Nigeria’s Rig Activity Rises, But Ageing Oil Fields Keep Output Under Pressure

Nigeria’s renewed drilling activity is yet to translate into the kind of sustained crude oil production growth that would significantly strengthen government revenue, foreign-exchange earnings and the country’s position in the global oil market.

The latest figures point to a more complicated picture than simply a shortage of rigs. While drilling activity has continued over the years, a large portion of Nigeria’s producing base consists of mature fields whose output naturally declines unless operators commit substantial capital to new wells, workovers, artificial lift and enhanced oil recovery.

That challenge is becoming increasingly important as Nigeria tries to move production closer to the 2 million barrels-per-day mark.

More drilling, but not necessarily more barrels

Rig count is commonly used as an indicator of activity in the upstream petroleum industry. More rigs can mean more exploration, appraisal drilling, well development and maintenance.

However, a rig does not automatically produce a barrel of crude.

There can be a significant gap between drilling a well and bringing commercial production online. A project may also face geological challenges, infrastructure limitations, regulatory approvals, funding constraints, security problems or difficulties evacuating crude.

Data cited from OPEC in a recent industry report showed that Nigeria recorded a cumulative 2,099 rig deployments between 2016 and 2026. The reported annual high was 360 rigs in 2018, while 2021 recorded the lowest figure at 87.

The figures underline the scale of upstream activity, but they also raise a more important question: how much additional sustainable production has that activity actually created?

The answer is that Nigeria’s production performance has remained volatile rather than following a straight upward trajectory.

OPEC data recorded Nigeria’s crude production at about 1.737 million barrels per day in 2019, with monthly production around 1.734 million barrels per day in the first quarter of that year.

Production subsequently suffered major setbacks, including the effects of disruptions, maintenance, crude theft and infrastructure problems.

Nigeria is producing more again — but sustainability is the real test

There is, however, an important development that should not be overlooked.

Nigeria’s upstream sector has been recovering in 2026.

The Nigerian Upstream Petroleum Regulatory Commission (NUPRC) reported that crude oil production increased from 1.483 million barrels per day in February to 1.546 million in March, 1.663 million in April, 1.700 million in May and 1.56 million barrels per day of crude in June, while condensates brought the June combined figure to 1.735 million barrels per day. NUPRC described the June crude figure as a 74-month high.

The regulator has also previously said Nigeria reached a peak production level of 1.86 million barrels per day in May and has the potential to reach about 1.9 million barrels per day.

This means the central issue is not that Nigerian oil production has stopped improving.

Rather, the bigger question is whether the improvement can be maintained as older fields continue to decline.

Five mature fields reveal the pressure underneath the national numbers

Production data from NUPRC show how rapidly some individual mature assets are losing output.

Five fields highlighted in the industry report recorded an average combined decline of 20.8 per cent year-on-year in June 2026.

Field	June 2025	June 2026	Year-on-year change
Abo	11,297 bpd	6,870 bpd	-39.2%
Pennington	7,107 bpd	3,880 bpd	-45.0%
Ugo Ocha (Jones Creek)	32,246 bpd	26,900 bpd	-16.6%
Sea Eagle	15,886 bpd	14,570 bpd	-8.3%
Okwori	2,435 bpd	2,430 bpd	-0.2%

Together, the five fields averaged about 10,930 barrels per day in June 2026, compared with approximately 13,794 barrels per day a year earlier.

The figures demonstrate why national production can improve while individual assets simultaneously deteriorate.

A mature field is typically one that has moved beyond its peak production period. Reservoir pressure can weaken, water production can rise and existing wells can become less productive. Maintaining output therefore requires continuous technical and financial intervention.

Abo and Sea Eagle show what operators are facing

Abo, operated by Eni and its partners, has been producing since 2003. Its decline in June is therefore consistent with the challenges associated with a field that has been producing for more than two decades.

Eni has said production optimisation work is being undertaken on the deepwater asset, including upgrades to gas-compression equipment.

Sea Eagle, operated by Renaissance Africa Energy, has similarly been described as a mature asset whose production profile reflects its stage in the field life cycle.

Renaissance said it continues to evaluate measures aimed at optimising production and extracting additional value from the asset within approved development plans.

