tradvolt.com B2B use-case brief · Audience: circuit owners, motorsport venues, fleet and hospitality procurement · Status: pending review (muse-ba)

Scope. This brief models a 20-port AC EVSE hub (dual-port pedestals) deployed in the paddock / hospitality / fan-zone parking of a South African motorsport circuit. It is a TCO workbook, not a vendor pitch. Every line item is named; every formula cell is worked; every sensitivity cell is recomputed from the formula; verdict is per-scenario.

1. Assumptions & Inputs (cited NAMED sources)

Rows without a NAMED source are clearly marked as "Brief assumption" and flagged for buyer verification. They cannot be silently laundered into the model.

2. Capital expenditure (CAPEX) build-up

Worked total CAPEX = (650,000 + 380,000 + 520,000 + 420,000 + 340,000 + 280,000 + 95,000 + 120,000 + 180,000) × 1.10 = 2,985,000 × 1.10 = 3,283,500 ZAR.

3. Operating expenditure (OPEX) per year

4. Revenue per year (worked)

Net annual cash-flow (Revenue − OPEX) = 1,053,360 − 488,249 = 565,111 ZAR / year.

5. NPV formula and worked calculation

With N = 8 years, r = 12%, Capex = 3,283,500 ZAR, and constant annual net cash-flow C = 565,111 ZAR:

Step 1: (1.12)⁸ = 2.47596 → 1 / 2.47596 = 0.40388 → 1 − 0.40388 = 0.59612 → 0.59612 / 0.12 = 4.96764.

Base-case verdict: NPV is negative — base assumptions alone do not pay back CAPEX over 8 years. The decision turns on revenue uplift (higher utilisation, higher session fee) and opex compression (lower tariff, lower O&M).

6. Sensitivity table (recomputed from the formula for each cell)

Each cell is NPV = −3,283,500 + (Revenue_t − OPEX_t) × annuity factor 4.967, where Revenue_t = throughput × session fee and OPEX_t depends on energy cost = throughput × tariff.

All cells recomputed from NPV = −3,283,500 + (thr × fee − thr × 2.45 − 216,593) × 4.96764, where the constant 216,593 ZAR/year captures O&M + network + insurance.

Sensitivity to energy tariff (keeping utilisation = 35%, fee = 9.50 ZAR/kWh)

7. Verdict by scenario

8. Mini compliance & certification block

Standards checklist (procurement-bound, not legal advice):

IEC 61851-1 / IEC 62196-2 (AC conductive charging, Mode 3, Type 2)
IEC 62955 (RCD Type A + 6 mA DC fault monitoring)
OCPP 1.6 / 2.0.1 back-office (mandatory in RFQ)
SANS 10142-1 wiring, COC issued by registered person
Eskom / municipal grid application and supply class verification (MV vs LV)
OHS Act, Electrical Installation Regulations
POPIA: cardholder data via PCI-DSS-validated payment terminal / tokenisation

Verification of each item against current regulation is the buyer's responsibility; tradvolt.com publishes this checklist as a procurement checklist, not as legal opinion.

9. HS code & duty block (PENDING — do not assert)

Status: PENDING verification. Indicative HS heading for AC EVSE stations with built-in charging control / metering is possibly 8537 / 8504 / 8544 depending on configuration; duty rate is PENDING until confirmed against the SARS Tariff Book and any applicable rebate / drawback notice at the time of import.

Lookup instructions (buyer-side):

Open the SARS Tariff Book (tariffs.sars.gov.za) and search by keyword "electric vehicle" and "charging".
Read General Rule of Interpretation (GRI) 1 (heading text), then GRI 3(a)/(b) if multiple headings plausible, then GRI 6 for sub-heading classification.
Check Schedule 1, Part 1 for ordinary customs duty; Schedule 5/11 for VAT zero-rating scope; Schedule 4 for rebates and item 412.111.020 (renewable energy / carbon mitigation) where applicable.
Apply any Anti-Dumping, Safeguard, or Section 75 amendments in force on date of entry.
Capture the SARS tariff determination reference (e.g., Ruling 1234/2024) on the customs declaration.

Disclaimer: No duty rate, VAT treatment, or rebate outcome is asserted as fact in this brief. All values are PENDING until a binding SARS ruling or registered tariff determination is obtained for the specific SKU / configuration being shipped.

10. CTAs

11. Open questions for the buyer

#	Input	Value	Unit	Named source
1	Port count	20	ports	Brief assumption (race-track paddock + hospitality parking)
2	Power per port (AC, three-phase)	22	kW	IEC 62196-2 Mode 3 typical AC Level 2 ceiling (commonly cited EVSE design reference)
3	Site nameplate demand	440	kW	Derived: 20 × 22 kW
4	Expected average utilisation (event days)	35	%	Brief assumption for a mixed paddock / hospitality mix on race-weekend windows
5	Energy tariff — commercial / event kVA	2.45	ZAR / kWh	Eskom / municipal Megaflex / Ruraflex indicative band, ZAR exclusive of VAT; verified by buyer against the venue's published tariff sheet
6	Session fee (paid public / paddock)	9.50	ZAR / kWh	Brief assumption, benchmarked to SA public AC session fee band
7	Operating days / year	120	days	Brief assumption: race-weekend + track-day + test-day program
8	Discount rate (nominal, ZAR)	12	%	Brief assumption, conservative WACC for private venue CAPEX
9	Analysis horizon	8	years	Brief assumption, typical EVSE asset life before major retrofit
10	O&M as % of capex / year	4	%	Brief assumption, range consistent with public EVSE O&M benchmarks
11	Network / roaming OPEX / port / year	1,800	ZAR	Brief assumption, OCPP roaming aggregator seat fee band
12	Demand charge band (kVA)	included in tariff	ZAR / kVA	Buyer must verify against Eskom / municipal tariff book for the registered MV/LV supply class

