By Amb Gabriel Tanimu Aduda, Former Permanent Secretary MPR and Former OPEC Governor for Nigeria

Abstract

Nigeria’s Petroleum Industry Act (PIA) 2021 was enacted to replace a fragmented legal

order with an integrated governance, regulatory, fiscal and host-community framework. Nearly five years later, the Act has produced major institutional gains: specialised upstream and midstream/downstream regulators have been established; the national oil company has been incorporated as NNPC Limited; subsidiary regulations have expanded; licensing and acreage administration have improved; and Host Communities Development Trusts have moved community benefits from discretionary corporate programmes into a statutory structure. Yet the reform has not fully transformed sector outcomes. NNPC Limited continues to combine commercial activity with quasi-fiscal and public-policy obligations; the relationship between the company and the Federation remains difficult to interrogate; regulatory boundaries are not always clear; production measurement and revenue assurance remain weak; environmental performance is inadequate; and the PIA is insufficiently connected to Nigeria’s energy-transition commitments.

This article applies legal-compliance, institutional-design, economic-outcome, public-interest and sustainability tests to assess the first five years of implementation. It argues that the central challenge is no longer the creation of institutions, but the conversion of legal architecture into transparent, measurable and commercially disciplined performance. The next reform phase should therefore prioritise an independent implementation audit, operationalisation of shareholder and policy-support institutions, integrated hydrocarbon measurement, stronger corporate governance, predictable domestic-supply rules, improved host-community accountability and enforceable methane and climate standards.

Keywords: Petroleum Industry Act; Nigeria; NNPC Limited; petroleum governance; host communities; regulatory reform; energy transition.

1.  Introduction

The PIA is one of Nigeria’s most consequential economic statutes since the return to democratic government. Enacted after more than two decades of unsuccessful reform initiatives, it sought to improve investment certainty, separate policy from regulation and commercial participation, establish a commercially oriented national petroleum company, strengthen government revenue, develop host communities and modernise environmental and gas governance. The statute comprises five chapters, 319 sections and eight schedules and formally created the Nigerian Upstream Petroleum Regulatory Commission (NUPRC), the Nigerian Midstream and Downstream Petroleum Regulatory Authority (NMDPRA) and NNPC Limited.

The significance of a five-year assessment lies in distinguishing legal enactment from institutional performance. The PIA can be successful as legislation while remaining incomplete as an implementation and development instrument. Accordingly, this article evaluates whether statutory institutions have performed their assigned functions; whether policy, regulation and commerce are genuinely separated; whether production, investment, revenue, domestic refining and gas commercialisation have improved; whether host communities and consumers have received intended benefits; and whether petroleum development is becoming consistent with environmental protection and Nigeria’s long-term transition obligations.

2.  Principal Gains Recorded

2.1  Legal consolidation and institutional separation

The Act replaced an ageing and dispersed framework of statutes, contractual practices and administrative conventions with a single legislative reference point. This has improved legal visibility for investors, operators and public institutions. It also established a clearer formal division between the ministry responsible for policy, the regulators responsible for technical and commercial oversight, and NNPC Limited as the Federation’s commercial vehicle. This separation accords with a basic principle of modern resource governance: the state should not allow the same institution to formulate policy, regulate competitors and participate commercially.

2.2  Commercialisation and disclosure by NNPC Limited

The incorporation of NNPC Limited in 2022 was a highly visible milestone. The company is expected to operate under company law, finance its activities commercially and deliver returns to its shareholders. It reported profit after tax of approximately ₦3.297 trillion for 2023 and ₦5.4 trillion for 2024, while public availability of audited financial statements represents a material improvement on the historical opacity of the former corporation. These gains, however, must be interpreted cautiously. Accounting profit does not by itself establish operational efficiency, because exchange-rate movements, asset revaluation, tax treatment, production entitlements, policy reimbursements and non-cash entries can materially affect reported results. Performance should therefore also be tested against cash remittances, debt, refinery productivity, cost efficiency and return on invested capital.

2.3  Subsidiary regulation, acreage management and investment certainty

The regulators have issued instruments on gas pricing, domestic demand, pipeline tariffs, safety, environmental management, decommissioning, remediation funds, strategic stocks, host-community trusts, gas distribution, dispute resolution and gas flaring, venting and methane emissions. These instruments have progressively converted broad statutory provisions into administrable obligations. The PIA also introduced stronger acreage-management principles, including relinquishment and the ‘drill or drop’ mechanism, intended to discourage prolonged warehousing of petroleum licences. Digital licensing processes offer a basis for more transparent allocation, although their credibility ultimately depends on public disclosure of criteria, beneficial ownership, signature bonuses, work commitments and post-award performance.

