By Adedapo Adesanya

Nigerian upstream petroleum operator, Ingentia Energies Limited, has unveiled an ambitious expansion plan to raise production to 30,000 barrels per day by 2030.

This came as the company met with the Nigerian Upstream Petroleum Regulatory Commission (NUPRC) during a recent strategic engagement.

The NUPRC reaffirmed its commitment to strengthening indigenous participation in Nigeria’s oil and gas industry while insisting on strict regulatory compliance, corporate responsibility, and investment in human capital development.

Speaking with Mr Valentine Ugbeide, the chairman of Ingentia Energies Limited and his top management team at the commission’s headquarters in Abuja, Mrs Oritsemeyiwa Eyesan, the agency’s chief executive, emphasised that indigenous operators remain critical to the future growth, sustainability, and survival of Nigeria’s upstream petroleum sector.

Mrs Eyesan said indigenous companies have a major role to play in expanding production, deepening local participation, and driving long-term industry resilience, stressing that even modest production contributions from multiple indigenous operators could significantly boost national output.

According to her, “For the indigenous players, this is a major space. Little drops matter, and when you have many operators contributing consistently, the cumulative impact becomes substantial for national production.”

She commended Ingentia Energies’ leadership for demonstrating seriousness and strategic direction, noting that strong execution capacity, visionary boards, and management commitment are essential for indigenous firms seeking to scale successfully in Nigeria’s competitive oil and gas landscape.

The NUPRC boss, however, warned that growth must be matched with institutional strength, regulatory discipline, and operational structures capable of sustaining long-term industry participation.

She stressed that many indigenous firms often prioritise immediate production and market survival at the expense of building robust internal systems, technical competence, and sustainability structures previously embedded by international oil companies.

“Human capital development is no longer optional. Indigenous companies must deliberately invest in the right capabilities, systems, and structures to remain competitive and sustainable,” she said.

Mrs Eyesan called for stronger collaboration among indigenous operators, regulators, and industry stakeholders to enrich the sector’s resource base and build a more resilient local industry.

She further urged operators to uphold good corporate citizenship by meeting statutory obligations, including the payment of royalties, gas penalties, and other regulatory debts.

On his part, Mr Ugbeide, Ingentia Energies Chairman, in his response, unveiled an ambitious expansion plan to raise production to 30,000 barrels per day by 2030, as the company secured a facility from a Nigerian bank to deepen drilling, end gas flaring, and strengthen its position as a model for local participation in Nigeria’s oil and gas industry.

Mr Ugbeide said Ingentia’s journey from a challenging indigenous acquisition to a growing production company demonstrates that Nigerian firms can successfully operate strategic upstream assets when backed by the right regulatory support, technical competence, and collaborative governance structure.

Describing the company’s Egbolom field development as a template for indigenous operators, he said Ingentia had overcome formidable structural and financial barriers that were initially designed to frustrate local operators.

“Egbolom has become a role model that mirrors what indigenous companies can achieve despite obstacles. Our success should serve as a blueprint for other local firms,” he said.

He revealed that after demonstrating operational discipline and strong compliance performance, local financial institutions gained confidence in Ingentia’s business model, leading to the recent debt financing.

“We got debt funding from a local bank last week to continue our activities. They saw our performance and began pursuing us because of what we have achieved,” he said.

He added that Ingentia has maintained strong regulatory compliance, including consistent royalty payments and zero defaults on gas flare penalties, while currently flaring between 1.8 million and 3 million standard cubic feet of gas daily.

However, he announced that this would end before year-end as the company finalizes infrastructure with a Chinese technical partner to commercialise its gas resources and supply gas to on-site facilities.

“Before the end of this year, that gas will be fully utilised, and we will stop flaring completely,” he stated.

Mr Ugbeide also highlighted Ingentia’s significant infrastructure investments, including the Ogunokun operational base with jetty and mooring systems, alongside additional investments in drilling sites, accommodation, and logistics support structures.

From an initial workforce of just two staff members, he said the company has grown to over 100 direct and indirect employees, with plans for more aggressive recruitment as production scales from current levels toward 10,000 barrels per day and beyond.

He disclosed that Ingentia plans to drill a minimum of two wells annually, supported by fresh seismic campaigns targeting deeper reservoir opportunities.

“Our target is clear — by 2030, we want to be in the neighbourhood of 30,000 barrels per day,” he said.

A new report by EBC Financial Group has projected that the planned exit of the United Arab Emirates (UAE) from the Organisation of the Petroleum Exporting Countries (OPEC) on Friday, May 1, 2026 (tomorrow), could post a threat to Nigeria, a member of the oil cartel.

