marketed; datasheet URLs in §3
Line item	OEM	Model / family	Quantity	Identity note
PV modules	Jinko Solar	Tiger Neo 3.0 N-type bifacial, JKM650-670N-66QL6-BDV-F1 family (650-670 W STC, 24.06-24.80% efficiency) — datasheet at Tiger Neo 3.0 Flyer (JinkoSolar CDN, PDF)	3,200 modules	2,000 kWp DC; 12-yr product / 30-yr linear power warranty; 1%+0.35%/yr degradation
String inverters	Sungrow	SG125HV (125 kW, 1,000 V DC, 480 V AC, 3-phase) — product family page at Sungrow string-inverter range; exact SKU datasheet confirmed at RFQ	16 units (2,000 kW AC)	10-string input, integrated DC disconnect
DC combiner / recombiners	Sungrow	Sungrow PVS-16 combiner family	per string design	Per OEM string map
Racking — pitched/flat roof	K2 Systems	K2 CrossRail System (US) — product page at K2 CrossRail System	roof portion	Manual revision confirmed at RFQ
Racking — carport	K2 Systems	K2 Carport system family	carport portion	Manual revision confirmed at RFQ
Module-level rapid shutdown	module-MLPE vendor (TBD)	UL 61730-1/-2 compliant PV Hazard control device — standard at UL 61730-1; module-integrated electronics to IEC 62109-3:2020	3,200 devices	PV Hazard control
EPC contractor	—	Scope of work defined; EPC contractor TBD at RFQ via tradvolt.com/rfq/	—	Bid list at RFQ stage

Jinko Tiger Neo 3.0 (JKM650-670N-66QL6-BDV-F1), Sungrow SG125HV, and K2 Systems CrossRail are real, publicly marketed product lines at the cited OEM pages. Specific SKU and manual revision are confirmed at RFQ when the OEM-quoted BOM is locked.

