Bonga SW/Aparo: What 175,000bpd could mean for Nigeria’s oil production, deepwater investment

The progress of the long-awaited Bonga Southwest/Aparo (BSWAp) project towards Final Investment Decision (FID) is coming at a critical point for Nigeria’s upstream sector, with the country trying to sustain its recent production recovery while attracting billions of dollars into new oil developments.

The deepwater project, which is expected to reach peak production of about 175,000 barrels per day (bpd) and attract between $15 billion and $21 billion in investment over its life, could eventually add a sizeable new production stream to Nigeria’s oil portfolio. But the significance of BSWAp goes beyond the volume of crude it could eventually produce.

Its progress is also being watched against Nigeria’s ambition to raise production to 2 million bpd by 2027 and 3 million bpd by 2030, as well as the Federal Government’s efforts to revive investment in capital-intensive deepwater projects.

175,000bpd: how significant is it?

Nigeria’s latest available production data show that the country averaged 1.505 million bpd of crude oil in July 2026, according to the Nigerian Upstream Petroleum Regulatory Commission (NUPRC). With condensates included, total oil and condensate production stood at 1.67 million bpd during the month.

The July crude figure was slightly above Nigeria’s 1.5 million bpd OPEC quota, marking the third consecutive month in which the country exceeded its quota. However, total production fell by about four per cent from the 1.735 million bpd recorded in June. NUPRC attributed the decline largely to operational challenges at the Erha and Akpo fields.

Against that backdrop, BSWAp’s projected 175,000bpd peak production would be equivalent to about 11.6 per cent of Nigeria’s July crude output. Put another way, if Nigeria were producing at July’s 1.505 million bpd level when BSWAp reaches its projected peak, the project’s 175,000bpd would represent a substantial addition to national crude production.

But the figure should not be interpreted as an immediate increase in output. BSWAp has not yet reached FID, and the project must still move through further engineering, commercial, regulatory and development stages before production can begin.

Bonga could help close the gap to 2 million bpd

The importance of new projects becomes clearer when Nigeria’s current production is compared with its national targets. At July’s crude production rate of 1.505 million bpd, Nigeria was about 495,000bpd short of the 2 million bpd target set for 2027.

A 175,000bpd BSWAp contribution, if it were available at that point, would amount to roughly 35 per cent of that gap. The project would also represent about 12 per cent of the difference between July’s crude output and the longer-term 3 million bpd target.

However, these comparisons are illustrative rather than a forecast of when BSWAp will come on stream. The project’s eventual production timing will depend on FID and subsequent development and construction schedules. For the NUPRC, accelerating deepwater developments is already part of the strategy for increasing national production. The regulator has said Nigeria is targeting 2 million bpd by 2027 and 3 million bpd by 2030, with accelerated deepwater development identified as one of the routes to achieving those targets.

The bigger issue: replacing lost and declining barrels

The significance of BSWAp is also tied to the need to continually replace production from mature fields. Nigeria’s production has recovered from much lower levels, but the July decline demonstrates that national output remains vulnerable to operational disruptions.

NUPRC’s figures show combined crude and condensate production rising from 1.459 million bpd in January to 1.735 million bpd in June, before falling to 1.67 million bpd in July. That recovery has largely involved getting more out of existing assets and improving operational performance.

New projects such as BSWAp are different because they can provide additional production capacity, rather than relying solely on recovering output from existing fields. This is particularly important for a country whose production base includes mature assets and where the government wants to increase output without relying indefinitely on older fields.

Bonga is part of a much bigger offshore investment pipeline

The BSWAp investment opportunity also needs to be viewed within the wider offshore pipeline. NUPRC said earlier this month that 22 major offshore projects are expected between 2026 and 2030, with estimated investment potential of $30 billion to $50 billion.

The regulator said more than $57 billion in Field Development Plans (FDPs) had been approved since 2024, some of which had already translated into FIDs. That means BSWAp is not an isolated investment opportunity.

