India’s smart metering programme is progressing at an accelerated pace, emerging as a cornerstone of the country’s distribution sector reforms. At a recent Power Line conference, Saurav Kumar Shah, Executive Director, Power Finance Corporation Limited, shared insights into the progress, policy framework, challenges and future roadmap of India’s smart metering initiative under the Revamped Distribution Sector Scheme (RDSS). Edited excerpts…
Update on RDSS
With a nationwide target of 250 million meters, RDSS is aimed at enabling loss reduction, improving billing efficiency and ushering in a data-driven power ecosystem. So far, 115 million meters have been awarded, and over 30 million have been installed. The daily installation rate has witnessed a substantial increase, from 25,000 meters per day in January 2023 to over 0.12 million and is expected to touch 0.15 million shortly.
This deployment is being carried out under the design, build, finance, operate, transfer model, supported by performance-linked contracts with advanced metering infrastructure service providers (AMISPs) for durations extending up to 10 years. Key commercial mechanisms, including the waterfall payment system and direct debit, have been embedded into the model. Further, under the total expenditure framework, both capital and operational responsibilities are allocated to the AMISP, ensuring full lifecycle accountability. However, discoms are expected to ramp up their internal technical and administrative capacities to take over the systems post-contract.
Smart meters are beginning to yield measurable operational gains. States such as Bihar and Assam have witnessed reductions in aggregate technical and commercial losses. These outcomes are driven by improved system visibility, accountability at the feeder and distribution transformer (DT) level, and a culture shift within discoms. The ability to monitor energy flow down to the DT level enables more precise reconciliation of units supplied, billed and paid, enabling better loss monitoring and control. Feeder-level metering is largely completed, and the focus is now shifting to DT metering. While feeder metering faces fewer logistical constraints, DT metering is more complex due to the larger volumes and geographical spread. Nonetheless, several states have achieved over 50 per cent penetration, and implementation is keeping pace with consumer metering.
On the consumer front, the introduction of prepaid meters has facilitated improved cash flows and is helping address legacy arrears. To smoothen the transition, the Ministry of Power (MoP) has issued advisories allowing the tapering of old dues through instalments to avoid bill shocks. Additionally, time-of-day (ToD) tariff implementation is gaining ground. While already adopted in several commercial and industrial segments, ToD pricing is expected to be extended to domestic consumers in the coming years. This will enable better peak load management and incentivise efficient energy usage.
That said, tariff design remains a key area for policy intervention. The MoP has underscored the importance of keeping tariff structures simple and transparent. The typical domestic consumer does not possess the time or the technical capacity to decipher complex multi-slab pricing models. Industry experience from telecom shows that overly complicated billing frameworks can alienate users. As such, reforms such as merging fixed and variable charges and simplifying unit-based pricing are being considered to enhance customer understanding and engagement.
Smart meters are redefining utility operations and customer engagement by enabling a real-time, data-driven infrastructure. This digital transformation supports advanced service offerings such as dynamic billing models, UPI-enabled prepaid transactions and mobile-accessible consumption analytics. For consumers, it enhances transparency and control; for utilities, it unlocks operational efficiencies through artificial intelligence (AI)- and machine learning (ML)-driven insights in areas like demand forecasting, predictive maintenance and loss reduction. Moreover, real-time outage detection and grid monitoring improve fault response and service reliability, positioning smart metering as a critical enabler of distribution sector modernisation.
With the proliferation of distributed energy resources, including rooftop solar, electric vehicles (EVs) and battery storage, smart metering is becoming central to dynamic load management. The episodic and often unpredictable load from EVs poses asset utilisation challenges. There is growing recognition that network investments must be backed by corresponding returns, necessitating solutions for backend optimisation and rotational charging. The government is also emphasising the integration of smart meters with energy management systems for planning, storage coordination and demand response.
Cybersecurity has emerged as a critical consideration. Cyber threats may lead to long-term reputational and operational risks with compromised digital infrastructure. Cyber audits need to be undertaken by AMISPs and at the discom level. Recent geopolitical developments underline the recognition that cybersecurity is no longer optional but a fundamental hygiene factor.
In terms of policy and funding, the RDSS remains performance-linked. Prepaid metering adoption has been positioned as a key performance indicator. While discoms are expected to adhere to contractual timelines and deliverables, the government has adopted a supportive stance, allowing delays where justified and offering extended windows for compliance rather than withholding funds. The objective remains to drive reform rather than penalise. With nearly 200 million meters sanctioned, the financial backing is in place across most states. Tamil Nadu, for instance, is in the process of finalising a new commercial round following challenges in its earlier tendering efforts, while states like Bihar and Madhya Pradesh have moved swiftly due to early pilot successes.
Challenges and the way forward
The RDSS addresses long-standing challenges associated with interoperability, vendor lock-in and ecosystem fragmentation. The commercial structure itself has driven greater alignment between vendors and AMISPs, and service level agreements are being monitored closely. Industry committees are working on standardisation across interfaces. Consumer engagement is being enhanced through digital outreach, social media feedback mechanisms and the standardisation of app-based interfaces. The MoP is currently developing hygiene and motivational templates for discoms and AMISPs to deliver a consistent digital experience.
As a next step, the MoP is working with stakeholders to build the India Energy Stack – a data-led platform to support peer-to-peer energy trading and analytics. Smart meter data, which constitutes one of the most voluminous data sources in the sector, will be key to network planning, load forecasting and outage management. Asset mapping and consumer indexing efforts under RDSS will further feed into this stack. The MoP is encouraging the cross-utilisation of data across planning tools and enhancing the policy framework for AI/ML-based data analytics.
Looking ahead, discussions are under way to extend RDSS timelines, especially for states requiring additional support to complete metering and infrastructure works. Given that distribution networks require an estimated investment of Rs 4.2 trillion over the next five to six years, the Indian government has reiterated its commitment to continue supporting state-level efforts while ensuring reform-linked accountability.
The success of India’s smart metering programme hinges not only on physical installation but also on stakeholder alignment, policy continuity and consumer trust. With smart meters now forming the foundational layer for a digital energy ecosystem, the focus must shift to ensuring that the data generated drives measurable improvements both in utility operations and in the consumer experience.
