Your Forecast Has a Range. Your Schedule Commits to a Number. That Gap Is the Penalty.
Your PPA commits you to a specific quantum in a specific window. Your solar and wind output answers to the weather. We help you schedule properly and reduce penalties.
Every Schedule Is a Bet on One Version of Tomorrow
Most IPPs build a generation schedule from a single forecast, the expected number. The schedule commits to one answer. Every gap between the commitment and what the grid actually settled is charged.
Fixed & Dispatchable Power is the hardest version. You are delivering a contracted amount of energy inside a nominated window, typically the evening peak. Getting through that window depends on decisions made all day, how much to charge during the afternoon solar surplus, how much to hold in reserve, what to do when wind underdelivers.
Those decisions interact across all three assets at once.
FDRE tenders are issued by SECI and state DISCOMs, and non-delivery triggers DSM charges under CERC’s deviation settlement framework. The rules are tightening: KERC’s 2026 regulations make Scheduled Generation the denominator for deviation charges instead of Available Capacity, which ties the penalty directly to the quality of your own forecast rather than to your capacity.
SECI’s FDRE-IX, bid opened 23 July 2026, contracts 1,200 MW for four hours daily and permits storage to earn on the exchanges outside the nominated window. Meeting the PPA takes precedence, and selling externally before the obligation is met carries severe penalty. That dual obligation, firm delivery first and arbitrage second, is the scheduling problem this platform was built for.
Schedules That Hold Up Across Every Likely Day
Quadrical’s Dispatch Management does not build a schedule around one forecast. It models the range of likely outcomes for each uncertain input, solar yield, wind yield and market price, at worst, base and best case, and finds the schedule that performs well across all of them rather than the one that performs best if everything lands as expected.
Every scenario is tested against hard system limits: battery C-Rate, SoC operating boundaries, round-trip efficiency and transmission losses. A schedule that is financially optimal but physically undeliverable is not offered.
The schedule runs day-ahead before the market opens, then reruns every 30 minutes intraday, incorporating updated weather, revised yield forecasts and actual battery state. Inside the locked commitment window, where positions are fixed, the platform still models whether accepting a DAM (Day-Ahead Market) penalty to capture an RTM (Real-Time Market) spike is worth it. Your team makes that call.
Forecasts are an input, not a product. Yield forecasts come from your third-party provider or by upload. Quadrical optimises what it is given, and connects to your QCA’s submission layer rather than replacing it.
Penalties are asymmetric. Over-committing to a position you cannot cover costs more than under-committing and missing some upside. The platform accounts for that asymmetry. A single-forecast schedule does not.
Specifications
- Plant yield forecasts [solar, wind, DG] from third-party providers or upload
- RealTime asset performance baselines from the Digital Twin layer
- Market price forecasts [DAM, RTM]
- PPA commitment schedules
- Battery state
- Load schedules from buyers
Worst, base and best case modelled for each uncertain input. Two-part optimisation: maximise mean revenue, protect worst-case revenue. Risk score 0–100 with default profiles and manual override.
Every scenario tested against C-Rate limits, SoC operating boundaries, round-trip efficiency and transmission losses. Every recommended schedule is physically deliverable.
- PPA allocation per 15-minute slot
- DAM bid volume
- RTM position
- Battery charge and discharge schedule optimised jointly against solar and wind in every window
- Best price indication, PPA vs IEX/RTM, shown automatically when surplus exists
- Hybrid dispatch across Solar, Wind and Storage simultaneously
Day-ahead schedule before market opens. Intraday rerun every 30 minutes, 48 per day. Locked-window penalty vs upside tradeoff modelled automatically.
DSM exposure tracked instantaneously, day-wise and month-wise. Revenue vs committed schedule in RealTime. Compliance reports generated automatically.
Solar PPC, Wind PPC, BESS BMS, EMS, SCADA, Grid SVG/STATCOM and Power Exchange Platform. Demand and capacity mapping. Load scheduling interface for all generation clients.
Connects to Quadrical’s demand scheduling layer, so buyer-side load schedules and PPA obligations sit in the same calculation as generation forecasts.
Built for IPPs With Hybrid Portfolios and Market Access
Dispatch Management is built for IPPs where solar, wind and storage decisions have to be made together, and where power can be allocated across long-term Power Purchase Agreements (PPAs), the Day-Ahead Market (DAM) and the Real-Time Market (RTM).
Firm delivery commitments during contracted windows. Miss the window and the DSM charge is immediate.
Long-term commercial PPAs with surplus trading on IEX, DAM or RTM. Revenue depends on matching supply to commitment and timing exchange positions.
Battery value depends on charge and discharge timing, scheduled within actual C-Rate and SoC operating limits against forecasts and live market prices.
DSM charges compound when schedules and actuals diverge. Exposure drops even without a battery, by hedging against forecast error rather than committing to a single expected outcome.
If you are locked into a 25-year PPA with no DAM or RTM access and no battery, dispatch optimization will not add meaningful value. Better forecasting and Digital Twin-based performance monitoring — both available on the core Quadrical platform — will serve you better.
Coordinated Wind and Storage Dispatch.
Wind under-delivery, BESS response, Real-Time Market allocation, and firm power tracking are managed as a single optimization problem. The Dispatch Schedule Optimizer runs 27 probability-weighted scenarios every 15 minutes and schedules the highest expected net-revenue strategy across the full hybrid portfolio.
A new strategy evaluated and committed every 15 minutes as wind conditions, battery SoC, and market prices update.
Wind yield variance stress-tested across three probability levels per cycle before any strategy is committed.
When wind under-delivers, BESS discharge timing adjusts automatically to cover the gap.
Wind surplus directed to highest-value market windows automatically.
Deviation from committed dispatch monitored in real time. Warnings issued before penalty thresholds are crossed.
Hard and deviation-based penalty structures modeled per market rules before strategy selection.