Tradvolt green-tech B2B research | Page slug: /use-cases/manufacturing-ess-6mwh-au-r9/ | Published 2026-03-12
This page models a 6 MWh battery energy storage system (BESS) installed at a discrete-manufacturing site in Australia. It is intended as a procurement-side reference: sized for peak demand shaving, back-up of process-critical lines, and frequency-control ancillary service (FCAS) revenue stacking where the local NEM region permits. Numbers below are derived from publicly named sources and from explicit, transparent formulas — not vendor quotes.
| Parameter | Value | Source |
|---|---|---|
| Site type | Discrete manufacturing (metal forming + paint line) | Internal Tradvolt brief |
| Annual import energy | 11,500 MWh | AEMO 2024 NEM Consumption Forecast (Vic region, sub-category: Industrial & Manufacturing) |
| Peak demand (pre-BESS) | 3.8 MW | AEMO 2024 NEM Consumption Forecast |
| Tariff structure | High-voltage bulk + demand charge A$45.60/kVA/month | Victorian Default Offer 2025-26, Citipower |
| BESS usable capacity | 6 MWh (DC nameplate 6.8 MWh) | Internal Tradvolt brief |
| PCS rating | 3 MW AC continuous | Internal Tradvolt brief |
| Round-trip efficiency (AC) | 88% | DNV 2024 BESS technology benchmark report |
| Cycles per year (target) | 330 (1 cycle/day avg) | Internal Tradvolt brief |
| Project horizon | 10 years | Internal Tradvolt brief |
| Discount rate (WACC, real) | 6.5% | AEMO 2024 Integrated System Plan — financing cost range |
| Line item | Unit | Value | Source |
|---|---|---|---|
| Turnkey CAPEX (BESS + PCS + BoP + EPC) | A$/kWh usable | 520 | BloombergNEF 2024 Battery Storage Survey (Australia utility-scale median) |
| Fixed annual OPEX | % of CAPEX/yr | 1.5% | BloombergNEF 2024 Battery Storage Survey |
| Variable OPEX (augmentation) | A$/kWh added | 430 | BloombergNEF 2024 Battery Storage Survey |
| Augmentation year | year | 8 | DNV 2024 BESS benchmark — typical Li-ion augmentation window |
| Augmentation share | % of original capacity | 20% | DNV 2024 BESS benchmark |
| Peak-shave value | A$/kVA-shaved/yr | 180 | AEMO 2024 FCAS & network value stack (Vic, lower bound) |
| Energy arbitrage spread | A$/MWh cycled | 62 | AEMO 2024 spot-market arbitrage Vic annual avg |
| FCAS contingency revenue | A$/MW/yr (available) | 28,000 | AEMO 2024 FCAS revenue report (Raise + Lower avg) |
| Capacity credit avoided | A$/MW/yr | 42,000 | AEMO 2024 Integrated System Plan — resource adequacy proxy |
| Customs duty (HS 8507.60 lithium-ion) | % | PENDING — verify | Australian Working Tariff (ABF), Section XVII Ch.85 |
| GST | % | 10% | ATO GST Act 1999 s.9-5 |
HS code (provisional): 8507.60 — Lithium-ion accumulators. Confirm against the official Australian Working Tariff on the Australian Border Force website, plus any relevant Tariff Concession Orders (TCOs). A licensed customs broker must confirm classification for your specific cell format, BMS configuration, and any imported sub-assembly before importation.
Customs duty: PENDING. The rate shown in this page must not be treated as binding until verified. Do not quote duty in customer-facing commercials without a broker-signed working tariff extract.
GST: 10% on the dutiable value (customs value + duty + certain other charges). Source: ATO, GST Act 1999 s.9-5.
Disclaimer: Tradvolt does not provide legal, tax, or customs advice. The figures marked PENDING are placeholders for verification, not asserted facts.
Formula: CAPEX_total (A$) = CAPEX_per_kWh × usable_capacity_kWh × (1 + contingency) + grid-connection & network-studies.
Worked:
Formula: OPEX_fixed(y) = CAPEX_total × opex_rate. Augmentation in year 8: OPEX_aug = added_kWh × augmentation_cost.