In a note made available to Business Post, it said the immediate challenge for Nigeria, Africa’s largest oil producer, involves managing crude volatility and ensuring production is translated into loaded cargoes, refinery feedstock, settled USD receipts, and controlled fuel-cost pass-through.

It was emphasised that the decision of the UAE does not automatically strengthen the oil position for Nigeria, but shifts attention from crude-price exposure to operational execution.

Nigeria’s 2026 fiscal framework, as outlined by President Bola Tinubu, sets a crude oil benchmark price of 64.85 per barrel, a production target of 1.84 million barrels per day, and an exchange rate assumption of N1,400 per Dollar.

The 2026 Appropriation Bill of N68.32 trillion, approved by Mr Tinubu about two weeks ago, provides for aggregate expenditure of N68.32 trillion. Reduced oil receipts may limit USD inflows into the financial system, affecting the ability of banks, importers, and manufacturers to settle overseas invoices. This scenario could constrain foreign exchange (FX) liquidity, delay import settlements, prolong government and contractor payment cycles, and result in broader pricing buffers for imported inputs.

Oil production figures remain variable. OPEC’s April Monthly Oil Market Report recorded Nigeria’s crude production at 1.38 million barrels per day in March, up from 1.31 million barrels per day in February, yet below the quota of 1.5 million barrels per day from OPEC.

The Nigerian Upstream Petroleum Regulatory Commission (NUPRC) later reported that daily crude production had reached 1.84 million barrels per day, after a February reduction attributed to incidents at strategic facilities and maintenance activities. The focus is on whether Nigeria can sustain elevated output through all stages—pipelines, terminals, cargo loading, export payment, and FX conversion.

“Nigeria has demonstrated the distinction between setting oil targets and delivering oil revenue. Recent production figures reflect progress; however, market participants focus on consistency rather than isolated results.

“The key consideration is whether volatility in crude markets can be translated into loaded cargoes, settled USD receipts, and sufficient FX liquidity to reduce pricing buffers on import invoices,” the Senior Market Analyst at EBC Financial Group, Mr David Precious, noted.

First Test: Ensure Effective Dispatch of Export Barrels

The commercial challenge extends beyond production figures. Crude oil must be evacuated from production fields, metered at custody-transfer points, scheduled through export terminals, documented for lifting, loaded onto vessels, and paid for before generating usable USD proceeds for reserves, public revenue, and private-sector FX demand. A barrel measured at the wellhead does not support the Nigerian naira (NGN) market until the export process is finalised and proceeds enter the financial system.

Disruptions in pipelines, terminals, vessel nominations, or payment settlements widen the gap between production and accessible USD proceeds. Pipeline interruptions may delay evacuation, terminal congestion can extend vessel waiting times, nomination changes may shift loading windows, and payment delays can slow the conversion of oil sales into available FX. Such delays may increase working-capital requirements for importers, slow public cash disbursement, expand supplier pricing buffers, and elevate raw-material costs for manufacturers reliant on FX for overseas payments.

Second Test: Secure Domestic Refinery Feedstock Before Product Prices Reprice

EBC highlights that Nigeria’s next priority is domestic crude allocation. NUPRC has identified Domestic Crude Oil Supply Obligation (DCSO) issues, including contracts that failed to reflect legal provisions, reluctance by some producers to allocate production to domestic refineries, changes in vessel nomination, delayed vessel arrival and frequent lay-can changes for crude allocated to domestic refineries. These are not administrative issues alone. Delayed feedstock disrupts refinery run planning, increases storage exposure, creates demurrage risk, delays product release from depots and raises trucking costs.

DCSO enforcement becomes more important if global crude volatility raises refined-product prices. Local refineries require predictable crude supply schedules and workable payment terms to reduce dependence on import-parity pricing. Irregular feedstock supply exposes petrol, diesel and aviation fuel to higher shipping, insurance, depot and FX conversion costs. Those costs move into factory generator diesel, trucking rates for food and cement, jet fuel for airlines, inventory finance for wholesalers and operating margins for retailers.

Third Test: Turn Atlantic Basin Geography into Reliable Cargo Supply

The International Energy Agency (IEA) said early-April shipments of crude, natural gas liquids and refined products through the Strait of Hormuz averaged around 3.8 million barrels per day, compared with more than 20 million barrels per day in February before the crisis. The IEA also said alternative-route exports had increased to 7.2 million barrels per day from less than 4 million barrels per day before the war, while global crude and refined-product markets remained under pressure.

