-By Sola Adebawo
In Nigeria’s latest petroleum licensing round, winning an oil block may prove easier than keeping it.
On July 21, 2026, the Nigerian Upstream Petroleum Regulatory Commission announced that 31 companies had emerged as successful bidders for 37 oil and gas blocks. One month later, the Commission reminded the winners that their awards remained conditional: pay the required signature bonuses and fulfil the prescribed post-award obligations within the stipulated period, or risk losing the awards to reserve bidders.
That warning is more than routine regulatory language. It is an early test of whether Nigeria’s licensing regime can distinguish credible upstream investors from companies primarily interested in acquiring and holding prospective acreage.
According to NUPRC’s official results, 143 companies submitted about 200 bids for 37 of the 50 blocks offered. Thirteen blocks attracted no bids and returned to the government’s licensing basket. Attracting that participation is a meaningful process achievement. It is not yet an upstream production achievement.
The acreage covers the Niger Delta’s onshore, shallow-water and deep-offshore terrains, as well as the Benin, Anambra and Chad basins and the Benue Trough. NUPRC described the interest in frontier basins as significant because such acreage had not historically attracted participation on this scale.
Yet a successful bid is not the same as a perfected petroleum licence.
The winners presently hold provisional awards subject to financial, legal and regulatory conditions. In a notice reported by The PUNCH, NUPRC warned that non-compliant winners would forfeit their bid guarantees and lose their provisional awards to designated reserve bidders.
Public accounts have not always distinguished clearly between the period for paying the signature bonus and the wider 90-day post-award compliance period. The binding deadline for each company is therefore the one contained in its provisional award letter.
This also explains why describing the consequence simply as “licence revocation” is not entirely precise. Failure at this stage would cause a conditional award to lapse or be invalidated. That is different from revoking an already granted Petroleum Prospecting Licence under sections 96 and 97 of the Petroleum Industry Act.
The signature bonuses offered during the round range from US$3 million to US$7 million per block and must be paid in United States dollars. NUPRC’s official licensing guidance shows that the bonus was only one part of the evaluation. Work programmes, technical competence, financial strength, bank guarantees, cost efficiency, corporate governance and decarbonisation plans were also considered.
Across 37 blocks, the prescribed range produces a nominal band of US$111 million to US$259 million. This is not a forecast of government receipts. Actual revenue will depend on the winning bids, completed payments, any tie-breaking offers and the awards that survive the post-award process.
The reduced bonus reflects a deliberate policy shift. Reuters reported that the entry payment had fallen from approximately US$200 million for some assets several years ago to about US$10 million in the 2024 round and US$3 million to US$7 million in the latest exercise. These figures are not strictly comparable across different assets and rounds, but they demonstrate a clear reduction in upfront entry costs.
There is sound commercial reasoning behind that change. Excessive signature bonuses may raise immediate government revenue but also consume capital that should be deployed for seismic acquisition, exploration drilling, appraisal and field development. Nigeria needs producing assets more than it needs impressive auction receipts unsupported by subsequent investment.
But lower entry costs must be matched by stronger execution standards. Otherwise, the country risks replacing expensive speculation with cheaper speculation.
NUPRC is therefore right to enforce published conditions consistently. An awardee unable to meet the first major financial obligation should not be permitted to warehouse acreage while other qualified bidders wait. Default does not, however, give a reserve bidder an automatic licence. It allows NUPRC to invite the designated reserve bidder to demonstrate funding, provide the required guarantees and satisfy the applicable approval conditions.
NUPRC has enforced such conditions before. In the 2020 Marginal Field Bid Round, it treated 33 unpaid awards as expired after the applicable 45-day window, while reporting approximately ₦174 billion in signature-bonus receipts, according to the regulator’s account reported by TheCable. Although that exercise had separate guidelines, it shows that the present warning should not be assumed to be empty.
Still, paying a signature bonus should not be confused with proving development capacity. The bonus tests immediate liquidity. It does not, by itself, establish that a company can fund seismic work, drill exploration wells or develop a commercial discovery.
Nothing in the public record establishes that any named winner lacks such capacity, nor should indigenous or newer entrants be presumed incapable because of their size. Upstream projects are commonly financed through equity, debt and technical partnerships. A smaller operator with committed capital, experienced partners and a disciplined work programme may be more credible than a larger company burdened by debt and competing investment commitments. The proper test is whether an awardee has a realistic and verifiable strategy for financing each stage of its obligations.
Enforcement must also run in both directions. Investors should meet their payment and work-programme commitments, while government must provide timely approvals, regulatory consistency, reliable geological data and an enabling framework for infrastructure access and project execution. Investor credibility and regulatory credibility are reciprocal.
Subject to legitimate commercial-confidentiality limits, NUPRC and NEITI should reconcile block-level payments and disclose forfeitures, reserve-bidder substitutions, beneficial ownership and final licence status. Any deadline extension or material alteration to an award should also be made public.
For communities around the awarded acreage, the relevant outcome is not the size of the signature bonus. It is whether operations proceed safely, protect the environment, create credible local economic opportunities and are supported by sustained engagement.
NUPRC is right to insist that deadlines mean something. But Nigeria should not declare the licensing round successful merely because bonuses have been collected. Success will be measured by credible work programmes executed, exploration wells drilled, discoveries appraised, communities responsibly engaged and commercially viable oil or gas production brought on stream.
The deadline is not the conclusion of the licensing round. It is the first serious test on the long road from bid to production.
Sola Adebawo is an energy industry executive, strategic advisor and thought leader with nearly three decades of experience across Africa’s upstream petroleum sector. He is the Chief Executive Officer of Hyphen Partners Limited, a specialist advisory firm focused on policy and regulatory intelligence, market entry, stakeholder strategy, executive and institutional positioning in complex and highly regulated industries. A former executive at Chevron and Heritage Energy, he is an author, scholar and ordained minister. His writing explores energy policy, political economy, corporate governance, strategic communication, leadership, the relationship between institutions and public life, as well as the institutional forces shaping Africa’s development.
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