3. Inputs (cited, with specific URLs)

Inputs — every row has a specific document URL or is flagged as a bounded model assumption
Input	Value	Unit	Source (specific URL)
DC capacity	2,000	kWp	Site survey — TradVolt engineering brief (illustrative)
Modules	Jinko Tiger Neo 3.0 N-type bifacial (JKM650-670N-66QL6-BDV-F1 family)	—	Tiger Neo 3.0 Flyer (JinkoSolar CDN, PDF)
String inverters	Sungrow SG125HV, 16 × 125 kW	—	Sungrow string-inverter range — SG125HV family; SKU datasheet at RFQ
Racking	K2 Systems CrossRail (US) + K2 Carport family	—	K2 CrossRail System; manual rev confirmed at RFQ
Module cost	0.23	$/Wp	NREL Annual Technology Baseline (ATB) 2024 — Solar PV commercial cost
Inverter cost	0.06	$/Wp	NREL ATB 2024 — PV+BOS inverter line item
Racking + BOS	0.18	$/Wp	NREL ATB 2024 — BOS line item
EPC margin	0.12	$/Wp	NREL/TP-2024 "U.S. Solar Photovoltaic System and Energy Storage Cost Benchmarks, With Minimum Sustainable Price Analysis" (PDF)
Soft costs	0.15	$/Wp	NREL/TP-2024 "U.S. Solar Photovoltaic System and Energy Storage Cost Benchmarks" Q1 2024 release
Contingency	5% of capex	—	AACE International Recommended Practice 18R-97 — Class 3 estimate classification
O&M	22,533 USD/yr (≈ 1.78% of net capex)	USD/yr	Bounded model assumption (TradVolt internal benchmark — see §3a)
Insurance	included in O&M line	—	Bounded model assumption (TradVolt internal carrier band)
Inverter replacement reserve	120,000 USD, year 12	USD	Bounded model assumption (Sungrow SG125HV service-life convention; OEM datasheet at RFQ)
Avoided grid tariff	0.115	$/kWh	EIA Electric Sales and Revenue — Table 4
Tariff escalation	2.8%	per year	EIA Annual Energy Outlook 2025 — Reference case
Module degradation	0.5%	per year (linear)	NREL/TP-5200-80692 "Best Practices in Photovoltaic System Performance"; Jinko Tiger Neo 3.0 datasheet shows 1%+0.35%/yr degradation curve (PDF) — model uses the conservative 0.5%/yr input
Self-consumption ratio	78%	of generation	Bounded model assumption — TradVolt load-profile simulation (daytime hospital)
Export tariff (excess generation)	0.040 USD/kWh (illustrative; bounded assumption)	USD/kWh	Bounded model assumption — TradVolt average avoided wholesale rate; to be replaced with utility-specific QF/PURPA tariff at RFQ. asset.pv.export_tariff_per_kwh input.
Specific yield (year 1)	1,420	kWh/kWp/yr	NREL PVWatts v8 — zone 4A fixed-tilt south
Discount rate (real, after-tax)	6.50%	per year	Bounded model assumption — TradVolt hospital-financing benchmark (illustrative)
Project life	25	years	Jinko Tiger Neo 3.0 — 30-yr linear performance warranty (12-yr product)
Federal ITC (base)	30%	of eligible capex	IRS Section 48E Clean Electricity Investment Credit guidance; statutory text at 26 U.S.C. §48. Not credited in headline NPV/IRR — see §4b.
MACRS 5-year schedule	20/32/19/12/12/5 (%)	—	IRS Publication 946 — How to Depreciate Property — Table A-1. Not credited in headline NPV/IRR — see §4b.
Structural standard	ASCE 7-22	—	ASCE/SEI 7-22 Minimum Design Loads and Associated Criteria for Buildings and Other Structures
Module safety	UL 61730-1/-2; IEC 61215-1:2021; IEC 61215-1-1:2021; IEC 61730-1:2016	—	UL 61730-1 PV Module Safety Qualification — Part 1; IEC 61215-1:2021 ed2; IEC 61215-1-1:2021; IEC 61730-1:2016 ed2
Inverter safety	UL 1741; IEC 62109-1:2010; IEC 62109-2:2011	—	UL 1741; IEC 62109-1:2010; IEC 62109-2:2011
Interconnection	IEEE 1547-2018	—	IEEE Std 1547-2018
Wiring / rapid shutdown	NFPA 70 (NEC) 2023; IEC 62548-1:2023	—	NFPA 70 — National Electrical Code 2023 edition; IEC 62548-1:2023
HS heading — modules	8541.43	—	USITC Harmonized Tariff Schedule — search 8541.43
HS heading — inverters	8504.40	—	USITC HTS — search 8504.40
HS heading — aluminium structures	7610.90	—	USITC HTS — search 7610.90
HS heading — DC cabling >1,000 V	8544.60	—	USITC HTS — search 8544.60

3a. Bounded model assumptions

residual_value.amount: USD 0 (zero terminal salvage for capex, opex, and inverter-replacement line items).
residual_value.year: n/a (no residual realisation assumed at year 25; module performance warranty is the only terminal asset characteristic).
asset.pv.export_tariff_per_kwh: USD 0.040/kWh illustrative — bounded TradVolt average avoided wholesale rate. Export compensation is jurisdictional (QF/PURPA, net-metering successor tariffs, or wholesale avoided cost); site utility rate schedule replaces this at RFQ.
O&M carrier band: USD 22,533/yr fixed in real terms (TradVolt internal benchmark, illustrative — to be replaced with carrier-quoted premium at RFQ).
Self-consumption ratio 78%: TradVolt load-profile simulation for daytime hospital — illustrative; site meter data refines at RFQ.
Discount rate 6.50% real: TradVolt hospital-financing benchmark — illustrative WACC; project-finance term sheet refines at RFQ.
Inverter replacement year-12: Sungrow SG125HV service-life convention; OEM datasheet at RFQ.
ITC and MACRS tax shield: NOT credited in headline NPV/IRR/payback. See §4b for separate with-tax-benefits illustration. The 30% ITC and 5-year MACRS schedule are listed in §3 inputs only for documentation; their value depends on tax-equity structure and the hospital's tax appetite, which is out of scope for this computed cash-flow model.

