Industrial Policy & Trade Monitor· 2666 actions· ✨ 90 recent

On 13 February 2026 President Bola Ahmed Tinubu signed Executive Order No. 9 of 2026 directing all Production Sharing Contract operators and contractors to remit Royalty Oil, Tax Oil, Profit Oil, and Profit Gas directly to the Federation Account, bypassing prior NNPC Limited intermediated collection. The order simultaneously eliminates NNPC Limited's 30% management fee on profit oil/gas, suspends the 30% Frontier Exploration Fund deduction, and redirects Gas Flare Penalty proceeds to the Federation Account — materially walking back the fiscal architecture established under Petroleum Industry Act 2021 §§ 9 and 53. An Implementation Committee chaired by the Minister of Finance was established to operationalise the order and resolve disputes.

President Bola Ahmed Tinubu signed the Upstream Petroleum Operations (Cost Efficiency Incentives) Order, 2025 on 29 May 2025, introducing a performance-based tax-credit framework for upstream oil and gas operators who beat NUPRC-set Unit Operating Cost benchmarks. Eligible lessees, licensees, and PSC contractors receive tax credits capped at 20% of their annual petroleum tax liability per licence area, applied against Petroleum Profits Tax, Hydrocarbon Tax, or Companies Income Tax. The Nigerian Upstream Petroleum Regulatory Commission (NUPRC) conducts annual terrain-specific (onshore, shallow-water, deep-offshore) Unit Operating Cost benchmarking, and the Federal Inland Revenue Service (FIRS) co-administers with claw-back provisions for non-compliance; the regime runs through 31 May 2035.

The National Upstream Petroleum Local Content Policy (NUPLCP), approved by Namibia's Cabinet in December 2024 and finalised by the Ministry of Mines and Energy in March 2025, requires all upstream petroleum operators to submit Local Content Plans detailing Namibian workforce hiring, skills transfer, and local supplier engagement commitments as a condition of exploration and production licences. The policy is the primary industrial-policy instrument governing Namibia's nascent offshore oil sector, targeting the Orange Basin deepwater blocks (PEL 39, PEL 56, PEL 83, PEL 85, PEL 90, PEL 91) where Shell, TotalEnergies, Galp, Chevron, ExxonMobil, and QatarEnergy have confirmed ~11+ billion barrels of recoverable resource with a 2027–2029 FID horizon and projected peak output of ~700 kbpd by 2030+. Enforcement is initially guidance-based with a dedicated monitoring framework under development; critics note weak enforcement infrastructure as the principal implementation risk.

Oman published its national Green Hydrogen Strategy in May 2024 (with an updated December 2024 release), formalising statutory production targets of 1.0-1.5 Mtpa green hydrogen by 2030, 3.25-3.75 Mtpa by 2040, and 7.5-8.5 Mtpa by 2050. Implementation is centralised in Hydrom (Hydrogen Development Oman), the wholly state-owned subsidiary of Energy Development Oman established in 2022 as the singular allocation authority for green- hydrogen master-planning, land tendering and developer concessions. Approximately 50,000 km² of state land in Duqm, Dhofar and Al Jazir is earmarked under the regime, sufficient to host ~95-100 GW of electrolyser capacity and ~175-185 GW of renewable build-out by 2050. The strategy underpins the ~USD 11bn Round-2 Dhofar awards announced April 2024 and positions Oman as a structural offtake supplier to EU/JP/KR hydrogen importers under the EU Renewable Energy Directive III non-bio renewable fuel of non-biological origin (RFNBO) framework and the Japan Hydrogen Society Promotion Act CfD scheme.

On 28 February 2024 President Bola Ahmed Tinubu signed one executive order and two presidential directives to revive upstream oil and gas investment in Nigeria after years of declining FDI: (i) the Oil and Gas Companies (Tax Incentives, Exemption, Remission, etc.) Order, 2024 — establishing a gas tax credit for non-associated gas (NAG) greenfield projects and fiscal enablers for deep-water oil and gas; (ii) the Presidential Directive on Local Content Compliance Requirements, 2024 — instructing the NCDMB to adapt enforcement of the Local Content Act to in-country capacity gaps; and (iii) the Presidential Directive on Reduction of Petroleum Sector Contracting Costs and Timelines, 2024 — streamlining NUPRC and NNPCL contracting approvals. Effective immediately on signing.

On 27 December 2017 President Nursultan Nazarbayev signed Code No. 125-VI ZRK "On Subsoil and Subsoil Use," a wholesale recodification replacing the 2010 Subsoil Use Law that entered into force on 29 June 2018 (with certain provisions deferred to 1 January 2019). The Code establishes the licensing architecture for all mineral extraction in Kazakhstan — the world's leading uranium producer (~40% of global U₃O₈ output, ~22,000 tU/yr) and a top-11 oil exporter (~1.8 mbpd) — covering solid minerals, hydrocarbons, and uranium under a single codified framework. For solid minerals the Code introduces a liberalised "first-come first-served" auction-free licence model for non-strategic deposits and a state-tender model for strategic deposits, alongside subsoil-use rights transfer and pledge provisions governing all M&A in the sector. For uranium the Code codifies the National Atomic Company Kazatomprom's statutory role as state operator over all uranium blocks, with government priority pre-emption rights and mandatory Kazatomprom participation in all production licences. For hydrocarbons the Code establishes the concession and production-sharing framework governing the pre-salt Caspian mega-projects (Tengiz, Karachaganak, Kashagan) and the model contract architecture for petroleum products. Horizontal obligations — local Kazakh-content procurement floors, social-package requirements, and environmental-restoration mine-closure security — apply across all subsoil-use categories. Structurally this Code is the parent statute for every subsequently filed KZ action: the 2023-12-28 REE Comprehensive Plan and the 2025-12-26 Kazatomprom uranium-priority amendments both operate under delegated authority created by this Code.

Tanzania's Parliament enacted Act No. 5 of 2017, the Natural Wealth and Resources (Permanent Sovereignty) Act, as part of a landmark resource-nationalism legislative trio (alongside Act No. 6 on unconscionable contract renegotiation and Written Laws Miscellaneous Amendments No. 7), signed into law by President John Magufuli on 4 July 2017. The Act vests all of Tanzania's natural wealth and resources — minerals, oil and natural gas, fisheries, wildlife, forestry, water, and related sub-surface assets — as the permanent and inalienable property of the People of the United Republic, held in trust by the President on their behalf. Key operative provisions prohibit international commercial arbitration of natural-resource disputes (mandating adjudication within Tanzanian courts under Tanzanian law), empower Parliament to review and require renegotiation of any natural-resource arrangement containing "unconscionable terms," impose an in-country banking rule on earnings from natural wealth extraction, and authorise statutory override of contractual stabilisation clauses embedded in pre-2017 mining development agreements. The Act is the foundational parent statute underpinning all subsequent Tanzanian mining-sector reform, including the 2024 Written Laws (Miscellaneous Amendments) (No. 4) Act critical/strategic minerals classification and the 2025 Finance Act mining amendments.