UTM secures 15-year gas supply deal for $3bn Nigeria FLNG project

UTM Offshore Limited has secured a 15-year gas supply agreement with the joint venture between NNPC Limited and Seplat Energy Producing Nigeria Unlimited, a subsidiary of Seplat Energy Plc (LSE: SEPL; NGX: SEPLAT), for its proposed floating liquefied natural gas project offshore Nigeria. The agreement provides for 200 million standard cubic feet of gas per day from the Yoho field to support a facility designed to produce approximately 1.8 million tonnes of LNG annually. UTM Offshore Limited said the supply framework removes a major commercial obstacle and supports its target of reaching a final investment decision in the fourth quarter of 2026. The project is expected to cost approximately $3 billion and is owned 72% by UTM Offshore Limited, 20% by NNPC Limited and 8% by the Delta State Government. The agreement materially improves project bankability, but financing, LNG offtake, construction contracting and a formal investment sanction must still be completed before the development can be treated as committed.

Why does the 15-year Yoho gas agreement materially improve UTM’s FLNG bankability?

Reliable feed gas is one of the most important requirements for financing an LNG project. Lenders and equity investors will not commit billions of dollars to liquefaction infrastructure without confidence that sufficient gas will reach the facility throughout the loan and operating period. The 15-year agreement gives UTM Offshore Limited a defined upstream supply source and a contractual counterparty structure involving Nigeria’s national oil company and its largest listed independent energy producer.

The duration is particularly important because LNG projects recover their capital across long operating periods. A short-term supply arrangement would leave the facility exposed to renegotiation, competing domestic demand or declining field production before investors had recovered their expenditure. A 15-year framework creates a closer match between gas availability, project debt and potential LNG sales contracts.

The agreement also links the proposed FLNG facility with an operating offshore asset rather than an undeveloped discovery. Yoho already forms part of Seplat Energy Plc’s offshore portfolio following its acquisition of Mobil Producing Nigeria Unlimited. Existing production facilities, export infrastructure and subsurface data should reduce some of the uncertainty associated with relying on a new field that must be developed simultaneously with the LNG plant.

However, the project’s supply risk has been reduced rather than eliminated. UTM Offshore Limited must demonstrate that Yoho can deliver the contracted gas volumes consistently while maintaining existing oil and condensate operations. Reservoir performance, compression requirements, offshore maintenance and pipeline availability will determine whether the contractual commitment becomes dependable physical supply.

Can 200 MMscf/d of Yoho gas reliably support 1.8 million tonnes of annual LNG output?

The contracted supply equates to approximately 73 billion cubic feet of natural gas annually if the full 200 million standard cubic feet per day is delivered throughout the year. UTM Offshore Limited’s planned LNG output of 1.8 million tonnes per annum represents a substantial conversion requirement once plant fuel consumption, processing losses and maintenance downtime are included.

The relationship between feed gas and LNG output depends on gas composition and calorific value. Richer gas can produce more energy per unit of volume, while the removal of condensate, liquefied petroleum gas and impurities affects the quantity available for liquefaction. UTM Offshore Limited has not disclosed the detailed material balance reconciling the contracted gas volume with the stated LNG capacity.

This does not necessarily mean the capacity target is unsupported. The 200 MMscf/d agreement may represent a base or initial contracted volume, while the design could allow additional supply or process optimisation. It may also reflect a revision to earlier configurations that included separate LNG, liquefied petroleum gas and condensate production.

Investors and lenders will require a precise technical reconciliation before sanction. The engineering package must explain expected gas quality, plant utilisation, internal fuel use, liquids recovery and annual maintenance assumptions. A facility designed for 1.8 million tonnes but consistently short of feed gas would operate below capacity and weaken project returns.

Reservoir certification will therefore matter alongside the contract. The partners must demonstrate that Yoho contains sufficient recoverable gas to sustain the commitment for 15 years without compromising other development priorities. A long contract is commercially valuable, but it cannot persuade a reservoir to contain more gas than the engineering data supports.

How does Seplat Energy’s Yoho ownership strengthen the project’s upstream credibility?

Seplat Energy Plc acquired its offshore interests through the purchase of Mobil Producing Nigeria Unlimited, giving the company exposure to Oil Mining Leases 67, 68, 70 and 104. Yoho and Awawa are located within OML 104 and have historically produced through the Yoho offshore platform and floating storage and offloading infrastructure.

The acquisition transformed Seplat Energy Plc from a predominantly onshore producer into a larger integrated Nigerian operator with offshore production, export terminals and natural gas liquids facilities. The company has since focused on restoring idle wells, improving asset integrity and increasing reliability across the acquired portfolio.

That operating presence gives Seplat Energy Plc a direct incentive to commercialise gas resources that may otherwise remain underused. Selling gas to UTM Offshore Limited could create an additional revenue stream from the Yoho asset while allowing existing oil and liquids production to continue.

The contract could also improve the economics of future investment at Yoho. Compression, well workovers, gas gathering and facility upgrades become easier to justify when supported by a long-term customer. The project may therefore help convert previously stranded or low-value gas into a contracted product.

Seplat Energy Plc still needs to manage capital carefully. The company is executing an extensive drilling and maintenance programme across both onshore and offshore assets. Supplying UTM Offshore Limited may require additional wells, modifications or processing expenditure that has not been quantified publicly.

The gas supply agreement does not make Seplat Energy Plc an equity owner of the FLNG project. Its principal exposure appears to be through the upstream joint venture and gas sales rather than direct responsibility for the $3 billion liquefaction investment. That distinction limits construction risk while preserving potential supply revenue.