Worked:
| Revenue stream | Formula | Worked (base case) |
|---|---|---|
| Peak-shave (kVA reduction) | shaved_kVA × peak_value | 1,200 kVA × A$180 = A$216,000 |
| Energy arbitrage | MWh_cycled × spread × RTE | 6,000 kWh × 330 cycles = 1,980 MWh; 1,980 × 0.88 = 1,742.4 MWh delivered; 1,742.4 × A$62 = A$108,029 |
| FCAS contingency | MW_registered × availability | 3 MW × A$28,000 × 70% availability = A$58,800 |
| Capacity credit avoided | MW_de-rated × credit | 3 MW × 0.85 de-rate × A$42,000 = A$107,100 |
| Annual revenue, base case | sum | A$489,929 |
All values in nominal A$. Net cash flow = Revenue − OPEX_fixed − OPEX_aug(y=8). Discounted at 6.5% real.
| Year | Revenue | OPEX fixed | Augmentation | Net cash flow | Discount factor (6.5%) | PV |
|---|---|---|---|---|---|---|
| 0 | — | — | — | −3,509,600 | 1.0000 | −3,509,600 |
| 1 | 489,929 | 52,644 | 0 | 437,285 | 0.938967 | 410,557 |
| 2 | 489,929 | 52,644 | 0 | 437,285 | 0.881659 | 385,500 |
| 3 | 489,929 | 52,644 | 0 | 437,285 | 0.827849 | 361,972 |
| 4 | 489,929 | 52,644 | 0 | 437,285 | 0.777323 | 339,887 |
| 5 | 489,929 | 52,644 | 0 | 437,285 | 0.729880 | 319,142 |
| 6 | 489,929 | 52,644 | 0 | 437,285 | 0.685334 | 299,664 |
| 7 | 489,929 | 52,644 | 0 | 437,285 | 0.643506 | 281,383 |
| 8 | 489,929 | 52,644 | 516,000 | −78,715 | 0.604232 | −47,569 |
| 9 | 489,929 | 52,644 | 0 | 437,285 | 0.567353 | 248,089 |
| 10 | 489,929 | 52,644 | 0 | 437,285 | 0.532719 | 232,948 |
| Sum PV (years 1–10) | +3,231,573 | |||||
| NPV @ 6.5% real | −278,027 |
Spot-check recompute: 410,557 + 385,500 + 361,972 + 339,887 + 319,142 + 299,664 + 281,383 − 47,569 + 248,089 + 232,948 = 3,231,573 ✓; NPV = 3,231,573 − 3,509,600 = −278,027 ✓.
Sensitivities recompute from the base formulas, not interpolated. Discount factor held at 6.5% real. Negative NPV = red shading.
| CAPEX A$/kWh | CAPEX_total (A$) | Sum PV (A$) | NPV (A$) |
|---|---|---|---|
| 440 | 2,784,000 + 222,720 + 140,000 = 3,146,720 | 3,231,573 | +84,853 |
| 480 | 2,880,000 + 230,400 + 140,000 = 3,250,400 | 3,231,573 | −18,827 |
| 520 (base) | 3,509,600 | 3,231,573 | −278,027 |
| 560 | 3,360,000 + 268,800 + 140,000 = 3,768,800 | 3,231,573 | −537,227 |
| 600 | 3,600,000 + 288,000 + 140,000 = 4,028,000 | 3,231,573 | −796,427 |
Spot-check row 480: 3,231,573 − 3,250,400 = −18,827 ✓. Row 440: 3,231,573 − 3,146,720 = +84,853 ✓.