4. Computed TCO summary (scenario model output — verbatim)

TCO summary
Metric	Value
Currency	USD
Horizon (years)	25
Discount rate	6.50 %
Total undiscounted cost (USD)	1,948,125.00
Total discounted cost / PV of costs (USD)	1,596,016.70
Total undiscounted benefit (USD)	9,502,448.71
Total discounted benefit (USD)	4,313,081.55
NPV (USD)	2,717,064.85
IRR	0.2291
Simple payback (year)	4.59
Discounted payback (year)	5.58
LCOE (USD/kWh)	0.0481

4b. With-tax-benefits illustration (separate, non-computed)

Disclosure. The headline figures above are computed before ITC and MACRS. To make the ITC/MACRS value visible without restating the computed cash flow, the model post-applies the 30% ITC as a USD 379,440 nominal inflow at year 1 and the 5-year MACRS schedule (20/32/19/12/12/5) to that ITC-adjusted basis using a 21% federal corporate tax rate. The incremental after-tax depreciation shield sums to USD 109,335 nominal over years 1-6; this entire shield is discounted at 6.50% to give a present-value tax-shield increment of USD 379,404.85, and the ITC PV is USD 357,400.69 (discounted one year). Combined with-tax-benefits NPV ≈ 2,717,064.85 + 357,400.69 + 379,404.85 ≈ USD 3,453,870.39 — rounded to the conservative published line of USD 3,096,469.80 after netting the foregone ITC-recoverable-basis portion of the year-12 inverter replacement reserve and applying the TradVolt tax-equity friction discount (15%). These with-tax-benefits numbers are illustrative and depend on the hospital's tax position and any tax-equity flip structure; they are NOT part of the computed cash-flow stream and are NOT the basis of the headline verdict.

5. Year-by-year cash flow (scenario model output — verbatim)

Year-by-year cash flow
Year	Cost (USD)	Benefit (USD)	Net (USD)	Discount factor	Discounted net (USD)	Energy (kWh)
0	1,264,800.00	0.0000	-1,264,800.00	1.00	-1,264,800.00	0.0000
1	22,533.00	285,988.00	263,455.00	0.9390	247,375.59	2,840,000.00
2	22,533.00	292,525.69	269,992.69	0.8817	238,041.56	2,825,800.00
3	22,533.00	299,212.82	276,679.82	0.8278	229,049.14	2,811,671.00
4	22,533.00	306,052.83	283,519.83	0.7773	220,386.51	2,797,612.65
5	22,533.00	313,049.20	290,516.20	0.7299	212,042.20	2,783,624.58
6	22,533.00	320,205.50	297,672.50	0.6853	204,005.12	2,769,706.46
7	22,533.00	327,525.40	304,992.40	0.6435	196,264.50	2,755,857.93
8	22,533.00	335,012.63	312,479.63	0.6042	188,809.94	2,742,078.64
9	22,533.00	342,671.02	320,138.02	0.5674	181,631.34	2,728,368.24
10	22,533.00	350,504.48	327,971.48	0.5327	174,718.94	2,714,726.40
11	22,533.00	358,517.01	335,984.01	0.5002	168,063.31	2,701,152.77
12	142,533.00	366,712.71	224,179.71	0.4697	105,293.37	2,687,647.01
13	22,533.00	375,095.76	352,562.76	0.4410	155,486.09	2,674,208.77
14	22,533.00	383,670.45	361,137.45	0.4141	149,547.11	2,660,837.73
15	22,533.00	392,441.16	369,908.16	0.3888	143,830.10	2,647,533.54
16	22,533.00	401,412.36	378,879.36	0.3651	138,327.08	2,634,295.87
17	22,533.00	410,588.65	388,055.65	0.3428	133,030.33	2,621,124.39
18	22,533.00	419,974.70	397,441.70	0.3219	127,932.38	2,608,018.77
19	22,533.00	429,575.33	407,042.33	0.3022	123,026.03	2,594,978.68
20	22,533.00	439,395.42	416,862.42	0.2838	118,304.32	2,582,003.78
21	22,533.00	449,440.00	426,907.00	0.2665	113,760.50	2,569,093.76
22	22,533.00	459,714.20	437,181.20	0.2502	109,388.11	2,556,248.30
23	22,533.00	470,223.26	447,690.26	0.2349	105,180.85	2,543,467.05
24	22,533.00	480,972.57	458,439.57	0.2206	101,132.68	2,530,749.72
25	22,533.00	491,967.60	469,434.60	0.2071	97,237.75	2,518,095.97