2.4  Host communities, environmental liabilities and gas development

Chapter 3 transformed host-community development from predominantly voluntary memoranda of understanding and corporate social responsibility arrangements into a statutory trust system funded by three per cent of settlors’ actual annual operating expenditure for the preceding year. By October 2025, NUPRC reported aggregate HCDT funding of about ₦373 billion and 536 ongoing community projects. The framework creates ring-fenced funding, formal governance structures and continuity of obligations when assets are transferred.

The PIA also strengthened the legal basis for environmental-management plans, remediation funding and decommissioning obligations. In addition, it treats gas as a distinct commercial and developmental resource rather than merely a by-product of crude production. Nigeria’s official gas reserves stood at 215.19 trillion cubic feet as of 1 January 2026, with an estimated reserves life index of 85 years. The critical task is to convert this resource base into electricity, industrial feedstock, liquefied and compressed natural gas, lower-emission domestic energy and export earnings.

3.  Implementation Losses and Deviations

3.1  Delays, overlap and an incomplete reform dividend

Several regulations required to operationalise the Act were issued only in 2023, 2024 or 2025. During this transitional period, statutory institutions existed while detailed procedures remained incomplete; legacy rules continued alongside the new framework; operators faced uncertainty; and regulators relied on circulars and administrative discretion. The creation of separate upstream and midstream/downstream regulators improved specialisation but introduced horizontal fragmentation. Gas gathering, processing, transportation, tariffs, measurement and domestic supply can engage both regulators, creating risks of duplicated approvals, inconsistent interpretations, delayed authorisation and forum shopping.

3.2  Incomplete commercial independence and shareholder oversight

NNPC Limited continues to perform commercial, quasi-fiscal and public-service functions. These include supporting domestic fuel supply, executing strategic infrastructure, implementing energy-security directives, managing legacy liabilities and absorbing costs that would ordinarily be transparently appropriated or compensated. Where such obligations are not separately identified, budgeted and independently verified, the company’s profitability, taxes, dividends and remittances cannot be properly assessed. Political control over board and senior-management appointments may also weaken continuity, merit-based selection, board independence and accountability for results.

The implementation gap is compounded by the non-operationalisation of the Ministry of Petroleum Incorporated (MOPI), contemplated as a specialist vehicle for managing the Federation’s petroleum investments, and the National Petroleum Policy Directorate (NPPD), intended to strengthen policy analysis, strategy and implementation monitoring. Without capable shareholder oversight and policy intelligence, government may respond to revenue concerns through ad hoc intervention rather than disciplined corporate governance.

3.3  Revenue opacity, measurement weaknesses and production underperformance

Publication of audited accounts has not resolved the wider opacity of financial relations between NNPC Limited and the Federation. Production entitlements, crude sales, joint-venture funding, supply costs, supplier debt, security expenditure, refinery rehabilitation, strategic infrastructure, deductions before remittance, taxation, dividends and retained earnings require more granular disclosure. These concerns are intensified by the absence of an integrated and independently verifiable hydrocarbon-measurement architecture. Revenue assurance is compromised where royalty, tax, production-allocation and flare-penalty calculations depend heavily on operator-generated data that are not consistently supported by tamper-resistant metering, remote transmission, reconciliation and independent audit.

Production remained below installed potential during much of the implementation period because of oil theft, pipeline vandalism, shut-ins, ageing infrastructure, evacuation constraints, delayed development and underinvestment. This illustrates a central lesson: legal reform is necessary, but insufficient where the state cannot secure infrastructure, enforce rules or reconcile physical production with fiscal records.

3.4  Domestic supply, social costs and environmental performance

The Domestic Crude Oil Supply Obligation seeks to support local refining and energy security, but recurring disputes over allocation, pricing, payment security, currency, crude quality, logistics and existing export contracts have weakened predictability. A legitimate domestic-supply objective can become commercially coercive when it lacks transparent pricing and bankable payment arrangements; conversely, producer avoidance defeats national energy-security objectives.

Market-based downstream reform also imposed substantial transitional costs because subsidy removal was not preceded by reliable domestic refining, competitive supply, transparent price setting, effective transport alternatives and targeted social protection. Meanwhile, stronger statutory environmental provisions have not yet produced a decisive reduction in spills, legacy pollution, routine flaring or ecological damage. Weak enforcement, inadequate measurement, delayed remediation, sabotage, illegal refining and limited public environmental data remain major constraints.

4.  Host Communities, Divestment and the Energy Transition

4.1  Host-community governance

The HCDT framework is a significant formal gain, but implementation has been uneven. Reported weaknesses include delayed incorporation and remittance, settlor influence over trustee selection and projects, disputes over community boundaries, weak publication of accounts, limited participation by women and young people, overlapping development structures and inadequate dispute-resolution arrangements. Formal compliance will not produce community ownership unless trusts publish contributions, audited accounts, procurement decisions and project-completion reports and are governed through transparent, inclusive processes.

