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The economics of commercial solar in Nigeria in 2026

For factories, hospitals and telecom sites, solar competes with the true cost of self-generation rather than with the grid tariff. The case is usually decided by load profile, finance and currency.

By Dr Olugbenga Olaoye, 8 September 2026, 6 min read

Rows of ground-mounted solar panels catching low afternoon sun.
Ground-mounted solar array. Photo: Vlad Burac

What solar is really competing with

Most commercial and industrial users in Nigeria run on a blend: grid supply when it is there, diesel or gas generation when it is not, and batteries to bridge the gaps. The relevant comparison for a solar investment is therefore not the published grid tariff but the blended cost of the supply it displaces, which is dominated by self-generation.

Where that supply is diesel, its cost moves quickly. Dangote’s gantry price for diesel rose from ₦1,570 a litre before 21 August 2026 to ₦1,850 on 4 September, and sites buying delivered fuel pay more than the gantry price; the National Bureau of Statistics put the national average retail price at ₦3,277 a litre in May 2026, 32% higher than in April. Generators also yield less energy per litre at part load. Cummins’ data sheet for its C500 D5e set shows fuel use of 74.25 litres an hour at three-quarters of its 364 kW prime rating, about 3.7 kWh per litre, and 31.42 litres an hour at a quarter of it, about 2.9 kWh per litre. At ₦1,850 a litre, fuel alone therefore costs about ₦500 per kWh from a well-loaded set (1,850 ÷ 3.7) and about ₦640 from a lightly loaded one (1,850 ÷ 2.9). Maintenance, overhauls and the capital cost of the set come on top.

That framing matters. A site with reliable grid supply on a low tariff band may find solar marginal. A site that runs generators for much of the day may find it compelling even on conservative assumptions.

Load profile decides the size

The economics are set less by the panels than by when the site uses power. Solar without storage produces in daylight. A day-shift factory or an office building matches that well; a facility with heavy evening load does not, unless it adds batteries. Oversizing wastes capital on energy the site cannot use; undersizing leaves the most expensive hours untouched.

A measured load profile, ideally a year of half-hourly data, is the single most valuable input to the decision. Where none exists, a few weeks of metering before design is cheap insurance.

Capital cost and currency

Panels, inverters and batteries are imported and priced in dollars, and the naira cost is set on the day the letter of credit is opened. Equipment prices have fallen over the past decade. OPIS assessed Chinese TOPCon modules at $0.108 a watt free on board in late August 2026, or about $108 per kilowatt, and BloombergNEF’s December 2025 survey put the average price of stationary-storage battery packs at $70 per kWh, 45% lower than a year earlier. Neither benchmark includes inverters, mounting, freight, clearing, inland transport or installation.

Duties add a layer that moves with policy. The Nigeria Customs Service confirmed in September 2024 that solar panels, under HS codes 8541.42 and 8541.43, carry no import duty and no VAT under the ECOWAS Common External Tariff, and the Nigeria Tax Act 2025, effective from January 2026, exempts renewable energy equipment from VAT unless the Minister of Finance directs otherwise. The Customs clarification covered panels, so inverters and batteries should be checked against their own tariff lines. The policy can also turn: in March 2025 the technology minister proposed banning imported panels to favour local assembly, before the Rural Electrification Agency said in April that imports would not be banned ‘for now’.

Two currency risks deserve separate treatment: the gap between approval and delivery, and the life of any dollar-linked financing. The first can be closed by paying early or fixing the rate. The second sits with the buyer for years.

How projects are financed

Bank lending against distributed solar remains limited. Local-currency finance is moving, in the words of one BusinessDay review of 2025, ‘from isolated, one-off transactions towards more programmatic, portfolio-based financing structures’, such as United Capital’s ₦5 billion revolving facility for Husk Power’s mini-grids, announced in September 2025; the same review found financing ‘still insufficient, both in volume and structure’. So most projects take one of three forms. Outright purchase suits buyers with cash and a long horizon. A lease moves the capital cost to a financing partner in exchange for fixed payments. A power purchase agreement, where a developer owns and operates the system and sells the output, shifts performance risk to the developer but makes the buyer’s credit the central question.

For developers, the offtaker’s ability to keep paying through a downturn is the risk that prices the deal. Tenor, termination terms and step-in rights matter as much as the tariff.

Operating realities

Systems perform, but not unattended. Dust cuts output in the dry season, inverters fail before panels do, and batteries age with every cycle. A warranty is only as good as the local presence of the party giving it. Buyers should budget for maintenance and check that spares and service exist in their state, not only in Lagos.

Grid interaction is a separate question. Most commercial systems run in island mode, supplying the site and its batteries. Export became possible under the Nigerian Electricity Regulatory Commission’s Net Billing Regulations 2026, implemented from June 2026: a system of 50 kWp to 1.5 MWp connected to a distribution company’s network may export surplus energy for credits against the customer’s bill, at an export tariff approved by NERC, once the distribution company has assessed technical feasibility and signed a net billing agreement, the system is registered with NERC and a bidirectional meter is installed. Several states have taken over regulation of their own electricity markets, so terms may differ by state. Where the grid is unstable, protection settings and equipment quality are not optional extras.

The decision in one line

The investment case is the capital and financing cost of the system, divided by the energy it displaces, set against the blended cost of the supply it replaces, then tested against a weaker naira, a cheaper diesel and a better grid. A case that survives all three is probably sound.

What to watch

  • Rules on grid export and metering, which decide whether surplus energy has any value.

  • Duty and tariff classification of solar equipment.

  • The naira, between order and delivery and over the life of dollar-linked contracts.

  • Battery cost and chemistry, which move the case for evening load.

  • Service networks outside Lagos and Abuja.

  • Appetite among development finance institutions for commercial solar, and the terms attached.

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