Verdict (NPV, 15-year, 11.0% WACC): −₹11.92 Cr (−119,195,413 INR). Equipment: 3,000 kWh LFP BESS + 1,500 kW PCS (C/2), containerised, paired with 4–6 MWp stadium rooftop PV. Location: India (multi-purpose stadium, 50,000–80,000 seats). Horizon: 15 years. Discount rate: 11.00 %. Evidence date: 2026-09-22. Limitation: indicative TCO only; no customs duty, no FCAS revenue, no broadcast-UPS capex credit included. Bounded assumptions are flagged [Assumption]. The scenario model has settled all numbers below; do not recalculate.
| Decision item | Value |
|---|---|
| Equipment / scope | 3,000 kWh LFP BESS + 1,500 kW PCS, containerised, paired with 4–6 MWp stadium rooftop PV |
| Location | India |
| Horizon | 15 years |
| Discount rate | 11.00 % |
| NPV | −119,195,413 INR (−₹11.92 Cr) |
| IRR | −0.2277 |
| Simple payback | None within horizon |
| Discounted payback | None within horizon |
| LCOS | 25.6213 INR/kWh (model output, denominator basis not disclosed) |
| Total undiscounted cost | 166,790,125 INR |
| Total undiscounted benefit | 49,840,096 INR |
| PV of costs | 143,997,714 INR |
| PV of benefits | 24,802,301 INR |
| Recommendation | Do not commit CAPEX on arbitrage + demand-charge stack alone; defer to a procurement window with stacked revenue (CERC ancillary, state DR, UPS capex displacement) or to a lower BESS ₹/kWh. |
Request an RFQ for a 3 MWh stadium ESS
| Parameter | Value | Notes |
|---|---|---|
| Venue profile | Multi-purpose stadium, 50,000–80,000 seats | Cricket / football match days + concerts |
| Critical sub-systems | Broadcast load, floodlights, HVAC chillers, EV chargers, UPS, scoreboards | Night fixtures drive evening peak |
| Load shape | Evening peak, ~1.2–1.6 MW sustained over 4–6 h | Day off-peak on non-event days |
| Stated battery size | 3,000 kWh / 1,500 kW (C/2) | Matches 2-hour utility ToU peak window |
| Primary value drivers | ToU arbitrage, peak shaving, PV self-consumption uplift, diesel offset, broadcast-quality ride-through | Stacked revenue considered qualitatively only |
| Site constraints | Urban footprint, fire-water setbacks, night-fixture sound limits | Containerised LFP preferred |
| Function | Named public model (real, on public datasheet) | Manufacturer evidence |
|---|---|---|
| Utility / containerised LFP BESS, liquid-cooled (ESS core) | Sungrow PowerTitan2.0 — 2,500 kW / 5,015 kWh per 20-ft container; max AC output 2,520 kW; DC 1500 V; operating −30 °C to 50 °C; 15 cm unit gap; ≥100 MWh station footprint ~1,200 m² | Sungrow PowerTitan2.0 product page (sized to match 3 MWh / 1.5 MW envelope; datasheet rev confirmed at RFQ) |
| Utility / containerised LFP BESS, single-unit datasheet reference | Sungrow ST2752UX — 2,752 kWh liquid-cooled container, 1500 V DC, operating −30 °C to 50 °C; pairs with SG3150/4400UD-MV MV skid | Sungrow ST2752UX product page (datasheet rev confirmed at RFQ) |
| PV modules (stadium rooftop 4–6 MWp) | LONGi Hi-MO 9 — up to 670 W, up to 24.8 % efficiency (HPBC 2.0 back-contact); 12-yr product warranty, 30-yr power warranty; bifaciality up to 80 % | LONGi Hi-MO 9 product page (module SKU confirmed at RFQ) |
| PV modules — alternate datasheet reference | Jinko Solar Tiger Neo 3.0 — 670 W output at 24.8 % module efficiency, TOPCon cells | JinkoSolar Tiger Neo 3.0 product page (module SKU confirmed at RFQ) |
| Residential / C&I string-inverter reference (C&I hybrid; size family) | Sungrow SH5/6/8/10/12T 3-phase hybrid — 5–12 kW, 400 V, 1000 V PV max, 98 % max efficiency, 200 % DC/AC oversizing, 2 MPPT, 0 ms switchover, IP65/C5, AFCI 2.0; pairs with SBH100-400 / SBR064-256 batteries | Sungrow SH5/6/8/10/12T product page (hybrid inverter family datasheet rev confirmed at RFQ; C&I-scale 1500 V string inverter datasheet to be requested at RFQ) |
| PV-side commercial string inverter (reference) | Fronius Verto 25.0 — 3-phase, multi-MPPT (Verto family 15–33.3) | Fronius Verto 25.0 datasheet page (manual rev confirmed at RFQ) |
| PV-side commercial string inverter (alternate) | SMA Sunny Tripower CORE1 — 33-US / 50-US / 62-US; 6 independent MPP trackers; 12 direct string inputs; 150–1000 V | SMA Sunny Tripower CORE1 product page (manual rev confirmed at RFQ) |
| EV chargers (site amenity) | Schneider Electric EVlink Pro DC 120 kW — EVD1S120TBB (CCS2 + CCS2, 3.6 m cable with CMS; range 120–180 kW) | Schneider EVlink Pro DC 120 kW product page (datasheet rev confirmed at RFQ) |
| PV mounting (rooftop) | K2 Systems rail/clamp kit — family only | K2 Systems (manual revision confirmed at RFQ) |
The 6,000-cycle to-80 % capacity retention figure and 92 % AC-AC round-trip efficiency used in the model are OEM-datasheet-typical values for utility-scale LFP prismatic cells at 25 °C, 1C/1C, 90 % DoD. They are not re-derived here; the model uses them as fixed inputs. A specific CATL / EVE / Sungrow datasheet revision must be requested via the RFQ form for any bankable run.
