By Dr. Lanre Babalola

The first two papers in this series established the diagnosis. The seasonal demand-supply scissor explains why Nigeria’s electricity crisis reaches its annual nadir between February and April. The Shiroro story explains why the crisis is consistently worse than the meteorology and hydrology alone would predict, and why the system’s own design – which contained a partial solution – has been quietly undone by operational drift. This paper turns to remedy. It begins with what will not work – specifically, the dominant policy prescription that the first two papers have already shown to be orthogonal to the seasonal crisis. It then sets out what can be done: The operational measures that require no new infrastructure, the medium-term structural changes that would address the seasonal supply gap at its root, and the institutional reframing without which no intervention can be designed or sustained with the precision the crisis demands.

First, what will not fix this
BEFORE turning to remedy, it is worth being precise about what will not work – not because the argument is unfamiliar, but because the dominant policy prescription continues to be applied with a universality that the evidence does not support.

The central claim of Nigeria’s electricity policy discourse is that tariffs are not cost-reflective and that cost recovery is the key to sector recovery. Distribution companies cannot pay generators. Generators cannot pay gas suppliers. Gas suppliers cannot invest in supply reliability. The circular debt compounds. And at the root of it all, the argument runs, is an electricity price too low to sustain a viable sector. Raise tariffs, allow full cost recovery, and the sector can begin to heal.

There is something to this argument in its own domain. The commercial dysfunction of the sector is real and consequential. The cascading payment failures that run from distribution through generation to gas supply are a genuine impediment to investment and maintenance. The conversation about sustainable cost recovery, cross-subsidisation, and tariff design that is simultaneously fair to consumers and financially viable for operators is a legitimate and necessary one.

It is worth noting, however, that even within that legitimate conversation, the analytical starting point matters enormously. The first-best basis for tariff setting is the efficient cost of electricity production and supply – what it costs to produce and deliver electricity when the sector is operating with productive, allocative, and distributional efficiency. Tariffs derived from that foundation provide a reference point for reform and a discipline on operator behaviour.

Tariffs derived instead from the required revenue of incumbent operators – which is the practical basis of most cost-of-service regulation in Nigeria – risk entrenching existing inefficiencies rather than correcting them. Revenue maximisation by operators is not a first-best policy objective; embedding it in the tariff structure is not reform. This distinction deserves a fuller treatment of its own. For this paper, it is sufficient to note that the tariff conversation, even at its most rigorous, does not reach the seasonal crisis.

But legitimate in its own domain is not the same as applicable everywhere. Consider the specific causal chain of the seasonal crisis: Cooling demand rises in February because temperatures rise; hydro output falls because reservoirs are depleted; the grid has no reserve to absorb the combined shock; unplanned outages result. At no point in that causal chain does the tariff level appear as a variable. A higher tariff does not reduce cooling demand in a country where most consumers have no realistic alternative to electricity for cooling. It does not raise reservoir levels. It does not repair vandalised gas pipelines. It does not restore spinning reserve to a grid that has none. It does not change the dispatch decisions that deplete reservoirs before the stress peak arrives.

The tariff argument is not wrong in all contexts. It is wrong as a diagnosis of seasonal stress, and it is wrong as a proposed remedy for it. Applying it as though it were a universal solution – as current policy discourse routinely does – ensures that the seasonal crisis is never addressed with the precision it requires.

The point is not that tariff reform should be abandoned. It is that it should be confined to the problems it can actually solve, and not allowed to displace the operational and planning interventions that the seasonal crisis specifically demands. Conflating the two – treating a pricing instrument as a remedy for an operational and hydrological problem – is a form of analytical malpractice whose consequences are measured in annual blackouts and the economic losses they produce.

What can begin immediately: The operational fixes
The most significant insight that emerges from the analysis in this series is that a meaningful portion of the seasonal crisis is the consequence of the inversion of design intent – the systematic subversion of the dispatch logic for which key assets were originally engineered – and is, therefore, remediable through operational change, without waiting for new investment or infrastructure. The following measures fall into this category, and none of them requires new legislation, new financing, or new physical assets.

