African oil-producing countries are sharpening their focus on marginal fields as they seek new avenues to strengthen energy security, boost domestic supply and stimulate economic growth. The strategy is gaining momentum in Nigeria, where indigenous firm Energy Transfer HS recently acquired a 48% working interest in the Kugbo West Marginal Gas Field, an investment that underscores the growing commercial viability of smaller, underdeveloped hydrocarbon assets.
The agreement, signed on December 8 with Prime Horizon Energy as technical partner, commits $120 million over two years to drilling, capacity expansion and infrastructure upgrades. These efforts support Nigeria’s broader policy objective to increase affordable natural gas availability for power generation, industry and households, key to meeting the country’s rising energy demand.
Across Africa, marginal fields are increasingly viewed as strategic opportunities. Though typically smaller or previously uneconomic, these deposits can be rapidly brought into production at lower cost and with fewer technical barriers than frontier megaprojects. By integrating them into national energy strategies, governments are able to supplement output from large fields, stabilize domestic supply and create new revenue streams.
To attract capital to these assets, several African states have introduced targeted fiscal and regulatory reforms. In Nigeria, marginal fields have contributed more than 2% of national crude supply since their introduction in 2003. The Petroleum Industry Act modernized the sector by clarifying licensing terms, streamlining royalties and boosting transparency, all essential to investor confidence. Annual bid rounds now include legacy and undeveloped acreage, creating openings for both indigenous and international players.
Additional incentives arrived with the 2025 Upstream Petroleum Operations Cost Efficiency Incentives Order, which grants tax credits of up to 20% of annual tax liability to operators achieving verified cost reductions. By lowering operating expenditure, the policy directly improves the economics of smaller and technically challenging fields.
Angola is following a similar trajectory. The National Oil, Gas and Biofuels Agency included five marginal fields in its 2025 bid round, prioritizing prospects located near existing infrastructure to reduce capital outlay. Angola has also maintained favorable fiscal terms, cutting Petroleum Production Tax and Petroleum Income Tax for marginal operations, to draw a diverse pool of investors and stimulate exploration of overlooked reservoirs.
Policies targeting marginal acreage are helping shift ownership and operational capacity toward domestic firms. Historically, smaller discoveries were undeveloped for decades under the portfolios of IOCs. By opening these assets to local operators, governments are promoting skills transfer, building local content and expanding indigenous participation in upstream activities.
Marginal field development is also driving new infrastructure. In June 2025, Nigeria’s Green Energy International completed the Otakikpo onshore terminal in Rivers State, lifting its first crude cargo shortly thereafter. With capacity to handle up to 250,000 barrels per day from third-party producers, the terminal is poised to unlock stranded volumes from more than 40 marginal fields, offering a long-awaited alternative to costly evacuation routes and strengthening overall supply resilience.
As global energy markets tighten, African oil and gas producers stand to benefit by scaling marginal field development across borders. Shared infrastructure, coordinated licensing and pan-African technical partnerships could help maximize investment efficiency while reinforcing regional energy integration. By prioritizing marginal fields, African countries can enhance domestic production, support industrial growth and advance energy security, laying the groundwork for a more resilient and sustainable energy future.
Source: energycapitalpower.com