Nigeria's Upstream Decommissioning & Abandonment Regulations 2026, Commercial, Contracting & Dispute Risks

Nigeria’s upstream oil and gas sector entered a new regulatory era when the Nigerian Upstream Petroleum Regulatory Commission (NUPRC) brought into force the Upstream Decommissioning & Abandonment Regulations 2026, fundamentally reshaping the decommissioning regulations Nigeria applies to ageing offshore and onshore assets. These Regulations operationalise the decommissioning framework established under the Petroleum Industry Act 2021 (PIA) by imposing prescriptive operator duties, mandatory cost-security instruments, and a structured approval pathway that directly affects how sponsors, lenders and contractors allocate risk. For in-house counsel, project financiers and EPC firms, the commercial consequences are immediate: existing joint operating agreements (JOAs), production sharing contracts (PSCs), finance documents and engineering contracts must now be stress-tested against a materially tighter compliance baseline.

This guide translates the new regime into a practical playbook, covering obligations, liability allocation, contract drafting, lender protections and dispute resolution, designed for practitioners advising on Nigerian upstream projects in 2026 and beyond.

Executive Summary, What Changed and Immediate Commercial Actions

The 2026 Upstream Decommissioning & Abandonment Regulations require every licence or lease holder to prepare, fund and execute a decommissioning plan approved by NUPRC before ceasing production, transferring an asset or surrendering a licence. The Regulations mandate specific cost-security instruments, introduce detailed environmental remediation obligations, and create an enforcement architecture with regulatory penalties that sit outside the scope of contractual arbitration clauses. Industry observers expect these changes to trigger a wave of contract renegotiations, revised lending covenants, and fresh dispute-resolution planning across the Nigerian upstream sector.

Five immediate actions for deal teams:

1. Deal-freeze audit. Review every pending acquisition, divestment or farm-in to determine whether the 2026 Regulations impose new pre-completion approval requirements or financial assurance obligations that were not contemplated at heads-of-terms stage.
2. Lender covenant review. Assess whether existing reserve-based lending (RBL) and project finance facilities contain decommissioning cost covenants adequate to satisfy the Regulations’ security requirements; if not, negotiate covenant amendments immediately.
3. Update JOAs and EPCs. Insert change-in-law clauses, decommissioning cost-sharing mechanisms and regulatory approval conditions that specifically reference the 2026 Regulations.
4. Confirm financial security. Determine whether the required decommissioning security bonds, escrow accounts or letters of credit are in place or need to be established.
5. Nominate a dispute route. Distinguish between contractual disputes (arbitrable) and regulatory enforcement actions (non-arbitrable) and update dispute-resolution clauses accordingly.

Legal and Regulatory Framework, From the PIA to the 2026 Decommissioning Regulations Nigeria

Understanding the decommissioning regulations Nigeria now applies requires tracing a three-layer statutory hierarchy: the enabling statute (PIA 2021), early subordinate legislation (the 2023 Midstream and Downstream Petroleum Operations Regulations), and the 2026 Upstream Decommissioning & Abandonment Regulations themselves.

Scope and Definitions

The PIA defines “decommissioning” as the process of safely ceasing operations and removing or securing upstream petroleum installations, including wellheads, platforms, pipelines, flowlines and ancillary infrastructure. “Abandonment” refers specifically to the permanent closure and securing of wells so that they pose no future environmental or safety hazard. The 2026 Regulations adopt and expand these PIA definitions, adding detailed requirements for partial decommissioning (leaving structures in situ where justified by environmental assessment) and phased abandonment programmes.

The Regulations apply to all upstream petroleum operations conducted under licences, leases and permits granted under the PIA or its predecessor legislation (the Petroleum Act, the Deep Offshore and Inland Basin Production Sharing Contracts Act, and related instruments). This scope captures both onshore and offshore installations across the Niger Delta, deepwater blocks and frontier basins.