| Input | Unit | Value | Basis |
|---|---|---|---|
| Turnkey LFP BESS cost (utility-scale, ≥2 hr) | ₹/kWh | 26,000 | [Assumption] — bounded developer assumption |
| PCS + MV transformer skid | ₹/kW | 7,500 | [Assumption] — bounded developer assumption |
| EPC, BoS, EMS, SCADA (% of battery) | ₹/kWh | 9,000 | [Assumption] |
| Land & grid interconnect | ₹/kWh | 3,000 | [Assumption] |
| Fixed O&M | ₹/kWh/yr | 500 | [Assumption] |
| Augmentation (calendar-year 8, 20% capacity) | ₹ | computed inside table | [Assumption] on tranche size and timing |
| Cycle life to 80% (model input) | cycles | 6,000 | OEM-datasheet-typical; product datasheet at RFQ |
| Round-trip efficiency (model input) | % | 92% (AC-AC) | OEM-datasheet-typical; product datasheet at RFQ |
| ToU arbitrage spread (winter weighted) | ₹/kWh | 4.50 | [Assumption] — bounded developer assumption; site-specific DISCOM tariff order governs |
| Demand-charge / peak-draw savings | ₹/kW/yr | 2,800 | [Assumption] — bounded developer assumption |
| Annual cycles | cycles/yr | 320 | [Assumption] |
| WACC (post-tax, project finance) | % | 11.00 % | [Assumption] |
| Project life | years | 15 | Including augmentation at year 8 |
| Degradation — usable % of nameplate (asset.ess.usable_pct) | % | bounded default per model | [Assumption] — bounded; LCOS denominator basis not separately disclosed |
| Asset degradation — kWh-nameplate (%/yr used inside model) | %/yr | 2.0 | [Assumption] — bounded; visible as the kWh column declining year-on-year in the cash-flow table |
| Charge energy cost (asset.ess.charge_cost_per_kwh; ZERO-AS-MISSING) | ₹/kWh | 0.00 | [Assumption] — bounded; ZERO-AS-MISSING (i.e. spread figure is already net of charging tariff); any non-zero value would lower benefit |
| Residual value (terminal year 15) | ₹ | 0 | [Assumption] — bounded; salvage = 0 |
| LCOS denominator basis | — | model output, basis not disclosed | [Assumption] — bounded; LCOS is reported as 25.6213 INR/kWh, denominator basis (delivered kWh vs. discharged kWh vs. nameplate kWh) is not separately reconciled in the scenario model |
| Undiscounted cost reconciliation (166,790,125 INR) | ₹ | total = CAPEX (125,250,000) + sum of annual OPEX rows + augmentation tranche at year 8 (15,600,000 nominal embedded in the year-8 cost of 17,323,028.50) | [Assumption] — bounded; reconciliation against CAPEX + OPEX + augmentation sum not separately broken out in the computed table |
asset.ess.usable_pct is a bounded model default; LCOS is reported as 25.6213 INR/kWh without disclosing the denominator basis used by the scenario model. The total undiscounted cost of 166,790,125.37 INR is the model output; CAPEX + OPEX + augmentation sum is not separately broken out in the computed table. These inputs are model defaults, not sourced facts; they are the levers that govern the final NPV within the model envelope.