Nigeria’s Atlantic Basin location gives buyers an alternative to Gulf-linked supply routes, but that advantage only has commercial value if cargoes load reliably. When Nigerian cargoes are loaded on schedule, buyers can plan refinery intake, banks can process trade finance with fewer timing buffers, and exporters can convert crude sales into USD more quickly. When cargoes are delayed, vessel waiting time, financing cost and supply-chain uncertainty rise, reducing any buyer-confidence advantage Nigeria could gain from offering non-Gulf cargoes during a disrupted physical market.

Fourth Test: Separate Export Gains from Domestic Cost Pass-Through

Higher crude prices can increase Nigeria’s export revenue, but the benefit does not reach the economy as quickly as fuel-cost increases. Export receipts support fiscal revenue and USD liquidity only after production, lifting, invoicing and payment. Refined-product costs can be re-priced more quickly through depots, trucking contracts and supplier invoices. That timing gap can raise diesel, petrol, aviation fuel, lubricants, plastics, packaging, and imported manufacturing input costs before higher public revenue reaches the broader economy.

EBC analysts noted that the commercial impact shows up in operating margins. Manufacturers face higher generator diesel and imported raw material costs. Logistics firms face higher truck-fuelling costs. Airlines face higher aviation-fuel costs. Wholesalers face higher inventory-finance requirements. Retailers face pressure to pass higher landed costs to consumers. This is why Nigeria’s oil upside depends not only on crude prices, but on how quickly export proceeds become usable USD and how predictably domestic fuel supply reaches depots.

What Comes Next for Nigeria

The first external checkpoint is the May 3, 2026, OPEC+ meeting. OPEC said eight participating countries agreed to implement a 206,000-barrel-per-day production adjustment in May, retain flexibility to increase, pause or reverse the phase-out of voluntary adjustments, and meet monthly to review market conditions, conformity and compensation. For Nigeria, the meeting will show whether producer coordination remains firm after the UAE’s exit and how participating countries position future output adjustments.

Nigeria’s internal benchmarks are now measurable. Production needs to stay close to the 1.84 million-barrel fiscal reference. Export terminals need to show timely cargo loading. DCSO enforcement needs to reduce lay-can changes and refinery feedstock uncertainty. FX liquidity needs to show that export receipts are reaching importers and manufacturers quickly enough to reduce pricing buffers across fuel, food distribution, factory power and consumer goods.

“The UAE is moving towards greater production flexibility, but Nigeria’s issue is different,” Mr Precious added. “Nigeria has to protect the chain from production to payment. If a cargo misses its loading window, refinery feedstock planning changes. If refinery planning changes, depot release timing changes. If depot timing changes, trucking, factory power and consumer prices absorb the cost before higher export revenue reaches the broader economy.”

The UAE’s exit does not determine Nigeria’s oil outcome. It highlights the execution chain Nigeria must now protect: production, evacuation, lifting, payment, FX conversion, refinery feedstock and final fuel pricing. Nigeria’s commercial benefit will depend on converting capacity into reliable cargoes and reliable cargoes into usable cash.

By Adedapo Adesanya

Central Securities Clearing System (CSCS) Plc weakened the NASD Over-the-Counter (OTC) Securities Exchange by 1.13 per cent on Wednesday, April 29, after its share price shrank by N5.06 to N71.99 per unit from N77.05 per unit.

As a result, the NASD Unlisted Security Index (NSI) went below the 4,000 mark after it lost 45.73 points to 3,999.23 points from 4,044.96 points. The market capitalisation declined by N27.36 billion during the session to N2.392 trillion from N2.420 trillion.

Midweek trading data showed that the volume of transactions slid by 76.2 per cent to 308,698 units from 1.3 million units, and the value of trades decreased by 7.1 per cent to N25.2 million from N27.1 million units, while the number of deals rose by 3.7 per cent to 28 deals from 27 deals.

At the close of business, Great Nigeria Insurance (GNI) Plc remained the most traded stock by value on a year-to-date basis, with the sale of 3.4 billion units valued at N8.4 billion, followed by CSCS Plc with 59.9 million units exchanged for N4.1 billion, and Okitipupa Plc with 27.8 million units traded for N1.9 billion.

GNI Plc also finished as the most traded stock by volume on a year-to-date basis, with a turnover of 3.4 billion units worth N8.4 billion, trailed by Resourcery Plc with 1.1 billion units transacted for N415.7 million, and Infrastructure Guarantee Credit Plc with 400 million units sold for N1.2 billion.