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Nigeria has no law for biomethane. No statute, regulation, gazetted standard or regulator guideline explicitly names biomethane, compressed biogas, renewable gas or anaerobic digestion. A developer does not read a rulebook for the sector, because there isn't one. Instead you map the plant onto instruments written for fossil natural gas, industrial waste and foreign investment, and you flag the gaps as you go. Getting that mapping right is the whole game.

This is the single most important fact for anyone scoping a CBG project in Nigeria, and it is routinely missed in consultant reports that assume a renewable-gas framework exists. It does not. What follows is how the regulatory stack actually works, drawn from primary instruments and Redrock's live project experience in Ogun State.

Licensing: treat CBG as marketable natural gas

Once biomethane is upgraded to pipeline-quality specification and either injected or compressed for a CNG offtaker, it is treated as marketable natural gas. That puts the plant squarely in the midstream and downstream chapter of the Petroleum Industry Act 2021, administered by the Nigerian Midstream and Downstream Petroleum Regulatory Authority (NMDPRA).

The operative instrument is the Midstream and Downstream Petroleum Operations Regulations 2023. It defines the licence types a gas business needs: a gas processing licence, and then one of a wholesale gas supply licence, a retail gas supply licence or a gas distribution licence, depending on how the molecule reaches the customer. A CBG plant that compresses to CNG for road transport adds an Auto Gas Permit, issued through NMDPRA's automated gas systems platform, the same permit fossil-CNG stations use. There is no separate biogas operating licence to apply for. You apply under the natural-gas framework and the plant is assessed on the gas it produces, not the feedstock it consumes.

A practical consequence worth building into any commercial model: gas sold outside the PIA's strategic sectors, meaning outside power, gas-based industry and the commercial allocation, transacts on a willing-buyer willing-seller basis rather than at a regulated price. A CBG plant supplying an industrial fuel-switcher or a CNG retailer can therefore price commercially, which is what makes USD-denominated offtake structures viable.

A structural advantage hiding in the PIA

The PIA's Host Community Development Trust obligation, at section 235, requires a settlor to contribute 3% of the prior year's operating expenditure to a community trust. A settlor is defined as the holder of an upstream petroleum interest, a licence or lease. A compressed biogas plant fed on organic waste holds no upstream interest. On a plain reading it is not a settlor and not obliged to form a Host Community Development Trust. That is a genuine structural cost advantage over upstream gas projects. It should be confirmed with Nigerian counsel before it is relied on, but it is the kind of insight that only surfaces when you read the Act rather than assume the sector has its own rules.

Environmental approval: two regulators, in sequence

The plant is assessed as an industrial waste and gas-processing facility, not as a renewable-energy project. Two federal bodies matter.

Project-level assessment runs under the Environmental Impact Assessment Act (Cap E12), administered by the Federal Ministry of Environment. Projects are screened into three categories; a CBG plant of meaningful scale will most likely land in Category I or II given its combined waste-processing, gas-processing and emissions profile, triggering a full or partial EIA with mandatory public review. The pathway runs registration, screening, scoping, terms of reference, draft EIA, public and panel review, then an approval certificate.

Once built, operating permits come from the National Environmental Standards and Regulations Enforcement Agency (NESREA): air quality, water and effluent discharge, and waste handling, including how digestate is classified. No NESREA regulation names biogas or anaerobic digestion, so the plant complies as a generic industrial facility under the air-quality, water-quality and waste-control regulations.

Carbon revenue sits with the climate authority, not the gas regulator

If the project carries carbon revenue, that lives under the Climate Change Act 2021 and the National Council on Climate Change (NCCC), which acts as Nigeria's Designated National Authority for Paris Agreement Article 6. Monetising credits through an international transfer under Article 6.2 requires a Letter of Authorisation from the NCCC, issued case by case. Nigeria has issued its first such letter, to a clean-cooking programme, which sets the template. Methodology selection for an AD or biomethane project sits alongside this and should be scoped early, because it shapes both the revenue and the authorisation pathway.

The investor layer: incorporate, register, and protect repatriation

A foreign developer operates through a Nigerian company. The Companies and Allied Matters Act 2020 requires incorporation of a local entity before carrying on business; 100% foreign ownership is permitted at that level. The developer then registers with the Nigerian Investment Promotion Commission, and, critically, secures a Certificate of Capital Importation from its Nigerian bank for every capital inflow. That certificate is the gateway to repatriating dividends, loan service and sale proceeds. Without it, the transferability guarantee in the NIPC Act is a promise you cannot execute. Land is held through the local entity under the Land Use Act 1978 as a Right of Occupancy, with any transfer needing the state Governor's consent.

Investment incentives exist under Nigeria's tax and investment regime and are worth pursuing, but the specifics have moved recently and are best confirmed live with Nigerian tax counsel rather than taken from any secondary summary. This is an area where out-of-date advice is common and expensive.

The pathway that actually de-risks a Nigerian CBG project

Because so much is governed by analogy, the highest-value early move is not a filing. It is a set of free pre-application meetings that convert ambiguity into a documented position:

• NMDPRA, to confirm which licence types apply and to get the authority's position on treating biomethane as marketable natural gas.
• Federal Ministry of Environment, to fix the EIA category and negotiate the terms of reference.
• NCCC, if carbon revenue is in the stack, to map the Article 6 authorisation route.
• State lands and investment agencies, for the Certificate of Occupancy timeline and any one-stop investment-centre eligibility.

The absence of these meetings is the most common cause of delay to financial close on a Nigerian gas project. Built in from inception, they replace guesswork with a paper trail a lender can underwrite.

The bottom line

Nigeria is an attractive place to build compressed biogas, with strong demand pull from the national CNG push and a commercial pricing environment for gas sold outside the strategic sectors. But it has no biomethane rulebook. The developers who succeed are the ones who accept that, map their plant precisely onto the natural-gas, environmental and investment regimes, document the gaps, and lock down each regulator's position in writing before FID. That discipline, not a search for rules that do not exist, is what makes a Nigerian CBG project bankable.

Redrock Bioenergy develops and advises on compressed biogas and anaerobic digestion projects in Nigeria and across emerging markets. To discuss a project, contact info@redrockbioenergy.com.

This article is a strategic reference, not legal advice. Nigerian regulation is administered by analogy for biomethane and changes frequently; confirm any position with qualified Nigerian counsel before relying on it.