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How to Read the 127 Million Barrel Figure
When a regulator says Nigerian refineries took in more than 127 million barrels of local crude in nine months, the number sounds like a clean success story. Read closely, it is a record of a troubled first quarter, a strong second one and a weaker third, with several questions left unanswered.
The Nigerian Upstream Petroleum Regulatory Commission gave the figure on Monday, October 26, in a speech delivered at the OTL Africa Downstream Energy Week in Lagos, whose theme was “Secure Energy, Shared Prosperity.” The commission’s chief executive, Oritsemeyiwa Eyesan, was represented by Prosper Omonedo, an assistant director in charge of operations. According to the speech, the volume covers crude oil and condensate supplied to domestic refineries from January through September.
The first fact worth noticing is why the early months were difficult. The commission said deliveries improved after commercial disagreements between oil producers and refiners disrupted supplies in the first quarter, and that its intervention helped fix the problem. That matches a long-running tension: the Petroleum Industry Act requires producers to make crude available to local plants, but price, grade and delivery terms are negotiated, and disputes can delay cargoes even when crude exists. The commission said it engaged both sides, after which the second and third quarters brought 53.7 million and 45.1 million barrels, or 97.4 percent and 76.2 percent of expected supply.
The second fact is the size relative to refining capacity. Spread across the nine months, 127 million barrels averages about 465,000 barrels a day, an estimate reported by Streamlinefeed that matches simple division over 273 days. The 700,000-barrel-a-day Dangote refinery alone could take more than that, and the figure also covers other private and public refineries, so it cannot show how well any single plant is supplied. Earlier reports this month said Dangote lined up about 16 million barrels of Nigerian crude for October and also bought American grades, which suggests local crude does not cover every need.
The third point is what the commission has not published. The reports reviewed contain no breakdown by refinery, no split between crude and condensate, no explanation of the third-quarter drop to 76.2 percent, and no figures on price. One reader comment on a news site asked who benefits and where the transparency is, a fair question for an allocation that is supposed to follow rules. Publishing per-plant volumes and the reasons for shortfalls would let the public judge whether the allocation system treats refiners equally.
What is the regulator doing next? It is consulting producers and refiners on a domestic crude swap framework, so a refinery could take crude from the nearest suitable production or export point, a change it says could save about $3 to $4 a barrel in transport costs. It also says it is enforcing the drill-or-drop principle to discourage speculative holding of licences, and that 22 recent awardees are expected to add at least 250,000 barrels a day within five years, and that the 40 blocks in the 2026 licensing round will go through an evaluation with published criteria and mandatory disclosure of beneficial owners. Production in September averaged 1.717 million barrels a day including condensate, and crude alone averaged 1.53 million, the fifth month in a row at or above the OPEC quota.
For readers, three takeaways follow. The 127 million barrels is real and covers a large share of what local plants need, but not necessarily all of it. The third-quarter dip shows supply remains uneven. And the next report to watch is the fourth quarter’s, plus any per-refinery data, since those will show whether the intervention fixed the system or only the second quarter.
