Forecast demand. Schedule dispatch. Cut standby power buying.
eZap interprets distribution grid demand and tells your dispatch desk how much generation to schedule, 24 to 72 hours ahead. Avoid reserves that add cost to every bill.
Distribution operators buy reserves they may not use
Three structural gaps push reserve procurement costs above necessary levels.
Forecast accuracy gaps
Persistence models miss rapid demand ramps. When summer mornings warm faster than historical patterns, yesterday's load profile is already wrong by 08:00.
Reserve overbuying
Worst-case reserve buying pays for generation that never runs. Distribution operators routinely procure 15-to-25 percent more standby capacity than actual peak demand requires.
Manual schedule delays
Once a planner checks last-hour actuals, recalculates reserve needs, and confirms dispatch, the short-notice window has passed. The correction cost is already fixed.
Accurate forecasts. Ready schedules.
Four capabilities for distribution operators handling real-time reserve procurement.
Feeder-level demand forecasts
Each feeder receives a 24 to 72-hour probability distribution, refreshed every 15 minutes as metering data arrives. P10/P50/P90 bands cover every interval.
Automated dispatch planning
For each 30-minute block, your dispatch desk receives a generation schedule ordered by unit cost across the forecast horizon. No spreadsheets. Minutes instead of hours.
SCADA and EMS connections
Connect existing metering through REST and MQTT. No new hardware is needed. Data contracts align with IEC 61968 and common EMS platforms.
Reserve procurement alerts
Threshold alerts identify commitments above the P90 forecast band. Your team sees the issue early enough to adjust before short-notice cost penalties apply.
Metering data to dispatch schedule in three steps
eZap collects grid data, runs the forecast model, and returns a structured schedule your operations team can use immediately.
90-day closed beta results
Standby reserve procurement cost reduction across 8 instrumented feeders
72-hour forecast horizon with 15-minute resolution, updated continuously
Feeders instrumented across 2 distribution networks in northern Portugal
Internal beta data from 2 distribution networks over a 90-day pilot. Results vary with grid configuration and baseline procurement practices.
What operators are saying
The 72-hour schedule changed how our dispatch team plans the week. We previously carried 20 percent overhead on every reserve commitment because uncertainty was too broad. With eZap's probabilistic bands, we can size procurement correctly while covering the P90 scenario.
Before eZap, our planning team spent much of each morning matching the previous night's actuals against the next-day schedule. That comparison now runs automatically, and the alert reaches the inbox before the short-notice procurement window opens. It saves us real money each week.
See what accurate load forecasts mean for your grid
Talk with the eZap team about your feeder network. We will show forecast output against your own data before you commit.