Its progress comes as Nigeria seeks to turn a broader pipeline of offshore developments into actual capital deployment and new production. The Federal Government has also estimated that its new deep offshore investment framework could unlock up to $50 billion in new investment.

The framework, given effect through the Deep Offshore Oil and Gas Projects Incentives (Tax Remission) Order, 2026, is designed to replace project-by-project negotiations with a more predictable framework for qualifying deep offshore developments. The State House said the reform would begin with the approximately $10 billion Bonga Southwest project and other qualifying developments.

Why the fiscal reform matters

Deepwater projects require large upfront capital, long development periods and technically complex offshore infrastructure.
For investors, therefore, the economics of a project depend heavily on the fiscal terms and the certainty surrounding them. That has been one of the central issues surrounding BSWAp.

In January, the Presidency announced targeted incentives for Bonga Southwest, describing them as investment-linked measures designed to attract new capital and incremental production.
By August, the Federal Government had moved towards a broader framework covering qualifying deep offshore developments rather than relying only on individual project negotiations.

The execution of the BSWAp PSC and DSA addenda on August 24 subsequently gave effect to the fiscal and commercial terms approved for the project. For the industry, the development therefore provides a link between policy reform and a specific large-scale project moving closer to execution.

What the $15bn-$21bn investment could mean

The projected investment is significant not only because of the amount of capital involved but because of the activities required to deploy it. A development of BSWAp’s scale will require engineering, fabrication, offshore construction, marine logistics, procurement, installation, operations and maintenance.

This creates potential opportunities for Nigerian companies across the oilfield services value chain. The Federal Government’s new deep offshore framework specifically places emphasis on increasing execution within Nigeria where commercially and technically feasible, including engineering, fabrication, marine logistics, technical services and project management.

The potential benefit, therefore, is not limited to the eventual sale of crude. A major offshore development can generate demand for local contractors, suppliers, engineers and technical professionals throughout its development and operating life.

Bonga also tests Nigeria’s deepwater revival

There is another reason BSWAp matters.
NNPC had described the project in March as potentially the first FID on a Nigerian deepwater PSC asset since 2008, highlighting the length of time between major deepwater investment decisions in the country. At the time, the company estimated that the project could attract about $20 billion and produce 150,000bpd of crude and 140mmscfd of gas.

The latest project parameters have since been put at $15 billion-$21 billion in investment and about 175,000bpd of peak oil production. The movement towards FID therefore comes after years of negotiations over the project’s commercial and fiscal structure.

If the project proceeds to FID and eventually production, it would provide a major indication of whether Nigeria’s revised approach to deepwater investment is capable of converting long-delayed projects into producing assets.

What still has to happen

Despite the latest milestone, BSWAp is not yet at first oil. The project has completed its Pre-Front End Engineering Design (Pre-FEED) phase and is expected to progress into FEED, subject to the necessary partner, assurance and governance requirements.

A preferred FPSO contractor has also been identified following a competitive selection process, but the eventual FPSO Engineering, Procurement, Construction and Installation contract remains subject to the required approvals. These steps still have to be completed before the project can move through FID and into full development.

The production question

For Nigeria, the eventual question will be whether projects such as BSWAp can turn the country’s recent production recovery into a sustained upward trend.
July’s 1.505 million bpd crude output shows that Nigeria is currently only marginally above its 1.5 million bpd OPEC quota, despite having recorded stronger production earlier in the year.

At the same time, NUPRC is targeting 2 million bpd in the near term and 3 million bpd by 2030. That makes the development of new large-scale projects increasingly important alongside efforts to restore existing production.

At 175,000bpd, BSWAp alone will not take Nigeria to 2 million or 3 million bpd. But at peak production, it could represent a material addition to the country’s crude output and account for more than a third of the gap between July’s production and the 2 million bpd target.

Its larger significance may ultimately be whether the project becomes a catalyst for a wider cycle of deepwater investment — turning Nigeria’s new fiscal framework, offshore resources and existing project pipeline into actual capital, new production and longer-term oilfield activity.