Digitalisation of discoms is increasingly being positioned as a key imperative of distribution reform. Digitalised systems allow discoms to move from reactive maintenance to data-led planning and predictive operations. Parallelly, digitalisation can directly affect discom finances. For instance, advancing smart prepaid metering can improve billing and collection efficiency, which can improve energy accounting and also address other instances of revenue leakage. As India progresses towards a more decentralised and renewable-rich power system, the digital transformation of discoms is emerging as a foundational requirement for sustainable operations, improved service delivery and long-term financial viability.
On the policy and reforms front, the Revamped Distribution Sector Scheme (RDSS) is the principal policy framework currently driving digitalisation across discoms. The RDSS links central financial support to outcomes such as prepaid and system smart metering, distribution infrastructure modernisation, and digital systems integration, with targets for loss reduction and quality of supply.
In parallel, the Ministry of Power (MoP)has initiated work on the India Energy Stack, envisaged as a digital public infrastructure for the power sector to enable interoperable and consent-based data exchange and common digital building blocks for utility operations and consumer services, with pilot demonstrations planned for 2026-27. In late 2025, the MoP also issued policy advisories encouraging the integration of artificial intelligence (AI) and machine learning (ML) applications in distribution operations to strengthen predictive maintenance, analytics and decision support. In addition, it suggested the adoption of smart meter data analytics, integrated information technology and operational technology systems, demand forecasting, revenue protection, and cost optimisation, while also pointing to emerging applications such as blockchain, internet of things (IoT) and smart home automation, to strengthen operational efficiency, grid reliability and consumer service delivery.
Smart metering
Advanced metering infrastructure (AMI) is emerging as the foundational layer for data-led distribution operations. Smart meters provide near-real-time, granular consumption information across consumer categories and geographies, enabling discoms to strengthen energy accounting and identify patterns linked to technical and commercial losses. This improves billing accuracy and revenue assurance while creating an analytical backbone for forecasting and planning.
As of January 15, 2025, more than 51.35 million smart consumer meters have been installed across the country, along with 1.31 million distribution transformer meters and about 0.16 million feeder meters, according to data compiled under the National Smart Grid Mission. Over time, continuous demand visibility can also support more accurate load forecasts and reduce reliance on high-cost power purchases driven by uncertainty in demand estimation. Moreover, smart metering supports operational responsiveness. When meter communication drops in a cluster, it can act as a signal for outage detection and complement feeder-level monitoring.
AI and ML
AI and ML are increasingly being positioned as the analytics layer that converts the growing stream of operational data from AMI, meter data management systems, supervisory control and data acquisition (SCADA) and other distribution platforms into actionable decisions for loss reduction, reliability improvement and consumer service delivery.
Outage management
Outage management systems (OMSs) allow for real-time outage tracking, fault identification and restoration monitoring through dashboards and workflow tools, improving situational awareness. When an OMS is integrated with a geographic information system (GIS) and SCADA, it strengthens fault localisation and improves outage response by shifting it from manual escalation to system-driven despatch. This is also being reinforced through feeder monitoring solutions, which issue alerts in case of feeder tripping or abnormalities.
Control centres
Another important innovation in this transition is the centralised monitoring and control centre (CMCC), which is designed to integrate GIS, SCADA and AMI into a unified operational view. By consolidating information from field assets and consumer endpoints, CMCCs support decision-making on load management, fault response and network planning. In practical terms, this enables utilities to monitor feeder and distribution transformer performance more systematically and track operational key performance indicators.
Asset management
Enterprise asset management platforms are increasingly being used to digitalise the life cycle management of transformers, switchgear, poles, conductors and cables. Asset management systems can support predictive analytics that flag equipment prone to fail, and enable condition-based maintenance rather than time-based maintenance through IoT sensors. This is an important shift for discoms, because it reduces unplanned outages, improves asset utilisation and strengthens maintenance planning through a centralised record of maintenance and repair activities.
Cables, conductors and towers
Distribution network digitalisation needs to extend beyond substations and meters to the line assets that drive day-to-day reliability outcomes. Digitalised asset registers and GIS mapping of underground cables, poles/towers and overhead conductors can give utilities a structured view of circuit-level bottlenecks, ageing spans and recurrent fault locations. Once this network model is linked to outage history, feeder performance and field inspection records within enterprise asset management platforms, discoms can shift from complaint-led replacements to risk-based prioritisation of the cable sections and conductor stretches that are most prone to failures. Over time, combining periodic thermography or drone-based inspections with condition and load data can help utilities detect hotspots, loose joints, sagging conductors and encroachment risks earlier, improving preventive maintenance planning, reducing restoration time and limiting repeat outages in high-loss or high-demand pockets.
Consumer interface
Several utilities have begun improving customer service delivery by deploying consumer relationship management platforms, self-service portals and chatbot-based interfaces to manage service applications, bill payments and complaint resolution. For starters, these tools reduce physical footfall, standardise service workflows and improve response times, while also lowering the administrative load on utility staff. There are also other features, such as interactive portals and advanced analytics-based consumer segmentation, that improve engagement and reduce repeat complaints. For instance, BSES Yamuna Power Limited has rolled out a WhatsApp-based consumer interface that allows registered consumers to receive and duplicate bills, register power outages and street light complaints, submit self-taken meter readings, track complaints, check payment and bill status as well as consumption, and track the status of new connections, through the utility’s WhatsApp number.
Challenges and the way forward
Despite the strong momentum around discom digitalisation, there are still implementation hurdles on the ground. A recurring challenge is the integration of new digital platforms with legacy systems and fragmented utility workflows. Many discoms continue to operate with distinct applications for metering, billing, outage response and asset management.
Capacity building is another key constraint. Digitalisation requires utilities to develop an in-house ability to interpret operational data, use analytics outputs in decision-making, and manage digital workflows at the field level. There is also a growing need for cybersecurity readiness, as discom operations become more connected and data-intensive, increasing exposure to system vulnerabilities if governance and security controls are not strengthened. Additionally, as discom operations become more digital and connected, cybersecurity is becoming a core operational requirement rather than just an information technology concern. For discoms, the practical implication is that cyber controls must be embedded into the design of AMI, MDS, SCADA and other integrated information technology and operational technology systems, including access management, incident response readiness and periodic assurance processes, rather than being treated as post-deployment add-ons.
Moreover, the transition to intelligent distribution networks will depend on foundational enablers that extend beyond technology procurement. Interoperability across systems, secure data-sharing protocols and consistent data governance will be essential to ensure that multiple digital platforms function as a coherent operational stack. In effect, digitalisation will soon become the operational foundation on which the next stage of distribution reform will be built.