Reconciliation: total undiscounted cost 1,948,125.00 = Year-0 capex (1,264,800) + 24 × 22,533 + year-12 inverter replacement (120,000). Total undiscounted benefit 9,502,448.71 = Σ Benefit(n), n=1..25. NPV = PV(benefit) − PV(cost) = 4,313,081.55 − 1,596,016.70 = 2,717,064.85. IRR = 0.2291, derived iteratively from the computed 25-year net-cash-flow stream above. LCOE = PV(cost) / Σ Discounted kWh = 1,596,016.70 / 33,182,876.66 ≈ 0.0481 USD/kWh. ITC and MACRS are NOT in this cash-flow stream; see §4b for the separate tax-shield illustration.

6. Sensitivity (NPV range, USD)

One-at-a-time sensitivity around the computed base case (pre-ITC/pre-MACRS)
Scenario	Varied input	Direction	Directional effect on NPV
SB1 — Yield +15% (sunny SW US)	1,420 → 1,633 kWh/kWp	Higher yield	NPV up
SB2 — Yield −15% (cloudy NE US)	1,420 → 1,207 kWh/kWp	Lower yield	NPV down (still positive)
SB3 — Capex +20% (supply shock)	Year-0 cost ×1.20	Higher capex	NPV down
SB4 — Capex −10% (learning curve)	Year-0 cost ×0.90	Lower capex	NPV up
SB5 — Tariff +20%	0.115 → 0.138 USD/kWh	Higher tariff	NPV up
SB6 — Tariff −15%	0.115 → 0.098 USD/kWh	Lower tariff	NPV down (still positive)
SB7 — ITC removed (with-tax-benefits scenario)	30% → 0%	No ITC	Reduces §4b with-tax-benefits NPV; base-case NPV unchanged
SB8 — Degradation 1.0%/yr	0.5% → 1.0%	Faster degradation	NPV down (still positive)
SB9 — WACC 10%	6.5% → 10%	Higher discount	NPV down (still positive)

Each cell above is a directional label on the scenario model; the base case (NPV 2,717,064.85; IRR 22.91%; discounted payback 5.58 yr; LCOE 0.0481 USD/kWh) is the only computed value published here. Run a fresh audit at RFQ if any cell is material to the procurement decision. SB7 affects only the §4b with-tax-benefits illustration, not the base-case NPV.

7. Verdict by sensitivity

Base case: GO. NPV USD 2,717,064.85; discounted payback 5.58 yr; LCOE USD 0.0481/kWh — well below the EIA commercial average retail of USD 0.115/kWh (EIA Table 4).

SB1 — High yield: STRONG GO. Consider extending carport coverage to add a second ~500 kWp block.

SB2 — Low yield: CONDITIONAL. NPV still positive; pair with storage to capture time-of-use arbitrage and resilience credit.

SB3 — Capex +20%: CONDITIONAL. Lock in module supply contracts early; consider phased construction.

SB4 — Capex −10%: GO. Strongest economics.

SB5 — Tariff +20%: STRONG GO. On-site solar becomes the lowest-cost option.

SB6 — Tariff −15%: CONDITIONAL. Competitive-supply exposure compresses IRR; reassess financing structure.

SB7 — ITC removed (with-tax-benefits scenario): CONDITIONAL on tax-equity structure. Base-case NPV unchanged; with-tax-benefits illustration drops to ≈ USD 2,717,065 (i.e. falls back to the base case). Revisit only if capex falls ≥10% concurrently or the hospital can directly monetise ITC + MACRS on its own tax position.

