Nigeria could lose 38% of its oil projects as the global energy transition accelerates, according to the Natural Resource Governance Institute (NRGI), a warning that lands directly on a producing country still dependent on crude exports for the bulk of government revenue and foreign exchange.

The figure frames a structural problem rather than a cyclical one. Demand-side pressure — electrification, efficiency gains and substitution in the world's largest importing economies — threatens to render a share of Nigeria's future production unsanctioned, undeveloped or uneconomic before the barrels are ever lifted.

For a country whose onshore Niger Delta estates have already struggled with theft, sabotage and divestment by international oil companies, the NRGI assessment adds an investment-risk dimension that no amount of operational improvement alone can fix.

What does the 38% figure actually mean?

NRGI's projection addresses Nigeria's project portfolio — developments that could fall away if the world decarbonises faster than the country's upstream sector adapts. The energy transition, in this reading, is not a distant policy debate but a present commercial constraint on final investment decisions.

The exposure cuts across the value chain:

• Upstream: fields requiring long payback periods face the risk that demand erodes before capital is recovered.
• Fiscal terms: the state's take from licensing, royalties and taxes shrinks if projects are never sanctioned.
• Downstream: refineries and export terminals built around crude flows inherit the same demand uncertainty.

The report does not argue that Nigerian production stops tomorrow. It argues that a material share of the pipeline — more than a third, on its central warning — sits in the zone where transition scenarios and project economics collide.

Why Nigeria carries outsized transition risk

Several conditions concentrate the risk in Nigeria specifically. The government depends heavily on hydrocarbon revenue to fund budgets, making any contraction in the project base a fiscal event, not merely a corporate one. International oil companies have already redirected capital toward gas and lower-carbon portfolios, and Nigeria has watched successive divestments reshape ownership of its onshore acreage.

At the same time, the global investment community increasingly prices transition risk into hydrocarbon financing. That raises the cost of capital for exactly the kind of long-cycle projects Nigeria would need to sustain output — deepwater developments and major rehabilitations among them.

The result, NRGI's analysis implies, is a country whose resource wealth may under-deliver not because the geology failed, but because the market moved.

What should policymakers and operators watch?

The report's warning is ultimately a planning instrument. For Abuja, the 38% figure argues for treating petroleum revenue projections with conservative assumptions rather than optimistic ones — budgeting, borrowing and saving decisions all hinge on how realistic the production outlook is.

For operators and investors across the Niger Delta, the onshore shelf and deepwater blocks, the question is which projects clear commercial hurdles under weaker long-term demand, and which never reach sanction at all.

The watch items are straightforward: the pace of FID announcements in Nigerian acreage, the terms offered in future licensing rounds, and whether Nigeria diversifies its revenue base fast enough to absorb a smaller upstream sector. NRGI's 38% is a projection, not a verdict — but it sets the benchmark against which Nigeria's next decade of project sanctioning will be measured.