By SolarQuant Editorial. Published 2026-09-25. Last updated 2026-10-12.
Nigeria’s Net Billing Regulations 2026 are now in force, establishing the country’s first national framework for connecting distributed solar to the grid and crediting the surplus that a system exports. Much of the commentary so far treats the framework as little more than a way to sell spare power back to the grid. We see it as something more significant than that. The regulations matter less for the export they allow than for the way they decide where a project’s value finally settles, and that is driven far more by how the system is sized and how its contract is written than by export itself. For anyone developing, financing, or contracting distributed solar in this market, these are the questions to resolve before committing to a project.
The most important point is that the framework does not change the underlying economics of most distributed solar projects. The highest-value kilowatt-hour remains the one consumed behind the meter and used to offset grid or diesel generation. Net billing introduces a mechanism for valuing surplus, but that value is secondary to the value of self-consumption.
This distinction matters because it changes the way a project should be sized. A system that is optimised around maximum generation may appear attractive in a simple energy model, but under a net billing regime it can create a larger volume of lower-value exported power. A system optimised around the site’s consumption profile may produce less total generation but retain more of its output in the highest-value part of the stack. The question is therefore not only how much solar can fit on the roof or land, but how much of that generation can be absorbed by the load at the times it is produced.
For commercial and industrial users, this makes the load profile central. Sites with daytime demand that tracks solar production will capture more value from the same installed capacity than sites whose demand is concentrated outside solar hours. Two projects with the same tariff, capex, and irradiation can therefore produce materially different outcomes once the regulation is applied to their actual consumption patterns.
Net billing is often described as an additional revenue stream, but in practice it is also an allocation mechanism. Once exported power is credited at a defined rate, the model must decide who receives that value and how it affects the contract between the parties.
In a self-consumption PPA, for example, the customer may buy only the energy consumed on site, while exported energy may accrue to the developer, the customer, or be shared according to the contract. In a lease or fixed-fee structure, export value may improve the project economics indirectly, but it may not be visible as a separate payment line. In a hybrid contract, the allocation may change over time or depend on thresholds.
This means that the same physical system can produce different financial outcomes depending on the contract structure. Treating export as a generic revenue line risks overstating the developer’s return or understating the customer’s benefit. The regulatory credit has to be mapped into the commercial agreement, not simply added to the project revenue stack.
Before net billing, oversizing a behind-the-meter system was often constrained by the risk of wasted energy or curtailment. Under the new framework, export can reduce that waste, but it does not automatically make oversizing optimal. The exported kilowatt-hour is still normally worth less than the self-consumed kilowatt-hour, and the system still carries the full capital cost of the additional capacity.
The practical implication is that oversizing must be justified by the marginal value of the extra generation. If the additional capacity mostly produces exported energy at a lower credit, the project may show weaker returns even though total generation is higher. If the additional capacity supports future load growth, improves resilience, or works in combination with storage, it may be justified. But that conclusion has to come from modelling the load, the regulation, and the contract together.
This is especially important for projects where the customer is expected to grow demand over time. A system that appears oversized in year one may be appropriately sized by year three. Conversely, a system justified on expected growth can become uneconomic if that growth does not materialise. Net billing does not remove that risk; it changes how the downside is expressed.
The regulation also affects the role of batteries. Where export credit is low relative to retail tariffs or diesel displacement, storage can preserve value by shifting surplus generation into periods of on-site demand. Where export credit is more favourable, the case for storage may depend less on avoiding export and more on resilience, demand management, or tariff arbitrage.
This makes dispatch assumptions important. A battery model that simply charges on surplus and discharges later may miss the economic trade-off between exporting now and consuming later. The correct dispatch strategy depends on the export credit, the import tariff, the customer’s load pattern, the degradation cost of storage, and the contract allocation of value.
For investors, this means that storage cannot be assessed as a generic add-on. It has to be evaluated against the specific regulatory and commercial structure of the project. In some cases it will increase returns; in others it may improve resilience but dilute financial performance.
The new rules also increase the importance of clear drafting. If exported energy has value, the contract must specify who owns that value, how it is measured, how credits are applied, and how disputes are handled. Ambiguity around export allocation can turn into a material economic issue once the system is operating.
Developers and customers should therefore align the technical design, metering arrangement, and payment mechanics before financial close. The PPA or lease should not be treated as separate from the grid-connection and net-billing assumptions. They are part of the same economic model.
This is also relevant for lenders and investment committees. A project whose model assumes export value but whose contract does not clearly allocate that value carries a documentation risk, not just a modelling risk. The stronger projects will be those where the regulation, meter configuration, billing logic, and contract language all point to the same outcome.
For Nigeria, the practical modelling implications are clear. A project should be tested under at least three linked dimensions: the site load profile, the net-billing credit mechanism, and the contract structure. Sensitivities should not be limited to capex, irradiation, and tariff escalation. They should also include export credit, self-consumption ratio, future load growth, storage dispatch, and the allocation of exported value between customer and developer.
A model that treats these variables separately will miss the way they interact. Increasing system size changes the self-consumption ratio. Changing the self-consumption ratio changes the value stack. Changing the value stack changes the economics of the contract. Changing the contract changes who receives the benefit of the regulation.
This is why net billing should not be modelled as a simple revenue uplift. It is a rule set that changes the boundary between technical sizing and commercial structuring.
Nigeria’s framework is a positive development because it gives distributed solar projects a clearer route to monetising surplus generation. But the projects that benefit most will not necessarily be the largest systems or those with the highest exported volumes. They will be the projects whose sizing, load profile, storage strategy, and contract structure are aligned with the regulation.
Considered together, these points lead us to a single conclusion. Sizing is not solely an engineering determination but an allocation of value, and the regulation, the load profile, and the contract structure each influence that allocation in ways that remain obscured when any one of them is assessed in isolation. A project evaluated without regard to all three will, in our judgement, misattribute its returns, overstating the contribution of export and understating that of the load it was built to serve. This integrated assessment is the function our platform is designed to perform. SolarQuant models net billing among its supported schemes and monitors grid-export regulation across the markets we serve, allowing a project to be tested against the applicable regulation, against the actual load profile of the site, and against the contract under which it will operate, in advance of any capital commitment. As further markets introduce comparable rules, the projects that realise the value on offer will be those modelled with the regulation, the load, and the contract treated as a single whole.