- 60% of power plants unavailable
- Report exposes Discos culpability
The state of electricity supply in the country has become a source of concern for residents. After enjoying a relative supply for some parts of last year, especially in the second quarter, drawing applause from consumers, the euphoria that greeted this has gradually becoming worrisome.
These concerns were more pronounced during the last yuletide, when several homes were left in the dark. The situation, electricity Distribution Companies (DisCos) often explain, results from national grid collapses, low power generation, gas supply shortages, or maintenance work by the Transmission Company of Nigeria (TCN). These issues, alongside infrastructure decay and vandalism, invariably leads to load shedding and intermittent supply.
Top officials of some Discos spoken to who pleaded for anonymity attributed power failures to a mix of upstream generation deficits, national grid instability and localised infrastructure challenges.
For a long time, there has been several horse-trading associated across the value chain over erratic power supply. For instance, it is common for DisCos often cite “system-wide disturbances” or “grid collapses” from the National Control Centre (NCC) as the reason for total outages across their franchise areas. Besides, many outages are blamed on “gas limitations” at thermal power plants and a general drop in power generation. This is because when generation drops, the energy allocated to DisCos decreases, forcing them to implement load shedding.
In situations like this, most hide under the guise of the feeder banding system. Under this framework, priority is given to “Band A” feeders, which are mandated to receive 20+ hours of supply thereby often leaving lower bands with significant outages when total available power is low.
Yet, is the technical faults and maintenance of equipment, equipment vandalism like destruction of transformers and theft of cables; planned maintenance, like upgrading or repairing transmission lines, are also factor readily given as excuses by service providers.
After enjoying relative stability in national grid in 2025, the facility experienced a first major collapse at the weekend caused by the simultaneous tripping of multiple 330kV transmission lines.
With this incident coming early in the year, stakeholders are worried that it may not be a good omen for the sector notwithstanding the several assurances by government. In 2024, 12 grid collapses were recorded; 12 in 2025 and one already recorded this year.
More worrisome is that the epileptic power supply has remained irrespective of the fiscal appropriation to the sector under the President Bola Tinubu administration.
A cursory look at these allocation indicate that in the last three years, there has been a consistent increase in fiscal allocation to the Ministry of Power aimed at resolving the underlying issues that have consistently impeded growth in the sector, including the consistent grid collapses each year.
A breakdown of the figures in the three years showed that the power ministry got a cumulative allocation of N239.5 billion in 2023; N344.097 billion in 2024; N2.1 trillion in the 2025 budget. The allocation in 2025 represented the government’s desire to make the sector work.
A further breakdown of the figures show that the power sector recovery programme received N810 billion from the budget; special intervention project got N269.74 billion, while the presidential power initiative (PPI) transmission project received N150 billion, all in an attempt to tackle the enormous challenges in the nation’s power sector from specific and targeted approach.
The Minister of Power, Adebayo Adelabu, assured that the ministry has set the agenda for Nigeria’s power sector in 2026, suggesting that the country has done enough to stabilise its grid in the previous year.
But these challenges appear unresolved despite huge budgetary allocations to the power sector. Giving more insight into what may be the cause of the deep-seated challenges confronting the country’s electricity supply is a recent report by the Nigerian Electricity Regulatory Commission (NERC) for the third quarter of 2025. The report, released recently, indicated that over 60 per cent of power plants installed generation capacity in the country remained unavailable for transmission to the national grid in the third quarter of 2025.
According to the NERC report, the average Plant Availability Factor (PAF) of all 28 grid-connected power plants stood at 39.86 per cent, meaning that 60.14 per cent of installed capacity could not be dispatched to the national grid at any point during the quarter. The figure represents only a 0.26 percentage-point increase from the 39.60 per cent recorded in Q2 2025, highlighting how limited progress has been in improving the operational readiness of generation assets.
“In 2025/Q3, the average plant availability factor for all grid-connected plants was 39.86 per cent, that is, at any point in time during the quarter, 60.14 per cent of the installed capacity across the 28 grid-connected power plants was not available for dispatch onto the grid,” the report read.
The PAF measures the ratio of a power plant’s declared available capacity to its manufacturer-rated installed capacity and is widely regarded by regulators as a key indicator of the health of the upstream segment of the Nigerian Electricity Supply Industry (NESI).
