Petroleum Industry Act (PIA) 2021: Full Breakdown of Regulations Every Nigerian Oil & Gas Professional Must Know

The Petroleum Industry Act 2021 is the most significant piece of legislation ever to reshape Nigeria's oil and gas sector. Signed into law on 16 August 2021 by President Muhammadu Buhari, the PIA ended a 20-year legislative journey and overhauled everything — from how the sector is governed and taxed, to how host communities are treated and how licences are issued. Nearly five years since its enactment, the PIA continues to define the operating landscape for every professional in Nigeria's energy industry.

This is your definitive guide.

What the PIA Set Out to Achieve

The PIA was designed to do five things simultaneously: create efficient governing institutions, commercialise the state oil company, establish a transparent fiscal framework, protect host communities, and foster a business environment that attracts sustained investment. It does all of this through five chapters, 319 sections, and eight schedules — making it the most comprehensive piece of energy legislation in Nigeria's history.

1. The New Regulatory Architecture: Two Agencies Replace One

Before the PIA, Nigeria's petroleum sector was regulated primarily by the Department of Petroleum Resources (DPR), a single agency overseeing everything from upstream exploration to downstream distribution. The PIA abolished this structure and replaced it with two distinct, specialised regulators.

Nigerian Upstream Petroleum Regulatory Commission (NUPRC) The NUPRC took over all upstream functions previously held by the DPR. It is responsible for licensing, reserves management, technical regulation, acreage management, cost benchmarking, and enforcing host community and environmental obligations across exploration and production operations. Since its establishment, NUPRC has gazetted several key regulations including the Upstream Petroleum Decommissioning and Abandonment Regulations (2023), the Host Communities Development Regulations (2022), and the Gas Flaring, Venting and Methane Emissions Regulations (2023).

Nigerian Midstream and Downstream Petroleum Regulatory Authority (NMDPRA) The NMDPRA regulates everything from crude oil transportation and storage to refining, distribution, and marketing of petroleum products. It took over the commercial functions of the defunct Petroleum Products Pricing Regulatory Agency (PPPRA), and oversees pricing, quality assurance, and supply reliability. The PIA also enshrined the deregulation of petroleum product prices into law under the NMDPRA's oversight framework.

What this means for professionals: Regulatory interactions that previously flowed through a single agency are now split. Upstream operators interface primarily with NUPRC; midstream and downstream operators work with NMDPRA. Knowing which regulator governs your operations is now a fundamental compliance requirement.

2. NNPC Limited: The End of the Old NNPC

One of the most consequential changes under the PIA is the transformation of the Nigerian National Petroleum Corporation into NNPC Limited — an independent commercial entity governed by the Companies and Allied Matters Act (CAMA). This removed NNPC from the constraints of the Treasury Single Account, Public Procurement Act, and Fiscal Responsibility Act, allowing it to operate as a profit-driven business.

Ownership of NNPC Limited is vested in the Federal Government, with shares held by the Ministries of Finance and Petroleum on behalf of the government. Critically, the PIA mandates that 30% of NNPC Limited's profits be channelled into the Frontier Exploration Fund, dedicated to oil and gas exploration in Nigeria's less-explored basins. An additional 10% of rents from petroleum prospecting and mining licences also feeds into this fund.

The PIA also provides that NNPC Limited earns a 10% management fee on the proceeds of profit oil and profit gas — a structural incentive for commercial performance rather than bureaucratic function.

3. Licences and Leases: A New Classification System

The PIA abolished the old Oil Prospecting Licence (OPL) and Oil Mining Lease (OML) framework for new entrants and replaced it with three new instruments:

• Petroleum Exploration Licence (PEL): For early-stage exploration activities
• Petroleum Prospecting Licence (PPL): For companies advancing toward development
• Petroleum Mining Lease (PML): For full production operations

All three may only be granted to companies incorporated in Nigeria and are subject to work programme obligations, fiscal terms, and regulatory compliance. Existing OPL and OML holders were given the option to convert to the new licence types — but conversion is not mandatory. Holders who do not convert retain the terms of the old Petroleum Act for the duration of their existing licences.