| Metric | Value |
|---|---|
| Currency | INR |
| Horizon (years) | 15 |
| Discount rate | 11.00 % |
| Total undiscounted cost (INR) | 166,790,125.37 |
| Total discounted cost / PV of costs (INR) | 143,997,714.46 |
| Total undiscounted benefit (INR) | 49,840,095.60 |
| Total discounted benefit (INR) | 24,802,301.42 |
| NPV (INR) | -119,195,413.04 |
| IRR | -0.2277 |
| Simple payback (year) | — |
| Discounted payback (year) | — |
| LCOS (INR/kWh) | 25.62 |
| Year | Cost (INR) | Benefit (INR) | Net (INR) | Discount factor | Discounted net (INR) | Energy (kWh) |
|---|---|---|---|---|---|---|
| 0 | 125,250,000.00 | 0.0000 | -125,250,000.00 | 1.00 | -125,250,000.00 | 0.0000 |
| 1 | 1,500,000.00 | 3,812,869.57 | 2,312,869.57 | 0.9009 | 2,083,666.27 | 864,000.00 |
| 2 | 1,530,000.00 | 3,736,612.17 | 2,206,612.17 | 0.8116 | 1,790,935.94 | 846,720.00 |
| 3 | 1,560,600.00 | 3,661,879.93 | 2,101,279.93 | 0.7312 | 1,536,437.77 | 829,785.60 |
| 4 | 1,591,812.00 | 3,588,642.33 | 1,996,830.33 | 0.6587 | 1,315,373.99 | 813,189.89 |
| 5 | 1,623,648.24 | 3,516,869.49 | 1,893,221.25 | 0.5935 | 1,123,534.66 | 796,926.09 |
| 6 | 1,656,121.20 | 3,446,532.10 | 1,790,410.89 | 0.5346 | 957,226.78 | 780,987.57 |
| 7 | 1,689,243.63 | 3,377,601.45 | 1,688,357.82 | 0.4817 | 813,211.75 | 765,367.82 |
| 8 | 17,323,028.50 | 3,310,049.42 | -14,012,979.08 | 0.4339 | -6,080,602.91 | 750,060.46 |
| 9 | 1,757,489.07 | 3,243,848.44 | 1,486,359.36 | 0.3909 | 581,054.69 | 735,059.25 |
| 10 | 1,792,638.85 | 3,178,971.47 | 1,386,332.61 | 0.3522 | 488,244.83 | 720,358.07 |
| 11 | 1,828,491.63 | 3,115,392.04 | 1,286,900.41 | 0.3173 | 408,312.03 | 705,950.91 |
| 12 | 1,865,061.46 | 3,053,084.20 | 1,188,022.73 | 0.2858 | 339,585.40 | 691,831.89 |
| 13 | 1,902,362.69 | 2,992,022.51 | 1,089,659.82 | 0.2575 | 280,602.94 | 677,995.25 |
| 14 | 1,940,409.95 | 2,932,182.06 | 991,772.12 | 0.2320 | 230,086.00 | 664,435.34 |
| 15 | 1,979,218.14 | 2,873,538.42 | 894,320.28 | 0.2090 | 186,916.83 | 651,146.64 |
CAPEX at year 0 = 125,250,000 INR (consistent with cash-flow row 0). Year-8 cost of 17,323,028.50 INR is the augmentation tranche plus operating OPEX for that year, as built into the scenario model. Discount factors are 1/(1.11)t.
Year-8 augmentation is the single largest negative-cash-flow event in the table (−₹1.40 Cr nominal, −₹60.8 L discounted); it is also the year in which a deferred-CAPEX case would have compounded benefit for an extra period. Replacing the augmentation tranche with a deferred-new-stack strategy (i.e. accepting higher cycling degradation past year 8 in exchange for skipping the tranche) is the main cost-side lever inside the same model envelope.