The possibility of reducing trust funding because of sabotage or civil unrest also creates a collective-responsibility problem. Communities should not lose development entitlements because of acts committed by unidentified persons, organised criminal groups or outsiders without independent investigation, proof of causation, procedural fairness and an opportunity to challenge the finding.

4.2  IOC divestments and legacy liabilities

Transfers of mature onshore and shallow-water assets to indigenous operators have expanded Nigerian participation but may also transfer ageing infrastructure, unresolved pollution and underestimated abandonment liabilities to less-capitalised buyers. Regulatory approval should therefore be conditioned on independent environmental baselines, credible decommissioning estimates, funded financial assurance, allocation of historical liabilities, disclosure of unresolved spills and verification of the buyer’s technical and financial capacity. Sellers should not be released from historical obligations without demonstrated remediation or adequately funded indemnities.

4.3  Energy-transition deficiency

The PIA remains primarily a petroleum-development statute. It does not sufficiently address carbon-intensity standards, methane benchmarks, electrification of producing assets, carbon capture and storage, transition-risk disclosure, just-transition planning, renewable-energy investment by petroleum institutions or alignment of licensing with Nigeria’s nationally determined contribution and net-zero ambition. Although this is partly a legislative limitation, the failure to supplement the Act through policy and regulation has become an implementation gap.

The second phase of implementation should not treat climate policy as external to petroleum governance. Methane control, flare elimination, energy efficiency and credible decommissioning directly affect project economics, access to finance, export competitiveness and environmental legitimacy. Gas may support domestic energy access and industrialisation, but its role must be linked to enforceable emissions performance, infrastructure delivery and a long-term transition strategy.

5.  Reform Priorities for 2026-2030

6.  Overall Assessment and Conclusion

The PIA has been strongly successful in legal consolidation, moderately successful in institutional separation and regulatory development, partially successful in commercialising NNPC Limited and improving transparency, and weakly successful in environmental performance, production measurement and energy-transition integration. Private refining and gas commercialisation present emerging opportunities, but domestic-supply disputes, payment constraints and infrastructure gaps continue to limit delivery. Host-community trusts represent an important statutory innovation, yet their legitimacy will depend on genuine participation, financial disclosure and measurable local outcomes.

The appropriate response is not wholesale reopening of the Act or the abandonment of its institutional design. Indiscriminate amendment could reintroduce the conflicts that the PIA was designed to remove, particularly if a regulator is made both umpire and commercial participant. Reform should instead preserve the separation of policy, regulation and commerce while correcting identifiable defects, strengthening enforcement and establishing transparent performance measurement.

Nigeria’s second phase of PIA implementation must therefore shift from institutional establishment to outcome delivery. Success should be judged by increased and accurately measured production; improved Federation revenue; commercially disciplined national ownership; predictable and competitive regulation; accelerated gas utilisation; viable domestic refining; transparent host-community benefits; reduced flaring and methane emissions; funded environmental liabilities; and alignment between petroleum investment and Nigeria’s long-term energy strategy.

Five years of implementation demonstrate that legislation can change organisational form more quickly than it changes institutional culture. The enduring value of the PIA will consequently depend on whether Nigeria replaces discretionary practice with rules, opacity with verifiable data, political intervention with accountable shareholder governance, and formal compliance with measurable public value.

References

Federal Republic of Nigeria. (2021). Petroleum Industry Act, 2021, Act No. 6, Federal Republic of Nigeria Official Gazette, Vol. 108, No. 142.

Nigerian Upstream Petroleum Regulatory Commission (NUPRC). (2025). Host Community Fund rises to

₦373 billion as NUPRC oversees 536 projects, 13 October 2025.

Nigerian Upstream Petroleum Regulatory Commission (NUPRC). (2026). National annual petroleum reserves position as at 1 January 2026, 1 April 2026.

Nigerian National Petroleum Company Limited (NNPC Limited). (2025). NNPC Limited declares ₦5.4 trillion profit after tax: Full-year 2024 results, 24 November 2025.

United Nations Environment Programme, Law and Environment Assistance Platform. (2021-2024).

Petroleum Industry Act No. 6 of 2021 and implementing petroleum regulations.

International Energy Agency. (2022). Nigeria Petroleum Industry Act: Policy summary.

Petroleum Industry Act Implementation Committee. (2021). Petroleum Industry Act portal and implementation materials.

Author’s note: This article is a condensed policy and governance assessment prepared for professional publication. Numerical and institutional claims should be checked against the latest official releases immediately before final submission to a journal or policy platform.