The NUPRC has power to grant PELs, while the Minister of Petroleum Resources retains authority over PPLs and PMLs.

4. The New Fiscal Framework: What It Means for Your Tax Position

Chapter 4 of the PIA introduced the most sweeping changes to Nigeria's petroleum tax regime in decades. Every upstream professional and finance team needs to understand these changes:

Hydrocarbon Tax (HCT) A new Hydrocarbon Tax applies to profits from crude oil production at progressive rates ranging from 15% to 30%, administered by the Federal Inland Revenue Service (FIRS). This runs alongside the existing Corporate Income Tax (CIT) at 30% and Education Tax at 2%. A 65% cap on the cost-to-revenue ratio applies for HCT purposes to prevent excessive deductions.

Royalties Royalty rates are now structured in two tiers — based on production rate and oil price — ranging from 5% to 15% for oil, and 5% for gas exports or 2.5% for domestic gas supply. Importantly, there is no price-based royalty for gas or frontier acreages, an incentive designed to encourage gas development and frontier exploration.

Production Allowances The old system of Investment Tax Credits and Investment Tax Allowances has been replaced by Production Allowances — a deliberate shift to reward output rather than capital expenditure. This changes the investment calculus for project planning across the sector.

Cost Efficiency Incentives In May 2025, President Tinubu signed the Upstream Petroleum Operations (Cost Efficiency Incentives) Order, which ties tax relief directly to cost-efficiency benchmarks. Operators who outperform these benchmarks can reclaim a portion of government gains — a significant incentive for operational excellence.

5. Host Community Development Trust Fund (HCDTF)

The PIA fundamentally resets the relationship between the oil industry and the communities it operates in. Every upstream licence holder is now legally required to establish a Host Community Development Trust (HCDT) and make an annual contribution equal to 3% of its operating expenditure from the previous year.

The allocation of these funds is specified in the law: 75% for capital projects, 20% for reserves, and 5% for administrative expenses. Where vandalism or sabotage occurs, the affected community forfeits the cost of repairs — a mechanism designed to align community interests with infrastructure protection.

As of mid-2024, over 167 HCDTs had been incorporated. However, compliance remains incomplete — nearly 30% of upstream licence holders had yet to establish their required trusts, highlighting an ongoing enforcement challenge that professionals in legal, compliance, and community relations roles must monitor closely.

6. Gas Sector Provisions: The Domestic Gas Obligation

The PIA codifies Nigeria's commitment to domestic gas utilisation. Under the Domestic Gas Delivery Obligation (DGDO), holders of PMLs and gas processing licences are required to prioritise gas supply to the domestic market before exporting. This is a significant compliance obligation for gas producers and processors.

The PIA also established the Midstream and Downstream Gas Infrastructure Fund, funded by a 0.5% levy on wholesale petroleum products and natural gas revenues. Gas flare penalties collected from midstream operators are also credited to this fund, earmarked for domestic gas infrastructure investment.

Where the PIA Stands in 2026

Five years since enactment, the PIA's impact is measurable. Nigeria approved 28 new field development plans in 2025 alone, mobilising $18.2 billion in upstream investment. Production has rebounded to approximately 1.6–1.7 million barrels per day — a significant recovery from lows below 1.2 million bpd in the pre-reform period. International oil companies are re-engaging deepwater assets, and indigenous operators are expanding their portfolios.

That said, full implementation remains a work in progress. Host community trust compliance gaps, ongoing pipeline security challenges, and the need for stronger regulatory enforcement capacity are areas professionals must continue to watch.

Key Takeaways for Oil & Gas Professionals

The PIA 2021 is not background knowledge — it is the operating manual for Nigeria's petroleum sector. Whether you work in upstream exploration, midstream infrastructure, downstream distribution, legal compliance, project finance, or community relations, the PIA directly governs your work. Staying current with its regulations, the subsidiary instruments being issued by NUPRC and NMDPRA, and the executive orders layered on top of it by the Tinubu administration is not optional — it is professional necessity.