Before setting out those measures, one point of principle deserves emphasis. Nigeria’s generation companies were privatised under the PHCN unbundling, and their operational autonomy must be respected. The measures proposed here do not require or imply direct intervention in the internal operational decisions of privately-owned generators.

They operate within the established instruments of power system governance: The system operator’s authority over generation scheduling and dispatch, and NERC’s regulatory mandate over system adequacy and operational standards. The distinction between dispatch instructions issued by the system operator – which generators are contractually bound to follow – and interference with private operator autonomy is well-established in electricity regulation. It is within that framework that the following measures are proposed.

Reservoir management reform at Shiroro, Kainji, and Jebba is the most urgent operational priority. These plants require explicit, seasonally calibrated dispatch protocols – issued through the system operator – that constrain continuous drawdown through the dry season and preserve minimum water volumes for the February–April peak.

This is not a novel intervention: Storage hydro systems worldwide operate under precisely these kinds of seasonal reservation rules. The principle is simple – the reservoir is a battery, and the battery must not be depleted before the peak. Implementing this at Shiroro means restoring, through dispatch scheduling, something of the plant’s designed role as a peaking and reserve asset, which in turn means ensuring that the thermal fleet carries more of the continuous load burden it was originally designed to carry.

Gas supply prioritisation for the stress season is the necessary corollary. If hydro is to be held in strategic reserve, thermal must compensate by running more reliably through the February–April window. This requires securing firmer gas supply contracts with meaningful delivery guarantees and financial penalties for non-delivery, specifically for the stress season months. Emergency fuel arrangements – including fuel oil or LNG backup capacity at key generating stations – should be pre-positioned before the stress season begins, not scrambled for after outages have already started. Maintenance scheduling across the thermal fleet should be deliberately calibrated to avoid the February–April period, concentrating planned outages in the wet season when hydro output is high and demand is lower. These are scheduling decisions. They require management discipline, not capital.

Demand-side management offers a third lever that is almost absent from Nigeria’s current toolkit. Time-of-use pricing – higher tariffs during peak load hours in the February–April stress season – would create a financial incentive for industrial and commercial consumers to shift discretionary loads away from the afternoon demand peaks. This does not require universal smart metering; it can be introduced selectively for large commercial and industrial accounts on advanced meters, and expanded progressively. Demand response programmes, in which large consumers agree in advance to curtail or shift specific loads during stress periods in exchange for price incentives, are standard practice in mature electricity markets and are technically feasible even within Nigeria’s current metering infrastructure for larger consumers. The contrast with the general tariff argument is instructive: This is a targeted pricing instrument applied to a specific seasonal problem, not a blanket increase applied in the hope that better commercial outcomes will flow.

Seasonal system adequacy reporting should be established as a regulatory requirement and published publicly. NERC should be required to produce, each October, an explicit adequacy assessment for the coming dry season – forecasting available capacity, identifying expected shortfalls, and committing to the specific measures in place to manage them. This alone would transform the accountability framework overnight.

That last point deserves emphasis. A mandatory public adequacy assessment – produced before the stress season arrives rather than after outages have begun – would establish a baseline against which performance can be measured, create public accountability for seasonal planning, and transform the analytical culture of the sector. It costs almost nothing. It requires only regulatory will. And it would make it impossible, for the first time, for Nigeria’s electricity authorities to treat the February crisis as an annual surprise.

The medium term: Changing the generation mix
The operational measures described above address the seasonal crisis within the existing generation portfolio. They are necessary and can begin immediately. But they are not sufficient on their own, because the structural mismatch between Nigeria’s generation mix and its seasonal load profile is deeper than operational reform alone can reach. The composition of the portfolio itself must change.

