Dispatch thousands of flexible assets without losing sight of grid constraints.
A DER orchestration platform for batteries, EV charging, solar, flexible load, and demand response across utility and commercial portfolios.
Scale and interface figures on this page are illustrative.
Optimization needs an explanation layer.
Operators need more than a dispatch number: they need availability, uncertainty, local constraints, reserve floors, and the objective that produced the plan.
Fragmented context
Not every enrolled DER is available, reachable, unconstrained, or economically sensible to dispatch at a given moment.
Decision logic
Operators need to understand why optimization chose a dispatch plan and what grid/program constraints shaped it.
Operational handoff
Performance settlement requires a baseline, actual telemetry, event window, exclusions and confidence—not only commanded kW.
A fleet is not one battery.
Device capability, program rules, customer opt-outs, telemetry health, and grid limits all shape usable flexibility.
Fleet
Enrollment, device capability, state of charge, connectivity and operating constraints.
Forecast
Load, solar, price, weather, customer opt-out and expected availability.
Dispatch
Objective, target, feeder/site constraints, setpoints, acknowledgements and fallback.
Events
Demand response/VPP event targeting, customer/program rules and real-time performance.
Settlement
Baseline, delivered response, exclusions, interval evidence and payout calculation.
Dispatch closes with settlement.
The operating loop runs from forecast to optimization to setpoint acknowledgement to interval-level performance.
Representative application states.
Representative application states from the product. Figures shown on screen are illustrative.
DER operations
Live portfolio
Peak event
17:00 to 19:00
Committed 86 MW against an 82 MW target
Every setpoint records the objective and constraints that produced it.
Event performance
EVT-2026-0919
79.4 MW delivered against 82 MW
By cohort, average MW
| Cohort | MW |
|---|---|
| Batteries | 39.6 |
| EV charging | 15.7 |
| HVAC | 20.6 |
| C&I curtailment | 3.5 |
| Total | 79.4 |
Method
- Baseline
- Weather-adjusted 10-of-10
- Intervals
- 24 × 5 min
- Excluded
- 1.8 MW
Site 441 telemetry gap excluded per rule; customer opt-outs removed before settlement.
DER site detail
Riverside Cold Storage
Riverside Cold Storage
State of charge today
Site limits
- Local export cap
- 900 kW
- Customer demand floor
- 410 kW
- Interconnection
- Feeder 12
Right now
- Site load
- 655 kW
- Battery
- Idle
- Grid import
- 655 kW
Scenario lab
Tomorrow 16:00 to 20:00
Tomorrow's evening peak
| Scenario | Peak | Flex needed | Flex available |
|---|---|---|---|
| Base | 486 MW | 82 MW | 151 MW |
| Heat wave +3°F | 519 MW | 121 MW | 148 MW |
| Cloudy afternoon | 486 MW | 98 MW | 151 MW |
Battery degradation cost is included in the objective. EV availability is sensitive to the commute return.
Failure states are part of the product model.
The cases below are intentionally modeled because real operating software is defined by what happens when data, people, or dependencies do not line up.
Telemetry drops during dispatch
Use declared fallback behavior, exclude uncertain intervals where required, and surface confidence degradation.
Customer opts out after commitment
Recalculate available portfolio headroom and redistribute within remaining constraints.
Grid constraint tightens
Re-optimize; do not continue prior site setpoints merely to preserve aggregate target.
The data model behind the interface.
The interface follows the domain relationships and rules below.