The responses illustrate an important point: declining production from mature fields is not necessarily evidence that operators have abandoned them. In many cases, the challenge is determining how much additional capital can economically be invested in assets that are already well into their productive lives.

Why Nigeria cannot rely on exploration alone

Nigeria has significant petroleum resources, but discovering or appraising hydrocarbons is only one stage of the production chain.

A commercially successful oil project must move through exploration, appraisal, development, drilling, infrastructure installation, production and crude evacuation.

That process can take years.

The country’s current upstream strategy is therefore increasingly focused on both new developments and maximising recovery from existing fields.

NUPRC said in August that 22 major offshore projects are expected between 2026 and 2030, with estimated investment potential of between $30 billion and $50 billion. The regulator also said it had approved more than $57 billion in Field Development Plans since 2024.

The Bonga North development is among the projects being highlighted by the regulator as an example of how improved regulatory certainty can help unlock major investment. NUPRC said the project progressed to a multi-billion-dollar Final Investment Decision following regulatory reforms and faster approvals.

These projects could provide new production capacity, but they will not eliminate the need to manage Nigeria’s existing fields.

Security and infrastructure remain part of the production equation

Oil production is also affected by what happens after crude is extracted from the reservoir.

Pipeline vandalism, crude theft, operational shutdowns and evacuation constraints can reduce effective production even when wells have the technical capacity to produce.

NUPRC said improved security and the absence of major pipeline outages contributed to stronger production performance in June 2026. The regulator has also been working with security agencies on measures to protect oil and gas infrastructure and improve production stability.

This means Nigeria’s production challenge is not purely a drilling problem.

It is simultaneously a reservoir, investment, infrastructure, security, regulatory and project-execution problem.

What happened to Nigeria’s position in OPEC?

Nigeria’s production remains far below its historical highs.

The country produced roughly 2.5 million barrels per day at its peak in 2005, according to historical production records, before years of disruptions, underinvestment, field decline and other constraints weakened output.

Nigeria’s comparatively lower production capacity also limits how much additional crude it can bring to the market when international prices are attractive.

However, Nigeria’s absence from a particular seven-country OPEC+ meeting should not by itself be interpreted as the country losing its membership or formal influence in OPEC+. The seven countries involved in that August production-adjustment decision were Saudi Arabia, Russia, Iraq, Kuwait, Kazakhstan, Algeria and Oman, reflecting their participation in the specific voluntary adjustment arrangement.

The broader issue for Nigeria is more straightforward: a country cannot fully benefit from its position in the global oil market if it lacks the production capacity to consistently supply the volumes available under its market arrangements.

The real opportunity may be beneath existing wells

For Nigeria, the next phase of oil growth may depend as much on getting more out of existing reservoirs as on discovering new ones.

Industry experts have pointed to measures such as:

• drilling additional wells within producing fields;
• re-entering selected abandoned or shut-in wells;
• well workovers;
• artificial-lift optimisation;
• enhanced oil recovery;
• faster approval of field development plans;
• improved crude evacuation infrastructure;
• stronger protection of oil installations; and
• faster commercial development of major new projects.

The Petroleum Industry Act already provides a regulatory framework governing upstream operations, while NUPRC’s mandate includes approving commercial aspects of field development plans and monitoring the economic performance of petroleum assets.

What Nigerians should watch next

The most important measure over the coming months will not simply be the number of rigs operating in Nigeria.

Investors, policymakers and Nigerians will need to watch whether drilling activity produces sustained additions to national crude output.

Three indicators will be particularly important:

First, production stability. Nigeria needs to maintain the gains recorded during the first half of 2026 rather than repeatedly moving between sharp increases and declines.

Second, mature-field recovery. If older assets continue losing production faster than new projects replace them, national output will remain vulnerable.

Third, project delivery. Major developments currently moving through Nigeria’s upstream pipeline must progress from approvals and investment decisions to actual first oil.

The country’s recent production recovery shows that higher output is possible. But the decline of mature fields demonstrates why maintaining that growth will require more than simply putting more rigs to work.

For Nigeria, the next oil-production battle is therefore not about drilling more wells alone. It is about turning capital, technology, regulation and existing reserves into barrels that can be produced consistently and profitably for years to come.