Solar PV generation is the most important medium-term opportunity for seasonal resilience, and its significance for the seasonal crisis is underappreciated in the policy debate. Solar output is naturally highest during the dry season months of maximum sunshine and clearest skies – precisely the February–April period when hydro output is lowest and cooling demand is highest.

This positive correlation between solar output and the stress season is the structural opposite of the negative correlation that characterises hydro. Deliberate expansion of grid-connected and distributed solar capacity would, therefore, not merely add megawatts in the aggregate; it would add megawatts specifically during the season that needs them most. Realising this opportunity requires active Federal-level policy support, targeted investment facilitation, and a financing framework that makes large-scale solar deployment commercially viable – not a devolution of responsibility to subnational actors whose fiscal and technical capacity is unequal to the challenge.

Battery storage, combined with solar or deployed as standalone peaking capacity, could partially replicate the designed peaking function that Shiroro is currently unable to fulfil – shifting solar generation from midday peaks to the evening hours when cooling demand persists and solar output has declined. Utility-scale battery storage remains expensive at present, but declining costs make it increasingly viable, and smaller-scale deployments at distribution substations could provide meaningful frequency support during the stress season without requiring the scale of investment that full grid-level storage would demand.

Dedicated peaking gas capacity for the February–April stress window need not mean new procurement in the first instance. Several generating units within the existing fleet – particularly fast-ramping open-cycle gas turbines currently used intermittently – are technically suited to a designated peaking and reserve role. Repositioning such units through dispatch scheduling, holding them in readiness specifically for the stress season rather than running them continuously at reduced efficiency, would deliver the strategic flexibility the system needs at substantially lower cost than new-build. The prerequisite conditions are firm gas supply contracts with reliable delivery guarantees and a payment mechanism that ensures gas producers are paid on time, without which no peaking arrangement, whether from existing or new capacity, can be made operationally credible.

Energy efficiency in cooling appliances is the demand-side complement to these supply-side measures. As incomes rise and urbanisation continues, Nigeria’s cooling load will grow substantially, and the amplitude of the seasonal demand spike will grow with it. Mandatory minimum efficiency standards applied to new room air conditioning units entering the market – without requiring existing owners to replace functional equipment – would moderate the long-run growth of that spike without imposing any burden on households already stretched by cost-of-living pressures. Voluntary incentive programmes for early adopters who can afford the transition to higher-efficiency units would accelerate the improvement without the regressive implications of compulsory replacement. The regulatory mechanism is straightforward; what is required is the decision to act on a timeline long enough to shape the market before the cooling load compounds further.

Transmission investment to remove the bottlenecks that prevent available generation from reaching demand centres is a prerequisite for any of these supply-side measures to be effective. It is a chronic problem, but it has particular seasonal significance: If southern thermal and future solar capacity cannot be wheeled northward and across the region where dry-season heat is most intense, the seasonal supply gap will persist regardless of what is added to the installed base elsewhere. This also calls for a deep examination of the configuration and purpose of the grid.

The reframing that is required
Beyond the specific operational and structural interventions, the analysis presented in this series calls for a more fundamental reframing of how Nigeria’s electricity crisis is understood – in policy circles, in regulatory proceedings, and in public discourse. Without that reframing, the interventions will not be prioritised correctly, and the accountability frameworks that would sustain them will not be built.

The first reframing is from installed capacity to seasonally reliable capacity. The headline figure of roughly 13,000 megawatts of installed generation capacity is a misleading measure of the system’s actual capability. What matters operationally is how much capacity is available when it is needed. A system that can deliver less than 5,000 megawatts in February is, in any meaningful operational sense, no more than a 5,000 megawatt system at its most critical moment. Planning standards, investment targets, and public accountability frameworks should be built around seasonally available capacity and seasonal adequacy – not nameplate totals that bear little relationship to operational reality.

