Improved Grid Visibility
Real-time awareness of DER behavior across the territory supports better planning, forecasting, and operations. Blind spots shrink as more devices report into a common view.
For Utilities
See and coordinate distributed energy resources without building custom integrations
01 Challenge & Solution
Challenge
Utilities are gaining load they can’t see or control
Utilities face rapid growth in distributed energy resources—EV chargers, batteries, solar, and flexible loads—connecting to the grid faster than visibility and control systems can keep up. Each device type, vendor, and aggregator introduces a different protocol, data format, and integration requirement. Most utilities have fragmented visibility into DERs and limited ability to coordinate them for grid benefit.
Solution
A unified view and control surface across distributed assets
This unlocks consistent visibility and coordination across the heterogeneous DER landscape. Utilities can aggregate telemetry from diverse devices, issue control signals through a common interface, and incorporate DERs into grid operations without building point-to-point integrations for every vendor. Distributed resources become grid assets that can be monitored, managed, and dispatched.
02 Competencies
Competencies
Aggregated visibility across device types and vendors
Telemetry from chargers, batteries, inverters, and flexible loads can be normalized into a consistent data model regardless of source. Real-time and historical data flows into utility systems without per-vendor transformation. Grid operators see DERs the same way they see traditional assets.
This commonly includes integration with utility control centers, energy management systems, CIS platforms, and program management tools, alongside support for industry standards like IEEE 2030.5, OpenADR, and SunSpec.
Coordinated control for grid services
Dispatch signals, curtailment commands, and demand response instructions can be issued to DERs through a unified control interface. Devices respond consistently regardless of manufacturer or protocol. Utilities can call on distributed capacity for load management, frequency response, or emergency curtailment.
Program enrollment and settlement support
DERs can be enrolled in utility programs, tracked for performance, and metered for settlement. Participation data flows back to billing and program management systems. Incentive programs become operationally tractable, not manually intensive.
From Design to Operation
- 1Utilities connect to DER aggregation points and normalize data across device types.
- 2Control policies and program rules are configured to align with grid operations needs.
- 3DERs participate in grid services with consistent visibility, control, and measurement.
03 Impact
IMPACT
Measurable gains across delivery, margin, and scale
Defer Investment
Coordinating existing DERs can reduce peak demand and defer costly transmission and distribution upgrades. Distributed capacity becomes a resource, not just a load.
Faster Program Deployment
New demand response, managed charging, or flexibility programs can launch without building custom integrations for every device class. Program time-to-value compresses significantly.
One integration layer instead of dozens of vendor interfaces
Instead of negotiating data access, building custom APIs, and maintaining integrations with every DER vendor, aggregator, and device manufacturer, utilities connect through a unified layer that handles protocol translation and data normalization. This replaces the fragmentation of one-off integrations with a scalable approach that grows with DER adoption.
As more devices connect to the grid, the integration burden stays manageable. Teams spend less time on vendor management and more time on grid operations, program design, and customer engagement.
