Transmission bottlenecks: 2026 risks of PGCIL dominance

Why the transmission debate has become urgent

India’s grid expansion is under strain at the same time that renewable capacity addition targets are rising. Multiple reports and industry representations point to the same operational problem: generation projects can be commissioned faster than the evacuation network needed to move power. This mismatch has started showing up as commissioning delays, curtailment risk, and compensation disputes.

A second, more structural issue sits underneath the project delays. The concentration of transmission project awards with Power Grid Corporation of India Ltd (PGCIL) is raising questions on whether the sector is building enough execution diversity for a national pipeline that is expected to expand rapidly.

TBCB was meant to widen competition

India introduced tariff-based competitive bidding (TBCB) for transmission in 2006 to improve efficiency and increase private participation. Over nearly two decades, the mechanism helped attract private investment and lower transmission costs. But the current pattern of awards has triggered fresh scrutiny of whether competitive outcomes still reflect a level playing field.

The concern is not about the need for a strong central utility. It is about whether a regime designed to balance public and private participation is drifting toward single-entity dependence in a period that demands faster delivery and higher throughput.

PGCIL’s funding advantage shapes bids

A key factor cited by industry watchers is PGCIL’s sovereign backing. The article notes that this translates into a cost of borrowing of about 7% to 7.5%, which is materially lower than what private developers can typically access. That cost advantage can flow through directly into bid tariffs.

At the same time, the article highlights how regulated-tariff (RTM) projects deliver stable cashflows and a stated 15.5% return on equity (ROE), which can support aggressive bidding under TBCB. Industry participants argue this combination can distort price discovery if competition is largely decided by structural funding advantages rather than execution capability and risk pricing.

A large pipeline, but rising single-point-of-failure risk

PGCIL currently has works worth INR 150,000 crore under execution and has indicated an outlay of INR 300,000 crore by 2032. Separate data points in the article also describe PGCIL’s large portfolio in the interstate segment, including 46 of 91 inter-state transmission system (ISTS) projects under construction valued at more than INR 127,000 crore, plus another INR 46,500 crore in regulated-tariff projects.

On paper, these numbers indicate scale and institutional capacity. In practice, the same concentration can become a vulnerability if schedules slip across multiple corridors at once. The policy question raised in the article is whether India can afford to be overly dependent on one entity, regardless of competence, when renewable integration timelines are unforgiving.

Execution delays are visible across renewable corridors

The article notes that several key transmission projects executed by PGCIL are running 18 to 30 months behind schedule. It cites an evacuation scheme designed for 8.1 GW of solar power from Rajasthan, where parts were scheduled for completion in 2022 but remain incomplete.

Similar delays are highlighted in Khavda, Gujarat and Anantapur, Andhra Pradesh, both areas linked to large-scale solar and wind capacity that is operational or close to commissioning. Developers argue that when transmission readiness lags, generation assets that are completed on time cannot sell power at contracted or expected volumes.

National line addition fell short in FY2025

Official data cited in the article shows that India added 8,830 circuit kilometres (ckm) of interstate transmission lines in FY2025 against a target of 15,253 ckm, a 42% shortfall. The gap equates to nearly 6,500 ckm of capacity that was planned but not commissioned.

PGCIL itself delivered less than half of its targeted 5,281 ckm for the year, according to the article. Separately, another data point in the text shows that only 1,998 ckm of new lines were added till August, 30% lower than the year-ago period, against a full-year target of 15,382 ckm.

Renewable bidding is slowing as connectivity risk rises

Transmission constraints are now overlapping with a slowdown in renewable energy (RE) awards. ICRA data cited in the article shows that only 5.8 GW of RE projects were awarded in the first eight months of FY2026. That compares with 47.3 GW in FY2024 and 40.6 GW in FY2025.

The article also notes that nearly 50 GW of projects remain stuck without signed power purchase agreements (PPAs). Another estimate in the text places the unsigned PPA backlog at 40 to 45 GW. ICRA’s Girishkumar Kadam links the decline in bids and PPA delays to concerns around available transmission connectivity.

Discom delays and cost inflation add to tariff stress

Developers bid through reverse auctions, where the lowest tariff wins. The article notes that aggressive bids can become unviable when discoms take months, and sometimes over a year, to sign PPAs. With time, project costs rise due to land prices, compensation payouts, and supply chain volatility.

Mercom data cited in the article indicates that the average cost of large-scale solar projects rose 3% quarter-on-quarter and 1% year-on-year in the first quarter of 2025. The article also points to a broader stress point: state discoms had debt of INR 740,000 crore as of March 2024, making them reluctant to lock in long-term fixed tariffs.

Compensation petitions are testing the regulatory framework

Developers have started seeking relief through regulators. The article cites petitions by ACME Solar, Ampin Energy, and Juniper Green before the Central Electricity Regulatory Commission, seeking compensation for generation loss and financial impact due to curtailment until the associated transmission systems become operational.

Industry sources cited in the text suggest total compensation claims being pursued or contemplated could run into “several hundred crores”. If such claims become frequent, they could affect balance sheet outcomes and future project costs.

What reforms are being discussed

The article outlines a case for market share caps to reduce concentration risk and keep private participation meaningful. A proposed benchmark mentioned in the text is a cap limiting any single entity’s share of ISTS projects to a maximum of 50% of the total pipeline.

It also argues for stronger execution monitoring. The Central Electricity Authority is cited as an institution that could play a bigger role in real-time tracking of milestones, with regular public reporting to improve accountability and enable earlier intervention.

The investment need is bigger than any single executor

Government plans referenced in the article call for INR 900,000 crore to INR 1,500,000 crore of investment in transmission infrastructure over the coming years to support renewable integration. The scale of that requirement underlines why policymakers are being pushed to think beyond tariff outcomes and focus on delivery resilience.

The text also flags on-ground constraints that can slow line construction, including multi-agency clearances, right-of-way issues, and land and environmental restrictions. One example cited is a legal ban on new overhead lines across more than 100,000 sq km in parts of Rajasthan and Gujarat to protect the Great Indian Bustard.

Key figures at a glance

Why the concentration question matters for investors

The core issue raised is execution risk at a system level. When transmission is delayed by 18 to 30 months, renewable assets can become stranded and revenue is deferred, even if plants are commissioned. That creates pressure on developer cashflows, complicates PPA signing, and increases the likelihood of disputes and claims.

At the transmission level, overly aggressive tariffs may look efficient in the short term but can weaken participation if private players consistently lose bids on funding advantage rather than operational competitiveness. The article’s argument is that caps and better monitoring are intended to preserve PGCIL’s strengths while reducing the sector’s single-point-of-failure exposure.

Conclusion

India’s renewable targets depend on a transmission build-out that can match the speed of generation commissioning. The article documents delays, missed line addition targets, stranded capacity, and rising regulatory petitions as evidence that current execution and market structure need adjustment. The policy discussion is now converging on two tools: limiting project concentration through market share caps and strengthening milestone monitoring through institutions like the Central Electricity Authority.