The second reframing is from chronic dysfunction to layered diagnosis. Nigeria’s electricity crisis is not one problem. It is at least two analytically distinct but operationally fused problems: A chronic structural layer and a seasonal cyclical layer. Interventions addressed at the chronic layer will not resolve the seasonal crisis. Interventions addressed at the seasonal layer will not resolve the chronic dysfunction. Both require diagnosis and both require remedy, and the remedies are different. The current policy conversation, which is almost exclusively focused on the chronic-structural dimension, addresses neither with the precision required.

The most fundamental reframing required is cultural and institutional: From a system that reacts to outages after they occur to one that plans for the stress season before it arrives. Nigeria’s electricity authorities know that February will arrive. They have known for decades. The failure to plan for it is not an information failure. It is a governance failure

The third reframing follows directly: From reactive to anticipatory management. Nigeria’s electricity operators and regulators know that February will arrive. They know that temperatures will spike. They know that reservoirs will be low. They have known these things for decades. The hydrological records exist. The meteorological data exist. The generation performance data exist. The failure to plan explicitly for this predictable annual event – to pre-position gas, conserve reservoirs, schedule maintenance, prepare demand-side responses, and publish an adequacy assessment that commits the system to accountability – is not a failure of information. It is a failure of governance.

Correcting it requires not just new policies but a new analytical culture: One that treats the seasonal cycle as an operational planning reality rather than an annual surprise, and that holds the people responsible for managing the grid accountable for the plans they make and the results they deliver.

The grid has a clock
Nigeria’s annual February–April electricity crisis is not mysterious. It is not random. It is not the undifferentiated expression of a generally dysfunctional system. It is the predictable, measurable, and largely avoidable consequence of a structural mismatch between the country’s generation mix and its seasonal load profile – a mismatch compounded by the inversion of key assets from their designed roles, and by the complete absence of seasonal adequacy planning in a system whose seasonal vulnerabilities have been visible in the data for decades.

The seasonal scissor – peak cooling demand coinciding with minimum hydro output in a system with no reserve margin – has been observable to any analyst willing to look at the data for as long as the data have existed. The Shiroro story – a plant designed explicitly to address seasonal system stress, now unable to perform that function because it has been consumed by the chronic dysfunction it was meant to help manage – is a microcosm of the broader analytical and governance failure. Nigeria built the answer to part of this problem. Then, through a combination of underinvestment elsewhere and the progressive subversion of design intent in dispatch operations, it dismantled the answer without noticing.

The remedies are not beyond reach. The most important immediate steps – seasonal reservoir management, maintenance scheduling reform, gas supply pre-positioning, and the establishment of mandatory seasonal adequacy reporting – require no new infrastructure. They require only operational discipline, exercised through the legitimate instruments of system operator dispatch and regulatory oversight, and the institutional will to treat a predictable annual crisis as a management challenge rather than an act of God.

The medium-term structural measures – solar expansion, repositioning of suitable peaking capacity, efficiency standards for new cooling appliances, transmission investment – require capital and political commitment. But they are investments targeted with a precision that the current policy conversation, focused almost entirely on aggregate capacity totals and tariff levels, does not achieve and cannot generate.

The starting point for all of this is the diagnostic honesty that this series has attempted to frame: A willingness to describe the problem with the specificity it deserves, to distinguish the seasonal crisis from the chronic dysfunction, and to resist the temptation to reach for a universal remedy – tariff reform, new installed capacity, foreign investment – that addresses the wrong question with the wrong instrument.

The grid has an invisible clock. It has been ticking for decades. It tells the same time every year. And every year, the people responsible for keeping Nigeria’s lights on are apparently astonished when it strikes. That astonishment is a choice. So is the alternative.

Dr Babalola is a former Minister of Power and was one of the principal architects of Nigeria’s electricity sector reform. Through Exenergia Limited, he works on infrastructure development, electricity industry policy, regulatory economics, and the macroeconomic dimensions of energy infrastructure failure. This paper is the third and final instalment of The Grid’s Invisible Clock, published under the Exenergia Limited banner.