Commencement and Retroactivity

The Regulations were gazetted in the Federal Republic of Nigeria Official Gazette and took effect in 2026. A critical feature for practitioners is that the Regulations are not purely prospective: they require existing licence and lease holders, including those operating under legacy concessions, to submit decommissioning plans within prescribed timescales. The likely practical effect is that operators with mature or declining fields must begin the decommissioning-plan preparation process immediately, even if cessation of production is years away.

Overlap With the PIA

The PIA’s decommissioning provisions (particularly Sections 232 and 233, which establish the general duty to decommission and create the regulatory power to prescribe standards) provide the enabling framework. Section 318 of the PIA further supports the Commission’s power to make regulations of this kind. The 2026 Regulations fill the procedural and enforcement gaps left by the PIA’s high-level provisions, creating a self-contained compliance code that operators must follow from plan submission through to final site certification.

Operator Decommissioning Obligations, Approvals and Timelines Under the 2026 Regulations

The operator decommissioning obligations imposed by the 2026 Regulations are the most detailed ever applied to Nigerian upstream operations. At their core, the Regulations require every licensee or leaseholder to prepare a comprehensive decommissioning plan, secure NUPRC approval before commencing any decommissioning activity, and provide evidence of adequate financial security.

Decommissioning Plan Content

The Regulations prescribe minimum content for every decommissioning plan, including:

• Asset inventory. A full register of installations, wells, pipelines and associated infrastructure subject to decommissioning.
• Technical methodology. Detailed description of removal, plugging and abandonment techniques, including well-integrity assessments.
• Environmental impact assessment (EIA). An EIA or environmental evaluation report addressing seabed/site restoration, waste management, and any proposal for partial leaving-in-place of structures.
• Cost estimate. An independently verified estimate of total decommissioning costs, updated at prescribed intervals.
• Financial assurance. Evidence of security instruments (bonds, escrow, letters of credit or parent guarantees) sufficient to cover the estimated costs.
• Stakeholder engagement. Documentation of consultation with host communities, state governments and relevant federal agencies.
• Timeline and phasing. A detailed project schedule with milestones for each phase of decommissioning and abandonment.

Approval Process and Timelines

The Regulations establish a structured multi-stage approval process:

Ongoing Reporting and Environmental Liabilities

Operators must submit periodic progress reports to NUPRC during the decommissioning process, including updated cost estimates and evidence that financial security remains adequate. Environmental remediation obligations survive the physical completion of decommissioning works: the Regulations require ongoing monitoring and, where contamination is discovered post-completion, additional remediation at the operator’s cost. Early indications suggest that NUPRC will apply these provisions strictly, particularly in the ecologically sensitive Niger Delta region.

Decommissioning Liability Nigeria, Who Pays and When

Allocating decommissioning liability Nigeria-wide is one of the most commercially consequential aspects of the 2026 framework. The Regulations create a layered liability structure that practitioners must map carefully against their contractual arrangements.

Statutory Liability

Under the PIA and the 2026 Regulations, the primary statutory duty to decommission rests with the licensee or leaseholder, typically the operator. This liability is non-delegable: even where the operator subcontracts decommissioning works to an EPC contractor, the licensee remains responsible to NUPRC for compliance. Where multiple parties hold interests under a joint venture, the Regulations contemplate that each participant bears liability proportionate to its participating interest, though the operator retains primary regulatory accountability.

JOA and PSC Allocation Patterns

In practice, decommissioning cost allocation under JOAs and PSCs is governed by the contractual cost-sharing provisions negotiated between the parties. Under most Nigerian JOAs, the operator conducts decommissioning on behalf of the joint venture and recovers costs from non-operating parties in proportion to their participating interests. Under PSCs, the allocation is more complex: the contractor group typically bears the initial cost, which may be recoverable under the cost-recovery mechanism, but the 2026 Regulations’ requirement for pre-funded security instruments may limit the extent to which parties can defer cost exposure.

Contractor Indemnities and Limits

EPC and decommissioning contractors face limited direct regulatory liability unless they are named as licensees. However, their contractual exposure can be substantial. Operators routinely require contractors to provide indemnities for defective decommissioning works, environmental damage caused during the decommissioning process, and failure to meet regulatory standards. Contractors should negotiate aggregate liability caps, exclusions for consequential loss, and carve-outs for regulatory fines imposed on the licensee for matters outside the contractor’s scope of work.

