Key Details
CEA’s October 2026 Unified Framework for Digitalization of Distribution Sector is a recommended planning framework, rather than a uniform technology mandate for every power distribution company (DISCOM).
Stage | Indicative Period | Main Priority |
|---|---|---|
Assess readiness and build foundations | 2026–29 | Check data and staff capability; improve network maps, metering, communications, monitoring and cybersecurity. |
Connect operations | 2029–32 | Link metering, grid-control, outage, billing and customer systems around a common view of the network. |
Expand intelligence and automation | 2032–35 | Scale advanced grid management, fault restoration, voltage management and tools for rooftop solar, storage and EV charging. |
Adopt advanced capabilities selectively | After 2035 | Consider digital models of networks and more autonomous functions only where operational and safety conditions support them. |
The periods are indicative: the report says DISCOMs should advance according to their needs and readiness, rather than follow identical rollouts.
Existing Digital Systems Need to Work Together
India’s distribution companies have acquired smart meters and other digital capabilities through programmes including the Revamped Distribution Sector Scheme (RDSS). Some also use digital network maps, real-time monitoring, outage-management and customer-service systems. CEA’s concern is that these systems often operate as separate “digital islands”: information collected for billing, for example, may not readily help a control room locate an outage or assess a network fault.
The gap matters more as electricity demand grows and rooftop solar, batteries and electric vehicles make local power flows harder to predict. The framework’s central proposal is therefore a sequence: establish visibility and reliable data, connect systems, enable greater control, and only then expand automation.
Readiness Assessment Comes Before Major Procurement
CEA recommends a DISCOM Digital Readiness Assessment before a utility undertakes major digital investment. It would examine consumer and meter records, the accuracy of network maps, real-time grid visibility, communications, cybersecurity, staff skills and the financial case—including recurring costs.
That assessment is intended to shape what a DISCOM buys and when. An advanced distribution management system (ADMS), for instance, needs an accurate picture of which lines, transformers and customers are connected. Without it, more sophisticated software may have little reliable information on which to act. The report also says digital tools complement, rather than replace, physical network strengthening where ageing assets or network constraints need direct repair or upgrading.
AI Is Proposed as an Aid to Operators, with Tighter Controls for Grid Decisions
The framework identifies potential uses for AI in forecasting demand, detecting losses, assessing equipment condition and managing outages. It proposes controlled, problem-led pilots with a baseline, success measures, a named operational owner and a decision to scale, refine or stop after evaluation.
For critical protection and switching functions, CEA says AI should initially support decisions rather than authorise them independently. More autonomous control would require tested safety boundaries, human override, fail-safe operation, audit trails and cybersecurity checks. The report also recommends a national distribution digitalisation test bed to check whether equipment and software from different suppliers work together safely before large-scale use.
What Is an Advanced Distribution Management System?
An advanced distribution management system (ADMS) brings network monitoring, outage information and grid-control tools together. It can help operators locate faults, plan switching and restore supply using a consistent picture of the distribution network.
Policy Relevance
The framework changes the emphasis from installing devices to using connected information. For DISCOMs, the immediate work is as much organisational as technical: assigning responsibility for data, training control-room and field staff, and writing procurement contracts that require systems to exchange information and remain maintainable over their working lives.
CEA’s staged approach also recognises that utilities start from different positions. A less-digitised DISCOM may gain more from accurate asset maps and dependable outage records than from an advanced AI pilot; a more mature utility may be ready to test automated functions. Across both, the relevant measures are losses, outage duration, billing accuracy and consumer service, alongside the cost and security of running the systems.
Follow the Full Report Here: CEA’s Unified Framework for Digitalization of Distribution Sector