It further noted that while 11 power plants recorded availability above 50 per cent, Ikeja Power Plant (Unit 1) emerged as the best-performing asset, posting a PAF of 99.24 per cent during the quarter. At the lower end, Sapele Steam Plant (Unit 1) recorded a PAF of just 2.66 per cent, while Alaoji Power Plant (Unit 1) failed to dispatch any electricity at all throughout the quarter.
Significantly quarter-on-quarter improvements were recorded at Dadin-Kowa (+41.32pp), Zungeru (+33.29pp) and Okpai (+15.95pp), reflecting gains from improved hydrology and reduced outages.
However, availability declined sharply at Ihovbor (Unit 2), which fell by 19.21 percentage points to 78.16 per cent, down from 97.38 per cent in Q2. Other plants that recorded notable drops included Geregu (Unit 1), Ibom Power, and Geregu (Unit 2).
“Overall, 11 power plants had availability factors above 50 per cent, with Ikeja_1 power plant recording the highest availability factor at 99.24 per cent. On the other end of the spectrum, Sapele Steam_1 recorded a PAF of 2.66 per cent in 2025/Q3. Alaoji_1 power plant was not available to dispatch any energy onto the grid throughout the quarter.
“Significant increases in PAF were recorded in Dadin-Kowa_1 (+41.32pp), Zungeru_1 (+33.29pp), and Okpai_1 (+15.95pp) power plants across the two quarters. Conversely, the PAF of Ihovbor_2 decreased significantly by 19.21pp during the quarter (78.16 per cent in 2025/Q3 compared to 97.38 per cent in 2025/Q2). Reductions in PAF were also recorded in Geregu_1 (- 12.79pp), Ibom power_1 (-10.34pp), and Geregu_2 (-8.41pp) power plants,” the NERC report said.
The commission attributed the fluctuations in plant availability to mechanical outages, feedstock constraints, hydrological conditions and operational limitations, factors that have continued to undermine Nigeria’s generation capacity for over a decade.
Beyond generation challenges, the report also highlighted weak energy offtake by electricity Discos, raising concerns over revenue recovery and market discipline. Under the Partial Activation of Contract regime, which came into force in July 2022, DisCos are required to off-take and pay for their Partially Contracted Capacity on a take-or-pay basis, even if they fail to utilise the power.
In Q3 2025, average energy offtake by DisCos fell to 3,328.33 megawatt-hours per hour, representing a 7.10 per cent decline from 3,582.62MWh/h recorded in the preceding quarter.
This decline occurred despite the fact that available contracted capacity dropped by only 2.43 per cent, suggesting that generation and transmission availability were sufficient to sustain previous offtake levels.
Overall, cumulative DisCo energy offtake performance during the quarter stood at 87.39 per cent, down from 91.78 per cent in Q2, a 4.39 percentage-point decline.
“All DisCos except Jos recorded a decline in their energy offtake performance during the quarter,” the report noted.
The commission attributed the reduced offtake to a combination of infrastructure weaknesses, seasonal demand changes and commercial considerations.
It noted that frequent network outages during the rainy season, driven by fragile distribution infrastructure, limited the ability of DisCos to evacuate power to customers.
In addition, cooler weather conditions reduced domestic electricity demand, while some DisCos deliberately constrained supply to loss-prone feeders to minimise financial exposure.
Under the Performance Monitoring Framework Orders issued in July 2024, DisCos are required to off-take at least 95 per cent of their available PCC or face regulatory sanctions.
However, in Q3 2025, only Benin and Port Harcourt DisCos met the threshold, with offtake levels of 99.20 per cent and 95.65 per cent, respectively.
The remaining nine DisCos, Abuja, Eko, Enugu, Ibadan, Ikeja, Jos, Kaduna, Kano and Yola, fell short, with Kaduna DisCo recording the lowest performance at 75.23 per cent.
“The Commission has commenced the implementation of appropriate sanctions against defaulting DisCos,” the report stated.
The figures reflect the persistent mismatch between installed capacity, available generation, and effective electricity delivery, a challenge that continues to frustrate households and businesses.
Despite Nigeria’s installed generation capacity exceeding 13,000 megawatts, average operational availability and weak offtake mean that actual electricity delivered to consumers remains far below demand, reinforcing dependence on self-generation and driving up energy costs.