Financing Implications, Decommissioning Security Bonds and Lender Decommissioning Protections

The 2026 Regulations fundamentally alter the risk calculus for lenders to Nigerian upstream projects. Before advancing funds, financiers must now satisfy themselves that decommissioning security bonds or equivalent instruments are in place and that the borrower’s decommissioning cost estimates are independently verified and regularly updated.

Types of Cost Security

The Regulations contemplate several forms of financial assurance:

• Decommissioning security bonds. Issued by a bank or insurance company in favour of NUPRC, callable if the operator fails to perform decommissioning obligations.
• Escrow accounts. Ring-fenced cash deposits that accumulate over the producing life of the asset, sized to match updated cost estimates.
• Letters of credit. Standby or documentary letters of credit from acceptable issuing banks, providing on-demand payment to fund decommissioning if the operator defaults.
• Parent company guarantees. Corporate guarantees from creditworthy parent entities, subject to NUPRC acceptance of the guarantor’s financial standing.
• Insurance products. Specialist decommissioning insurance policies where available in the Nigerian or international market.

Lender Covenants and Step-In Rights

Lenders providing reserve-based lending, project finance or corporate facilities to upstream operators should consider including the following covenant protections in their finance documents:

• Decommissioning cost covenant. Require the borrower to maintain financial security equal to a specified percentage of the independently estimated decommissioning cost at all times.
• Periodic cost-estimate testing. Mandate annual (or more frequent) updates to decommissioning cost estimates, with independent verification by a qualified engineering firm.
• Regulatory compliance undertaking. Require the borrower to comply with all obligations under the 2026 Regulations and promptly notify the lender of any NUPRC enforcement action or plan rejection.
• Step-in rights. Reserve the right for the lender (or its nominee) to step in and perform decommissioning obligations if the borrower defaults, protecting the security package from regulatory impairment.
• Intercreditor priority. Clarify the ranking of decommissioning security against other secured creditors, particularly where escrow funds or bonds form part of the broader security pool.

Independent Cost Verification

The Regulations require decommissioning cost estimates to be independently verified. Lenders should insist on appointing, or approving, the independent verifier, and should require direct access to the verification reports. Discrepancies between operator estimates and independent assessments should trigger an obligation to top up financial security within a defined cure period.

Oil and Gas Decommissioning Contracts, JOA, PSC, EPC, SPA and Transfer Clauses

The 2026 Regulations demand that every major category of oil and gas decommissioning contract used in the Nigerian upstream sector be reviewed and, in most cases, materially amended. The following drafting guidance addresses the key contract types.

JOA and PSC Clause Redlines

Existing JOAs and PSCs should be updated to include:

• Change-in-law provisions. Explicitly reference the 2026 Regulations as a change-in-law event that triggers renegotiation of cost-sharing, security and approval obligations.
• Decommissioning cost-sharing mechanism. Define each participant’s share of decommissioning costs by reference to participating interest (JOA) or cost-recovery entitlements (PSC), with provisions for default by a non-paying party.
• Pre-funded security obligation. Require each participant to contribute to a decommissioning fund or provide individual security proportionate to its interest.
• Regulatory approval condition. Make commencement of decommissioning conditional on NUPRC approval, with the operator bearing the obligation to obtain approval and non-operators bearing the cost of compliance.

EPC Scope and Acceptance Tests

EPC contracts for decommissioning works should define scope by reference to the approved NUPRC decommissioning plan and should include:

• Regulatory compliance obligation. Require the contractor to perform works in accordance with the approved plan, all applicable NUPRC directives, and the environmental standards specified in the Regulations.
• Acceptance and certification. Link final acceptance (and release of retention) to NUPRC certification that decommissioning has been completed in accordance with the approved plan.
• Defects liability period. Extend the contractor’s liability for defective works to cover any post-completion remediation required by NUPRC.