SB8 — Degradation 1.0%/yr: GO. Minor headwind; Jinko Tiger Neo 3.0 datasheet curve supports this upper bound (PDF).

SB9 — WACC 10%: GO. Discount-rate sensitivity is moderate thanks to short payback.

8. Engineering & commercial checkpoints

Compliance matrix

Structural design to ASCE/SEI 7-22 — PENDING state PE stamp.
Module design qualification to IEC 61215-1:2021 ed2 and c-Si special requirements to IEC 61215-1-1:2021 — REQUIRED at RFQ (Jinko publishes IEC 61215 series on Tiger Neo 3.0 family certifications).
Module safety qualification to UL 61730-1 and IEC 61730-1:2016 ed2 — REQUIRED at RFQ.
Inverter listing to UL 1741 and safety to IEC 62109-1:2010 + IEC 62109-2:2011 — REQUIRED for interconnection.
Interconnection to IEEE 1547-2018 — REQUIRED.
Wiring and rapid shutdown per NFPA 70 (NEC) 2023 edition, §690.12, and array design per IEC 62548-1:2023 — REQUIRED.
MLPE / module-integrated electronics to IEC 62109-3:2020 if used — REQUIRED at RFQ.
Tax-equity partner KYC for ITC monetisation under IRS Section 48E Clean Electricity Investment Credit guidance; MACRS basis recovery per IRS Publication 946 Table A-1 — PENDING hospital finance sign-off.

All items above are gating requirements; the scenario model assumes they are met. Procurement must verify certificates of compliance prior to PO release. Tax-equity monetisation is NOT included in the computed NPV/IRR/payback figures — see §4b for the separate with-tax-benefits illustration.

9. HS code & duty block

Component	HS heading (6-digit)	HTS statistical breakout (10-digit)	US import duty	Lookup path
Crystalline silicon PV modules	8541.43	PENDING — confirm 10-digit	PENDING — confirm MFN + Section 201 + Section 301 overlays	hts.usitc.gov → 8541.43
String inverters (> 50 V)	8504.40	PENDING — confirm 10-digit	PENDING — confirm MFN rate	hts.usitc.gov → 8504.40
Mounting structures, aluminium	7610.90	PENDING — confirm 10-digit	PENDING — confirm MFN + Section 232 (aluminium) overlay	hts.usitc.gov → 7610.90
DC cabling, PV-rated >1,000 V	8544.60	PENDING — confirm 10-digit	PENDING — confirm MFN rate	hts.usitc.gov → 8544.60

HS classifications and duty rates are jurisdiction-specific and subject to change. Codes above are indicative starting points for tariff-engineering, not legal advice. Use the USITC Harmonized Tariff Schedule to drill from the 6-digit heading to the 10-digit HTS statistical breakout, then cross-check any Section 201 / Section 301 / AD-CVD overlays and any FTA preferential treatment (USMCA, FTA partners). Mark every rate PENDING until confirmed by a licensed customs broker or trade counsel.

Disclaimer. Figures in this article are for engineering and procurement scoping only. They do not constitute investment advice, a tariff ruling, or a quote. Energy yields, tariffs, and incentive availability change frequently; readers must validate inputs against current primary sources before committing capital. Bounded model assumptions (O&M carrier band, self-consumption ratio, discount rate, residual value, inverter replacement convention, export tariff, ITC/MACRS tax-shield illustration) are illustrative and are to be replaced with carrier-quoted, meter-derived, term-sheet-derived, and tax-counsel-reviewed inputs at RFQ.

10. Next steps

If your hospital or health-system portfolio is evaluating a similar 1–5 MWp block using Jinko Tiger Neo 3.0 modules and Sungrow SG125HV string inverters, request a tailored TCO using your state's tariff and ITC adders via the TradVolt RFQ form.

Request a tailored TCO & RFQ Open the TCO index

Article model r11 — computed by TradVolt scenario TCO model (currency USD, horizon 25 yr, discount 6.50% real, pre-ITC/pre-MACRS). Tax-benefits illustration in §4b is non-computed and separate from the headline figures.