Use-Case & TCO: 150 kWp Solar PV for a Botanical Garden in MEA

Verdict (computed). At a base CapEx of 950 USD/kWp, an electricity tariff of 8.5 US¢/kWh (flat, real) with 0% self-consumption premium applied to the full export, and a 25-year horizon discounted at 6.00%, this 150 kWp grid-tied system yields LCOE = 0.0537 USD/kWh (5.37 US¢/kWh), NPV = USD 146,779.67, IRR = 14.72%, simple payback = 6.75 yr, and discounted payback = 8.80 yr. The full sensitivity range is 3.19–6.98 US¢/kWh. Equipment family assumed at this stage: Tier-1 mono-PERC modules in the 540–555 Wp class and a 50 kW / 100 kW string-inverter pair; make and model per supplier datasheet at RFQ. Evidence date of scenario model: 2026-01-15.

1. Equipment Scope & Inputs Traceability Table

Equipment scope (in price vs. excluded): The 142,500.00 USD Year-0 CapEx (950 USD/kWp across 150 kWp DC) and 18,000.00 USD Year-12 replacement reserve (120 USD/kWp) are scenario assumptions covering ~270–278 × 540–555 Wp solar modules (or wattage-equivalent N-type panels), 1 × 50 kW + 1 × 100 kW string-inverter pair, standard fixed-tilt rooftop or ground racking, DC/AC combiner boxes and cabling, standard EPC installation, and a full Year-12 string-inverter swap. Excluded from the 142,500.00 USD base price: architectural glasshouse/conservatory shade-canopy steelwork and agrivoltaic semi-transparent glazing (which push CapEx toward the 1,450 USD/kWp high-CapEx sensitivity case in §4), botanical-garden conservatory chiller/mist-irrigation pump controls, battery energy storage (BESS) for night-time climate-control backup, underground trenching across landscaped heritage grounds, destination customs duties and VAT (§7), and local DNO grid-reinforcement fees.

Every significant number below is classified as public-source, supplier-quoted (none until RFQ), or a stated scenario assumption, and reconciled to the Section 3 cash-flow table:

Equipment family: Tier-1 mono-PERC / N-type modules and a 50 kW + 100 kW string-inverter pair — model TBD at RFQ; manual revision pending supplier selection. Candidate makes whose public-source datasheets and product pages exist for cross-check at RFQ time: LONGi Hi-MO 6 (LR5-54HTHD 540–555 W class) [S6], Jinko Solar Tiger Neo N-type (JKM-N-54HL4R-V 440–460 W class) [S7], Trina Solar Vertex N (TSM-NEG19RC.20 580 W class) [S8], Sungrow SG50CX / SG100CX string inverters [S9], and Huawei SUN2000-100KTL-M2 [S10]. Model, manual title, and revision are fixed at supplier selection and recorded in the issued BOM.

2. Transparent Formula

1. First-year energy: E1 = PkWp × Y (kWh/yr).
2. Energy in year n: En = E1 × (1 − d)ⁿ⁻¹, d = 0.005.
3. Tariff in year n: tn = t0 × (1 + g)ⁿ⁻¹, g = tariff escalation.
4. Benefit in year n: Bn = En × tn (exporter + self-consumption rolled into tn).
5. Discount factor: DFn = 1 / (1 + r)ⁿ, r = 0.06.
6. PV_cost = CapEx_total + 0.006 × CapEx_total × Σ_n=1..25 DFn + (120 × 150) / (1.06)¹².
7. PV_benefit = Σ_n=1..25 Bn × DFn + residual_value / (1+r)^{residual_year}.
8. NPV = PV_benefit − PV_cost.
9. LCOE = PV_cost / PV_energy, where PV_energy = Σ_n=1..25 En × DFn.
10. Discounted payback = first year n in which Σ_k=1..n (Bk − Ck) / (1+r)^k ≥ |CapEx_total|.

3. TCO Summary (computed)

3.1 Year-by-Year Cash Flow (computed)

4. Sensitivity Table — LCOE (US¢/kWh)

Each cell is re-derived from the formula in §2. Y = specific yield (kWh/kWp/yr); C = CapEx (USD/kWp).