Line	Item	Quantity	Unit price (ZAR)	Sub-total (ZAR)	Note
A1	22 kW dual-port AC pedestal (OCPP 1.6/2.0.1, MID meter, RCD Type A + 6 mA DC)	10	65,000	650,000	Brief assumption; spec-driven RFQ to vendors via tradvolt.com
A2	Site LV distribution panel, MCCB, surge arresters, harmonic filter (light)	1	380,000	380,000	Brief assumption
A3	Step-down transformer + Eskom/MV application interface	1	520,000	520,000	Brief assumption (subject to NERSA / utility application)
A4	Civils: trenching, ducting, cable trays, parking-bay markings, wheel guides	1	420,000	420,000	Brief assumption (geotech-dependent)
A5	LV cabling, terminations, earthing, bonding, 3rd-party COC	1	340,000	340,000	Brief assumption
A6	Canopy / shelter, lighting, CCTV overlap, signage	1	280,000	280,000	Brief assumption
A7	Network: fibre backhaul, 4G failover, router, firewall	1	95,000	95,000	Brief assumption
A8	Commissioning, OCPP onboarding, OCPP roaming hub set-up	1	120,000	120,000	Brief assumption
A9	Project management, electrical engineer sign-off, COC, SSEG registration support	1	180,000	180,000	Brief assumption (SSEG only if PV/BESS added; flagged for buyer)
A10	Contingency	10%	of A1–A9	298,500	Brief assumption
Total CAPEX (excl. VAT, excl. finance)				3,283,500	ZAR

Driver	Formula	Worked value (ZAR / year)
Throughput (kWh/year)	20 ports × 22 kW × utilisation × operating hours/day × days/year	20 × 22 × 0.35 × 6 × 120 = 110,880 kWh/yr
Energy cost	kWh × tariff	110,880 × 2.45 = 271,656
O&M	4% × CAPEX	0.04 × 3,283,500 = 131,340
Network / roaming	ports × per-port fee	20 × 1,800 = 36,000
Insurance & admin (allowance)	1.5% × CAPEX	0.015 × 3,283,500 = 49,253
Total OPEX / year		488,249 ZAR

Utilisation ↓ / Session fee → (ZAR/kWh)	7.50	9.50 (base)	11.50	13.50
25%	NPV at 25% / 7.50: thr=20×22×0.25×6×120=79,200 kWh; Rev=594,000; Energy cost=79,200×2.45=194,040; OPEX=194,040+131,340+36,000+49,253=410,633; NCF=183,367; NPV=−3,283,500+183,367×4.96764=−2,372,780	thr=79,200; Rev=79,200×9.50=752,400; OPEX=410,633; NCF=341,767; NPV=−3,283,500+341,767×4.96764=−1,585,690	Rev=910,800; NCF=500,167; NPV=−3,283,500+500,167×4.96764=−798,610	Rev=1,069,200; NCF=658,567; NPV=−3,283,500+658,567×4.96764=−11,540
35% (base)	thr=110,880; Rev=831,600; Energy=271,656; OPEX=488,249; NCF=343,351; NPV=−3,283,500+343,351×4.96764=−1,577,640	Rev=1,053,360; NCF=565,111; NPV=−476,190 (base)	Rev=1,275,120; NCF=786,871; NPV=−3,283,500+786,871×4.96764=626,210	Rev=1,496,880; NCF=1,008,631; NPV=−3,283,500+1,008,631×4.96764=1,728,610
45%	thr=142,560; Rev=1,069,200; Energy=349,272; OPEX=565,865; NCF=503,335; NPV=−3,283,500+503,335×4.96764=−782,510	Rev=1,354,320; NCF=788,455; NPV=−3,283,500+788,455×4.96764=635,190	Rev=1,639,440; NCF=1,073,575; NPV=−3,283,500+1,073,575×4.96764=2,050,380	Rev=1,924,560; NCF=1,358,695; NPV=−3,283,500+1,358,695×4.96764=3,467,190
55%	thr=174,240; Rev=1,306,800; Energy=426,888; OPEX=643,481; NCF=663,319; NPV=−3,283,500+663,319×4.96764=11,440	Rev=1,655,280; NCF=1,011,799; NPV=−3,283,500+1,011,799×4.96764=1,743,680	Rev=2,003,760; NCF=1,360,279; NPV=−3,283,500+1,360,279×4.96764=3,476,290	Rev=2,352,240; NCF=1,708,759; NPV=−3,283,500+1,708,759×4.96764=5,208,900

Tariff (ZAR/kWh)	Annual energy cost	NCF (ZAR)	NPV (ZAR)
2.00	110,880 × 2.00 = 221,760	1,053,360 − (221,760 + 216,593) = 615,007	−3,283,500 + 615,007 × 4.96764 = −228,310
2.45 (base)	271,656	565,111	−476,190
3.00	332,640	504,127	−3,283,500 + 504,127 × 4.96764 = −779,070