| Standard / instrument | Issuer | Identifier / path | Status in this scenario |
|---|---|---|---|
| IEC 62619:2022 ed2 — Safety requirements for secondary lithium cells and batteries for use in industrial applications incl. stationary/ESS (TC 21/SC 21A) | IEC | IEC 62619:2022 ed2 publication page (IEC Webstore) | Cell-level compliance — confirm on datasheet revision at RFQ |
| IEC 63056:2020 — Safety requirements for secondary lithium cells and batteries for use in electrical energy storage systems (up to 1500 V DC) | IEC | IEC 63056:2020 publication page (IEC Webstore) | Stationary ESS compliance — confirm on datasheet revision at RFQ |
| IEC 62109-1:2010 — Safety of power converters for use in PV power systems, Part 1: General requirements (TC 82) | IEC | IEC 62109-1:2010 publication page (IEC Webstore) | PV PCS safety — confirm on datasheet revision at RFQ |
| IEC 62109-2:2011 — Safety of power converters for use in PV power systems, Part 2: Particular requirements for inverters (TC 82) | IEC | IEC 62109-2:2011 publication page (IEC Webstore) | Used jointly with IEC 62109-1 — confirm on datasheet revision at RFQ |
| IEC 62485-5:2020 — Safety requirements for secondary batteries and battery installations, Part 5: Safe operation of stationary lithium-ion batteries (TC 21, 76 pp) | IEC | IEC 62485-5:2020 publication page (IEC Webstore) | Installation-level stationary Li-ion compliance — confirm on datasheet revision at RFQ |
| UL 1973 — Batteries for Use in Stationary and Motive Auxiliary Power Applications | UL | UL 1973 product page (UL Shop) | Module-level compliance — confirm at RFQ |
| UL 9540A — Standard for Test Method for Evaluating Thermal Runaway Fire Propagation in BESS | UL | UL 9540A service page (UL) | Required for dense urban India sites; concrete certificate ID pending RFQ — do not assert a generic "mandatory for urban stadium siting" without the holder ID |
| NFPA 855 — Standard for the Installation of Stationary Energy Storage Systems | NFPA | NFPA 855 standard development page | Reference standard for siting — confirm current edition applicability at RFQ |
| UL 61730-1 — PV Module Safety Qualification, Part 1 | UL | UL 61730-1 product page (UL Shop) | PV module safety — confirm on datasheet revision at RFQ |
| IEEE 1547-2018 — Standard for Interconnection and Interoperability of DER with Associated Electric Power Systems Interfaces | IEEE | IEEE 1547-2018 standard page | DER interconnection compliance — confirm on datasheet revision at RFQ |
| IEC 61851-1:2017 — Electric vehicle conductive charging system, Part 1 (TC 69) | IEC | IEC 61851-1:2017 document page (IEC Webstore) | EV-charger sub-system only |
| UN 38.3 — Lithium battery transport tests | UNECE | UN Manual of Tests and Criteria (ST/SG/AC.10/11/Rev.7 and amendments) | Required for any sea / air shipment of cells — shipping-line / IATA DGR compliance at IATA DGR programme |
| India BESS grid connection and safety | Applicable Indian authorities and network operator | PENDING — obtain the applicable grid-connection and safety documents for the project. Customs portals do not establish grid-side requirements. | Confirm the document title, revision and applicability before design approval. |
| ISPM 15 — Wood packaging compliance for imports | IPPC | IPPC ISPM standards list | Required for any wood pallets / crating in the import shipment |
| Clean Energy Council approved-battery list (Australia reference; SRES / network connection) | Clean Energy Council (Australia) | CEC approved batteries list | Reference list for AU / Indian-spec module equivalent class — confirm equivalence at RFQ |
India classifies lithium-ion BESS components across Chapter 85 (Section XVI). Indicative headings (not a duty determination):
Duty treatment in India depends on (a) whether cells are imported separately or as part of an integrated rack, (b) country of origin (Korea / China / India-domestic carry different BCD outcomes, with potential FTA / EHTP / SION interactions), and (c) the applicable Customs Notification under CBIC. The figures in this page do not include customs duty as a cost line. For a bankable run, confirm classification and duty against the current CBIC Customs Tariff (Chapter 85) and any applicable notification before filing the Bill of Entry. Reference points:
Tradvolt does not assert any duty rate as fact. The HS codes above are illustrative placeholders; final duty is to be confirmed with a licensed customs broker or the buyer's CHA prior to filing.
Request an RFQ for a 3 MWh stadium ESS
Figures in this document are the computed outputs of the TCO model for the inputs in section 3. They do not constitute a quotation, financial advice, or a customs ruling. Inputs flagged [Assumption] are bounded developer assumptions, not sourced facts. Equipment names in section 2 are real, publicly-marketed products with the cited datasheet or product pages; the relevant datasheet revision for the bankable run must be confirmed via RFQ. All cost, revenue, and certification claims should be re-validated against current vendor datasheets, the applicable state DISCOM tariff order, and current CBIC notifications before any commercial commitment. Tradvolt accepts no liability for decisions taken on the basis of this model.
Evidence pack reference date: 2026-09-22. computed figures per scenario model: NPV −119,195,413.04 INR; IRR −0.2277; LCOS 25.6213 INR/kWh (model output, denominator basis not disclosed).