The Authority Is Signed. Now Comes the Hard Part.

There is a particular kind of optimism that fills conference rooms when governments announce electricity reform in Nigeria. It is real, it is often earned, and it has — on more occasions than the sector cares to count — collided with the distance between policy ambition and operational reality.

The BusinessDay Energy Conference 2026, themed 'Beyond the Grid: How States Can Rewrite Nigeria's Power Story', was not short on ambition. Lagos Governor Babajide Sanwo-Olu's declaration — relayed through Commissioner Biodun Ogunleye — that the first state-licensed independent power producers will commence commercial operations between 2026 and early 2027 drew the kind of response that reform announcements are designed to draw: cautious excitement and a quiet hope that this time, the execution matches the rhetoric.

PowerPulse was in the room. This is what we observed, what the data says, and what strategists and investors should actually be thinking about.

What changed — and why it matters this time

The Electricity Act 2023 did something procedurally significant that its predecessors did not: it created a legal pathway for states to own their electricity markets — not just complain about the federal one. Lagos moved faster than every other state, completing its transition to state-level regulation in 2025 and enacting the Lagos State Electricity Law 2024 to give the framework domestic teeth.

On Sunday, the state formalised Power Purchase Agreements and concession arrangements with three independent power producers — Mainland Power Limited, Fenchurch Power Limited (in partnership with Aggregate Utilities Limited), and Vaikhan Engineering Limited — targeting between 200MW and 400MW of new generation capacity over the coming years.

“The question is no longer whether states have the authority. It is whether they have the will to act.”

That framing, offered by the Governor, is strategically astute — and slightly misdirecting. Will is not the scarce resource. Execution infrastructure is. The difference between Lagos today and Lagos in previous reform cycles is not political resolve; it is the presence of a legal instrument that, for the first time, lets the state go around the federal bottleneck rather than through it.

That is the structural change worth tracking. Everything else is execution detail — and execution detail is precisely where Nigeria's energy reform history has accumulated its most painful lessons.

The regulatory question nobody fully answered

The conference surfaced a tension that the sector has not yet resolved cleanly: in a decentralised electricity framework, which regulator is actually in charge?

The Electricity Act 2023 devolves market authority to states. But NERC — the Nigerian Electricity Regulatory Commission — retains jurisdiction over interstate transmission and the national grid. State-licensed IPPs that wish to wheel power beyond their host state, access backup capacity from the national grid, or transact with federal offtakers enter a regulatory overlap zone where the applicable rules are, at best, imperfectly defined.

For Lagos, this is manageable in the near term: the projects are scoped to stay within the state's regulatory perimeter. For Nigeria's twenty-nine other states watching this experiment, the lesson is more nuanced — the Lagos model is not a copy-paste template. It works partly because Lagos has the demand density, the economic base, and the legal groundwork to sustain a genuinely self-contained sub-market. Most states do not.

The $2.7 billion number and what it actually means

Governor Sanwo-Olu cited a figure that should arrest the attention of every economist, banker, and industrial operator in Nigeria: Lagos spends an estimated $2.7 billion annually on self-generation. Diesel generators. Inverters. Backup systems. Dead capital.

To contextualise: that is roughly 1.5% of Nigeria's entire GDP disappearing into a workaround for a service the state should be providing. It represents the cost floor against which any serious IPP offering must compete — and it is a compelling commercial argument for the viability of state-licensed alternatives, provided they can achieve the reliability threshold that makes self-generation redundant rather than merely supplementary.

“Reliable electricity could potentially double the size of Lagos' economy over time. The number is large enough to be aspirational. It is also large enough to be a measure of how much has been lost to inaction.”

The strategic read for investors is straightforward: any project that can credibly deliver above 95% uptime to industrial clusters in Lagos is not competing against the grid. It is competing against diesel. That is a more favourable competitive position than the headline electricity market analysis typically suggests — and it changes the bankability calculus significantly.

From PPA to megawatt: the execution gauntlet

A signed Power Purchase Agreement is not power. Between the signature and the first commercial megawatt, a project must navigate land acquisition, equipment procurement (in a constrained global supply chain), grid interconnection approvals, financing drawdown, construction, commissioning, and metering infrastructure.

Nigeria's IPP history is well-acquainted with projects that signed, announced, and stalled. The Electricity Act 2023 removes one critical bottleneck — federal regulatory overlap — but it does not resolve financing risk, FX exposure on imported equipment, or the capacity of state governments to process approvals at the speed that commercial timelines require.

The 2026–2027 commercial operations window cited by the Governor is achievable — for fast-tracked projects with construction already advanced. For the broader pipeline implied by the PPA announcements, 2027–2028 is a more conservative and, arguably, more honest planning horizon.

What other states should actually take from this

The conference framed Lagos as a proof point and a model. It is a proof point. It is a partial model.

States considering a similar path should be clinical about which elements of the Lagos story are transferable. The legal framework — the state electricity law — is replicable anywhere the political will exists to draft and pass it. The demand base that makes IPP investment commercially viable is not. Lagos' industrial density, population, and economic activity create an offtake environment that Kebbi, Taraba, or even Enugu cannot replicate at equivalent scale without a fundamentally different project structure.

The more instructive Lagos lesson is not 'decentralise and investors will come.' It is, build the regulatory infrastructure first, identify the anchor demand that makes projects bankable, then create a state electricity law that gives investors the contractual certainty to deploy capital. Sequence matters as much as intent.

What to watch

• → NUPRC and NERC formal guidance on state-federal regulatory interface for licensed IPPs — no official timeline, but lobbying is active.
• → Construction commencement notices from Mainland Power, Fenchurch/Aggregate, and Viathan — the first real signal of whether 2026 is credible.
• → Other state governments' responses to the Lagos announcement — early movers with legal frameworks already in draft include Rivers and Kaduna.
• → NERC tariff methodology update expected before June — will reshape C&I solar and IPP bankability calculations sector-wide.