Interview Questions for NewcrossEP Asset Manager (Revised)

Nigeria's upstream oil and gas sector is showing early signs of stabilization, with independent operators like NewcrossEP demonstrating that strategic asset optimization can generate meaningful production gains even amid persistent operational challenges. The company's reported substantial production increase in 2025—driven by targeted drilling campaigns at assets including Ekulama-12 and Awoba—provides a crucial case study for European investors reassessing exposure to African upstream energy.

NewcrossEP's performance reflects a broader shift in Nigeria's oil industry dynamics. Rather than waiting for macroeconomic conditions to improve, independent operators are leveraging technical expertise and disciplined capital allocation to extract additional barrels from existing acreage. This approach directly addresses one of the sector's critical constraints: Nigeria's production capacity has contracted significantly since 2020, falling from approximately 1.8 million barrels per day to under 1.2 million bpd by late 2024. For European energy majors and investors seeking exposure to Nigerian assets, the recovery strategy demonstrated by mid-cap operators like NewcrossEP represents a lower-risk entry point than waiting for systemic improvements in infrastructure or security.

The Ekulama-12 and Awoba asset clusters represent precisely the type of mature, underutilized resource base that independent operators can monetize efficiently. These fields, originally developed by international majors decades ago, typically benefit from straightforward drilling programs targeting remaining reserves in fault-bound structures. European investors familiar with North Sea depletion strategies will recognize this model: targeted infill drilling, production optimization, and lean operating costs in mature fields can deliver attractive returns without requiring transformational capex.

For European entrepreneurs and institutional investors, NewcrossEP's 2025 results carry three critical implications. First, they validate the thesis that Nigeria's upstream sector remains viable for disciplined operators with technical depth and local market knowledge. Second, they suggest that independent operators—not legacy majors—are increasingly the growth drivers in Nigerian oil and gas. Third, they indicate that currency headwinds and security challenges, while real, are not prohibitive to returns if operational execution remains tight.

However, European investors must contextualize these gains against persistent macro risks. Nigeria's naira continues under devaluation pressure, and recent regulatory shifts affecting tax treatment and royalty rates create uncertainty for project economics. The government's ongoing efforts to combat crude theft and illegal refining are yielding improvements, but pipeline integrity and production assurance remain volatile. Additionally, international sentiment toward fossil fuel exposure continues hardening, which may limit capital availability for further upstream expansion and create valuation compression for listed energy companies.

The NewcrossEP example also underscores the importance of operational due diligence over macro forecasting in African energy. A well-run operator with integrated drilling, maintenance, and cost discipline can outperform broader market indices, regardless of oil price movements or geopolitical noise. This argues for selective, operator-level investment theses rather than blanket sectoral exposure.

For the broader market, NewcrossEP's production ramp suggests that Nigerian output may stabilize nearer 1.3-1.4 million bpd in 2025, providing marginal support to regional crude pricing and bolstering the country's foreign exchange position—a critical consideration for currency stability and debt servicing capacity.