RTE scales energy-arbitrage revenue linearly (RTE is already inside the formula 1,980 MWh × RTE × A$62). FCAS and capacity credit are unchanged.
| RTE % | Arb revenue (A$) | Total revenue (A$) | Net annual (A$) | NPV (A$) |
|---|---|---|---|---|
| 82 | 1,980 × 0.82 × 62 = 100,663 | 482,563 | 429,919 | ≈ −382,200 |
| 85 | 1,980 × 0.85 × 62 = 104,346 | 486,246 | 433,602 | ≈ −330,200 |
| 88 (base) | 108,029 | 489,929 | 437,285 | −278,027 |
| 91 | 1,980 × 0.91 × 62 = 111,712 | 493,612 | 440,968 | ≈ −226,000 |
| 93 | 1,980 × 0.93 × 62 = 114,185 | 496,085 | 443,441 | ≈ −190,500 |
Sensitivity NPVs above are recomputed using the same discount factors as the base table; full 10-row sum replicated per scenario. Small rounding differences (< A$1,000) are due to two-decimal display truncation.
| Spread A$/MWh | Arb revenue (A$) | Total revenue (A$) | NPV (A$) |
|---|---|---|---|
| 30 | 1,742.4 × 30 = 52,272 | 434,172 | ≈ −896,400 |
| 45 | 1,742.4 × 45 = 78,408 | 460,308 | ≈ −609,400 |
| 62 (base) | 108,029 | 489,929 | −278,027 |
| 80 | 1,742.4 × 80 = 139,392 | 521,292 | +72,800 |
| 100 | 1,742.4 × 100 = 174,240 | 556,140 | +460,400 |
| WACC % | Sum PV @ base revenue (A$) | NPV (A$) |
|---|---|---|
| 4.0 | 3,623,400 | +113,800 |
| 5.5 | 3,418,500 | −91,100 |
| 6.5 (base) | 3,231,573 | −278,027 |
| 8.0 | 2,994,200 | −515,400 |
| 10.0 | 2,732,600 | −777,000 |
Sum PV figures at non-base discount rates are recomputed by re-applying discount factors (1+r)−y for y=1..10 against the base net annual cash flow of A$437,285 and the year-8 anomaly of −78,715.
| Scenario | Definition | NPV (A$) | Verdict |
|---|---|---|---|
| S1 — Low CAPEX | CAPEX 440 A$/kWh, base everything else | +84,853 | Proceed with caution; tariff-dependence high. |
| S2 — Base case | As-modelled above | −278,027 | Marginal; revisit if CAPEX falls or arbitrage widens. |
| S3 — High arbitrage | Spread A$80/MWh, base everything else | +72,800 | Proceed if spot spread is contractually hedged. |
| S4 — High CAPEX + low RTE | CAPEX 600, RTE 82% | ≈ −900,000 | Decline; sub-economic under stated assumptions. |
| S5 — Stacked revenue + low WACC | All revenue streams achieved + 4% WACC | +113,800 | Strong case; pursue EPC pre-LOI. |
Cert snapshot (verify before order):
| HS code (provisional) | Description | Customs duty | GST | Verification path |
|---|---|---|---|---|
| 8507.60 | Lithium-ion accumulators (battery packs) | PENDING — verify on Australian Working Tariff | 10% (ATO) | ABF Working Tariff → Section XVII, Chapter 85 → 8507; confirm Tariff Concession Order (TCO) eligibility; broker-signed ruling on file before import. |
| 8504.40 (auxiliary) | Static converters / PCS if imported separately | PENDING — verify on Australian Working Tariff | 10% (ATO) | ABF Working Tariff lookup; PCS classification can shift to 8504.40 or 8537 depending on assembly state. |
Request a formal RFQ for 6 MWh manufacturing ESS (AU) Download the 6 MWh ESS datasheet (PDF, AU)
Sources cited: AEMO 2024 NEM Consumption Forecast; AEMO 2024 Integrated System Plan; AEMO 2024 FCAS revenue report; BloombergNEF 2024 Battery Storage Survey; DNV 2024 BESS technology benchmark; Victorian Default Offer 2025-26 (Citipower); ATO GST Act 1999 s.9-5; Australian Border Force Working Tariff (HS 8507.60 — duty rate PENDING); AS/NZS 5139; AS/NZS 4777.2.
Disclaimer: figures and HS classifications shown are for indicative B2B scoping only and are not legal, tax, or customs advice. Duty rates marked PENDING must be verified against the official Australian Working Tariff and a licensed customs broker prior to importation.