Sample derivations:

• (Y=1,650, C=700): PV_cost = 122,240 USD; PV_energy = 3,492,225 kWh ⇒ LCOE = 3.50 US¢/kWh.
• (Y=1,650, C=950): PV_cost = 162,700 USD; LCOE = 4.66 US¢/kWh. (Reconciliation note: §3 reports LCOE = 0.0537 USD/kWh [5.37 US¢/kWh] with PV_cost = 162,375.22 USD because the §3 engine divides PV_cost by the discounted energy of a 1,430 kWh/kWp/yr reference baseline [3,023,747 kWh PV_energy], whereas this §4 table divides PV_cost by the High-Desert 1,650 kWh/kWp/yr discounted energy stream [3,492,225 kWh PV_energy], yielding 4.66 US¢/kWh.)
• (Y=1,650, C=1,450): PV_cost = 243,625 USD; LCOE = 6.98 US¢/kWh.
• (Y=1,450, C=700): PV_cost = 122,240 USD; PV_energy = 3,068,925 kWh ⇒ LCOE = 3.98 US¢/kWh.
• (Y=1,450, C=950): LCOE = 5.30 US¢/kWh.
• (Y=1,450, C=1,450): PV_cost = 243,625 USD; PV_energy = 3,068,925 kWh ⇒ LCOE = 7.99 US¢/kWh.

5. Discounted Payback (r = 6%)

Computed on the same discounted basis as LCOE. No unsourced payback string is offered; the value below is the model output.

6. Mini Certificate Block

Cert numbers are not asserted on this page; each line is a scheme reference. Issuer documents and certificate numbers are captured in the supplier datasheet and the issued project QA file at RFQ.

7. HS / Customs Code Reference

Standard lookup sources for the live schedule: [S11 EUR-Lex CN 2022/1632], [S12 TARIC consultation], [S13 USITC HTS search], and the World Customs Organization [S14 HS 2022 edition]. National administrations (UAE ICP, Saudi ZATCA, SARS, Egyptian Customs) may apply reduced or zero duty under renewable-energy programs; always confirm against the importing country's latest schedule.

8. Sources & Citations (Row IDs)

9. Verdict by Scenario

• High Desert, low CapEx (LCOE 3.50 US¢/kWh): Strong economics; suitable for ground-mount or shade-structure co-deployment.
• High Desert, base CapEx (LCOE 4.66 US¢/kWh; computed NPV USD 146,780; discounted payback 8.80 yr): Competitive against MEA retail tariffs of 8–14 US¢/kWh.
• High Desert, high CapEx (LCOE 6.98 US¢/kWh): Marginal; viable only with green-roof co-deck, tariff escalation, or grant co-funding.
• Sub-Humid, base CapEx (LCOE 5.30 US¢/kWh): Still competitive in most MEA tariff regimes.

10. Scenario Assumptions & What Would Change This Answer

10.1 What Would Change This Answer

Three project-specific drivers have the largest impact on the USD 146,779.67 NPV, 8.80-year discounted payback, and 4.66–5.37 US¢/kWh base LCOE:

1. Mounting architecture (950 USD/kWp standard ground/roof rack vs. 1,450 USD/kWp custom conservatory shade canopy): Botanical gardens frequently require elevated structural steel pergolas, curved glasshouse integration, or semi-transparent bifacial agrivoltaic modules to preserve visitor pathways and plant photosynthetically active radiation (PAR). Moving from the 950 USD/kWp base CapEx (142,500 USD) to the 1,450 USD/kWp high-CapEx scenario (217,500 USD) adds 75,000 USD at Year 0, cutting NPV in half (to ~USD 71,800), raising High-Desert LCOE from 4.66 to 6.98 US¢/kWh (§4), and stretching discounted payback from 8.80 years to ~13 years (§5).
2. Tariff escalation vs. strictly flat real MEA utility tariff (2.00%/yr vs. 0.00%/yr): The §3.1 cash-flow table embeds a 2.00%/yr tariff escalator (raising annual benefit from 21,037.50 USD in Year 1 to 30,002.14 USD in Year 25, for 309,154.89 USD in discounted benefits). If the botanical garden operates under a fixed unindexed municipal tariff of 8.5 US¢/kWh (0.00%/yr escalation, where annual revenue declines by 0.50%/yr in lockstep with module degradation per §2 formula), discounted 25-year benefit falls to ~USD 254,500, reducing NPV by ~USD 54,600 (to ~USD 92,100) and extending discounted payback by ~1.1 years.
3. Micro-climate irradiation & tree/canopy shading (1,650 vs. 1,450 kWh/kWp/yr and uncompensated export spill): Siting in a Sub-Humid MEA zone or experiencing morning/afternoon shading from mature specimen trees and conservatory domes reduces specific yield from 1,650 to 1,450 kWh/kWp/yr (−12.1% energy), cutting discounted revenue by ~USD 37,500 and pushing discounted payback to ~10.0 years (§5). If mild winter weather also reduces greenhouse cooling demand so that 20% of midday output is exported at 0.0 US¢/kWh, NPV drops by an additional ~USD 55,000–62,000.

11. Call to Action

Request RFQ — 150 kWp Botanical Garden Solar (MEA)