CYPRUS SOLAR + BESS · HYBRID DISPATCH SIMULATOR v2
06:00
Data source: Bundled climatological model · Click "Load PVGIS Data" to fetch real satellite-derived data for your site.
Solar Gen
0MW
Wind In
0MW
Wind Captured
0MWh today
To Grid
0MW
BESS Flow
0MW
SoC
0MWh
Curtailed
0MWh
SPEED40×DATE
24-Hour Energy Profile
Solar (MW)Grid Export (MW)Wind In (MW)SoC with wind (MWh)SoC without windCurtailed (MW)BESS Sizing Limit
PV Array
Parameter
Value
Unit
DC Capacity (peak)
MW
Inverter AC Limit
MW
System Loss
%
(Nicosia default)
BESS (Battery Storage)
Parameter
Value
Unit
Nameplate Capacity
MWh
Power Rating (max charge/discharge)
MW
Charge Efficiency (η_c)
%
Discharge Efficiency (η_d)
%
Min SoC
%
Max SoC
%
200 MWh
Drag to test smaller/larger BESS sizes — see curtailment & revenue impact below.
Wind Source A — Storage Fee Mode
Parameter
Value
Unit
Available Capacity
MW
Capacity Factor (avg)
%
Storage Fee (we earn)
€/MWh
Active Hours
h
Wind operator owns the energy, pays storage fee. We rent BESS capacity. Lower margin, simpler contract, no supplier license needed.
Wind Source B — Purchase Mode (Arbitrage)
Parameter
Value
Unit
Available Capacity
MW
Capacity Factor (avg)
%
Purchase Price (we pay)
€/MWh
Active Hours
h
We buy distressed wind cheap, store, resell at peak rates. Higher margin, requires supplier license. Spread vs peak tariff = arbitrage profit.
Grid Services (Priority 3)
Parameter
Value
Unit
Service Tariff
€/MWh
Reserved Capacity
%
Activation Probability
%/h
FCR/FFR-style: random ±MW grid calls compensated at the tariff rate.
Time-of-Day Grid Pricing (€/MWh)
Period
Hours
Rate
PEAK
SHOULDER
OFF-PEAK
all other hours
Hours format: "07-09,18-22" means 07:00-09:00 and 18:00-22:00. Cyprus typical: morning + evening A/C peaks.
BESS Costs
Stream
€/MWh
BESS Round-trip Cost (degradation)
Daily Revenue (€)
P1Solar → Grid (PPA)€0
P2aWind A — Storage Fees€0
P2bWind B — Resale€0
− Wind B Purchase Cost€0
P3Grid Services€0
− BESS Degradation€0
− Curtailment Loss (opp.)€0
NET DAILY€0
Annualized (×365)€0
BESS Sizing Sweep
For the selected day, this shows daily NET revenue across BESS sizes from 50 to 400 MWh. Look for the elbow — beyond it, more battery costs more than it earns.
CurrentElbow (sweet spot)Max revenue
Run simulation to populate.
Daily Energy Balance
Solar generated
0 MWh
Solar to grid (direct)
0 MWh
Solar to BESS
0 MWh
Wind A → BESS (storage)
0 MWh
Wind B → BESS (purchased)
0 MWh
BESS to grid
0 MWh
Grid services delivered
0 MWh
Curtailed (lost)
0 MWh
Total to grid
0 MWh
Avg sell price (weighted)
€0/MWh
About the model & data sources
Solar profile: Bundled data is a climatological model derived from PVGIS-SARAH3 averages for Nicosia (35.1°N, 33.4°E), tuned to the corrected figures (Mar/Jun/Sep daily totals ~641/785/657 MWh; Dec ~360 MWh; Dec peak ~62 MW). Click "Load PVGIS" to fetch real satellite-derived data via a CORS proxy for any coordinates.
Dispatch logic (priority cascade):P1 Always deliver up to 50 MW to grid from solar; surplus charges BESS. If solar exceeds inverter+BESS capacity, the rest is curtailed.
P2 When BESS has headroom and our solar isn't filling it (typically evening/night), accept wind energy — we earn the storage fee, and the energy goes out to grid via P1 logic the next day.
P3 A reserved fraction of BESS capacity is kept available for grid services (FCR-style ±MW calls), compensated at the service tariff.
BESS Sizing Sweep: The right-hand chart re-runs the dispatch with BESS sizes from 50–400 MWh, plotting net daily revenue. The elbow shows diminishing returns. To make a bankability decision, compare the marginal € gain per extra MWh against the marginal capex (~€250–350k/MWh installed for utility-scale Li-ion, 2025–26 prices).
Caveats: Single-day analysis. Real bankability needs 8760-hour annual simulation × 20-25 year horizon, with degradation curves, weather variability, and PPA structure. This tool is for scoping & sensitivity.