Assignment and Transfer Protections

SPAs and farm-out agreements for upstream assets must now address:

• Decommissioning liability assumption. The buyer or farmee should expressly assume all decommissioning obligations under the 2026 Regulations, with the seller retaining a residual indemnity for pre-transfer environmental liabilities.
• NUPRC transfer approval. Include a condition precedent requiring NUPRC consent to the transfer, including confirmation that the incoming party has provided adequate financial security for decommissioning.
• Escrow and holdback. Consider holding a portion of the purchase price in escrow pending NUPRC confirmation that the buyer’s decommissioning plan and financial security meet regulatory requirements.
• Novation of security instruments. Require the buyer to novate or replace any existing decommissioning security bonds or escrow arrangements within a specified period post-completion.

Sample Clause Bank

The following illustrative clause snippets reflect the kinds of provisions that industry observers expect to become standard in Nigerian upstream contracts under the 2026 regime:

• Decommissioning cost contribution (JOA). “Each Participant shall contribute to the Decommissioning Fund in proportion to its Participating Interest. The Operator shall establish and maintain the Decommissioning Fund in accordance with the Approved Decommissioning Plan and the Regulations.”
• Change-in-law adjustment. “In the event that the Regulations impose obligations not contemplated at the Effective Date, the Parties shall negotiate in good faith to amend this Agreement to reflect such obligations within [60] days of the relevant Regulation taking effect.”
• Lender step-in (finance document). “If a Decommissioning Default occurs, the Lender may (but shall not be obliged to) step in and perform or procure the performance of the Borrower’s decommissioning obligations, and all costs incurred shall be recoverable from the Borrower as a Secured Obligation.”
• Seller’s residual indemnity (SPA). “The Seller shall indemnify the Buyer against all Losses arising from Pre-Transfer Environmental Liabilities, including any decommissioning or remediation obligations attributable to the period prior to the Transfer Date.”
• Contractor regulatory compliance (EPC). “The Contractor shall perform the Works in compliance with the Approved Decommissioning Plan, all applicable NUPRC directives, and the environmental standards specified in the Regulations. Failure to achieve NUPRC certification shall constitute a material breach.”
• Security replacement on transfer (SPA). “Within [30] days of Completion, the Buyer shall procure the issuance of replacement Decommissioning Security in favour of NUPRC, in form and substance satisfactory to the Commission, and shall procure the release of the Seller’s existing Security.”

Decommissioning Arbitration Nigeria, Dispute Resolution and Enforcement

The interaction between contractual arbitration and regulatory enforcement is one of the most nuanced aspects of the decommissioning regulations Nigeria has introduced. Practitioners must draw a clear distinction between disputes that can be arbitrated and regulatory decisions that must be challenged through administrative or judicial channels.

Arbitration Validity and Jurisdictional Challenges

Contractual disputes between JOA participants, between operators and contractors, or between buyers and sellers over the allocation of decommissioning costs, indemnity obligations, or breaches of contractual warranties remain arbitrable under Nigerian law and international arbitration rules (including ICSID, ICC and LCIA, depending on the governing law and arbitration clause). Nigeria is a signatory to the New York Convention on the Recognition and Enforcement of Foreign Arbitral Awards, and Nigerian courts have generally upheld the validity of arbitration clauses in upstream petroleum contracts.

However, decommissioning arbitration Nigeria practitioners must recognise that certain matters fall outside the scope of arbitration. Regulatory decisions by NUPRC, including approval or rejection of decommissioning plans, imposition of penalties for non-compliance, and directives requiring additional environmental remediation, are administrative acts that must be challenged through judicial review in the Federal High Court, not through arbitration.

Regulatory Enforcement and Penalties

The 2026 Regulations empower NUPRC to impose penalties for failure to submit a decommissioning plan, failure to provide adequate financial security, commencement of decommissioning without approval, and failure to comply with an approved plan. Industry observers expect that the level of penalties will be substantial and that NUPRC will adopt an active enforcement posture, particularly in respect of legacy assets that have been neglected by departing international operators.

Interim Relief and Injunctions

Where an operator faces simultaneous regulatory enforcement and contractual disputes, the question of interim relief becomes critical. Arbitral tribunals may grant interim measures (such as preservation of escrow funds or continuation of security instruments) pending final resolution, while the Federal High Court retains jurisdiction to grant injunctive relief against NUPRC enforcement actions where the operator can demonstrate that the regulatory decision was made in excess of jurisdiction or in breach of natural justice.

The recommended approach is to include in all relevant contracts a dispute-escalation clause that distinguishes clearly between regulatory matters (to be handled through administrative engagement with NUPRC, followed by judicial review if necessary) and contractual matters (to be referred to arbitration).

Practical Risk Allocation Checklist and Due-Diligence Matrix

The following checklist consolidates the key risk items that sponsors, lenders and contractors should address in connection with decommissioning regulations Nigeria now imposes on upstream operations.

Pre-Completion Due Diligence

• Confirm the existence and adequacy of any submitted or approved decommissioning plan.
• Obtain copies of all NUPRC correspondence regarding decommissioning obligations for the target asset.
• Review the current decommissioning cost estimate and the date of last independent verification.
• Identify all financial security instruments in place (bonds, escrow, LCs, guarantees) and confirm their terms, expiry dates and assignability.
• Assess environmental liabilities through an independent environmental audit, including contamination, remediation obligations and pending regulatory enforcement.
• Review the relevant JOA, PSC or licence terms for decommissioning cost-sharing, change-in-law and transfer provisions.

Post-Completion Monitoring

• Establish a periodic review cycle (quarterly or semi-annually) for decommissioning cost estimates and security adequacy.
• Monitor NUPRC guidance, directives and enforcement actions for developments affecting the asset.
• Maintain ongoing compliance with reporting obligations under the 2026 Regulations.
• Test financial security against updated cost estimates and top up if required.

Template Risk Register

Conclusion, Immediate Next Steps for Counsel, Sponsors and Lenders

The decommissioning regulations Nigeria adopted in 2026 represent the most significant regulatory intervention in the country’s upstream petroleum decommissioning landscape since the PIA was enacted in 2021. The Regulations create binding obligations that cannot be deferred or managed through informal regulatory engagement alone. Every participant in the Nigerian upstream sector, from major international operators to indigenous companies, from development finance institutions to EPC contractors, must now take concrete steps to align contractual, financial and operational arrangements with the new regime.

Five immediate next steps:

1. Audit all existing JOAs, PSCs, finance documents and EPC contracts against the 2026 Regulations and identify gaps in decommissioning provisions.
2. Commission independent decommissioning cost estimates for all operated and non-operated assets and ensure these are updated to reflect current regulatory requirements.
3. Establish or top up decommissioning security instruments (bonds, escrow, letters of credit) to meet the financial assurance thresholds imposed by the Regulations.
4. Engage NUPRC proactively, submit preliminary decommissioning plans for mature or declining assets before the regulatory deadline to avoid enforcement action.
5. Update dispute-resolution clauses to distinguish clearly between arbitrable contractual disputes and non-arbitrable regulatory enforcement matters.

Practitioners who act early will secure a significant advantage, both in regulatory compliance and in commercial negotiations with counterparties. For guidance on Nigeria’s upstream decommissioning obligations, find a qualified Nigeria commercial lawyer through Global Law Experts.

Sources

1. Federal Republic of Nigeria, Official Gazette (Upstream Decommissioning & Abandonment Regulations)
2. Templars, Nigeria’s Upstream Decommissioning & Abandonment Regulations 2026
3. SSRN, Decommissioning and Abandonment (Academic Analysis)
4. BudgIT Foundation, Oil & Gas Policy Brief (2026)
5. Advocaat Law Practice, Legal Framework for Decommissioning in Nigeria
6. Stakeholder Democracy Network, Sustainable Closure and Decommissioning of Oil and Gas Assets in Nigeria
7. AO2Law, Exit but at What Cost: Decommissioning and Environmental Risks in Nigeria’s Petroleum Sector Divestments