Why could floating LNG offer Nigeria a faster route to monetising stranded offshore gas?

Floating LNG combines gas processing, liquefaction, storage and offloading on a marine facility positioned near offshore resources. The model can avoid the need to construct a long pipeline to a large onshore liquefaction plant, reducing exposure to land acquisition, community disputes and extensive onshore infrastructure.

For Nigeria, that feature is commercially relevant. The country holds 215.19 trillion cubic feet of gas reserves but has repeatedly struggled to convert resources into reliable domestic supply and exports. Infrastructure gaps, financing constraints and project delays have prevented the reserve base from producing its full economic value.

An FLNG facility can be matched more directly with an offshore gas source. Gas from Yoho could be processed and liquefied near the field before being transferred to LNG carriers. This may reduce the number of infrastructure interfaces compared with routing supply through several onshore pipelines and processing facilities.

Floating LNG is not automatically cheaper or easier. The vessel requires complex cryogenic equipment, offshore mooring, storage systems, marine loading facilities and reliable operation in difficult conditions. Construction is typically concentrated at specialised shipyards, creating dependence on a limited number of contractors and equipment suppliers.

Operating an LNG plant offshore also complicates maintenance. Major repairs can require specialist crews, replacement modules or extended downtime. Weather and marine conditions may affect LNG carrier loading and access to the facility.

The project’s strategic advantage is therefore reduced dependence on onshore infrastructure, not the elimination of execution risk. UTM Offshore Limited must show that the selected design delivers competitive capital cost, availability and safety across the facility’s operating life.

Does the gas agreement mean UTM Offshore is now certain to reach a 2026 final investment decision?

The agreement is a meaningful prerequisite for a final investment decision, but it is not the investment decision itself. UTM Offshore Limited has targeted several earlier sanction dates as the project moved through engineering, licensing, ownership restructuring and financing discussions. The latest fourth-quarter 2026 objective should therefore be judged against completed commercial milestones rather than accepted solely as a timetable.

Front-end engineering and design was completed by JGC Corporation and Technip Energies in 2023. Nigeria’s midstream regulator subsequently granted the project the country’s first licence to construct a floating LNG export facility in 2024. The ownership structure has also been formalised with NNPC Limited and the Delta State Government.

Feed-gas contracting removes another major obstacle, but several critical items remain. UTM Offshore Limited must secure committed equity, project debt, LNG buyers, construction contracts and firm cost estimates. Each component affects the others because lenders will examine offtake quality, while buyers will assess construction credibility and project sponsors will require confidence in the final capital budget.

The $3 billion estimate may also change as engineering and procurement are updated. LNG equipment, shipyard capacity, financing rates and specialist labour costs have shifted since the original design work was completed. A refreshed cost estimate may be necessary before investors commit capital.

Repeated delays do not mean the project will fail. Large LNG developments frequently take several years to assemble because upstream supply, commercial contracts and financing must align. The delays do mean that the fourth-quarter target should remain conditional until UTM Offshore Limited announces financial close and a formal notice to proceed.

How could the $3 billion project be financed without overloading its Nigerian sponsors?

UTM Offshore Limited owns 72% of the project, giving the private Nigerian company the largest potential equity obligation. NNPC Limited holds 20%, while the Delta State Government has an 8% interest. Applying these percentages directly to the $3 billion cost would imply substantial sponsor commitments, although the final financing structure may include project debt and external investors.

A conventional LNG financing package could combine sponsor equity, commercial bank loans, export credit support and development finance. Equipment sourced from international suppliers may allow the project to access financing backed by export credit agencies in the suppliers’ home countries.

Long-term LNG offtake contracts will be central to debt capacity. Lenders prefer buyers with strong credit profiles and contractual obligations extending through much of the financing period. UTM Offshore Limited has not publicly disclosed enough binding LNG sales agreements to demonstrate that revenue risk has been fully addressed.

The 15-year feed-gas contract improves the financing proposition because it gives lenders greater confidence in the input side of the business. The project still needs equivalent certainty on the output side. A plant with secure gas but no dependable LNG customers remains difficult to finance.

NNPC Limited’s participation provides state alignment, but it does not remove funding risk. Nigeria has several competing oil, gas and infrastructure priorities, and the national oil company must allocate capital across upstream production, pipelines, refineries and LNG developments.

Delta State’s ownership can strengthen local political and economic alignment. It may also support employment and supply-chain participation. The state’s ability and willingness to fund its share of construction will need to be clarified before financial close.

UTM Offshore Limited could bring in another strategic investor to reduce its own equity requirement. A global LNG trader, infrastructure fund or energy company could contribute capital and marketing capability. The cost would be dilution and potentially reduced control over the project.

What does the agreement mean for Seplat Energy’s earnings and capital-allocation strategy?

Seplat Energy Plc entered the agreement from a stronger financial position following the integration of its offshore acquisition. First-quarter 2026 revenue reached $840.7 million, adjusted EBITDA was $371.3 million and free cash flow increased to $199.2 million. Net debt declined to $531.6 million, equivalent to approximately 0.43 times trailing adjusted EBITDA.

The balance sheet gives Seplat Energy Plc capacity to invest in Yoho and other offshore assets while maintaining dividends and its wider drilling programme. The company has guided for 135,000 to 155,000 barrels of oil equivalent per day of production during 2026, with gas and natural gas liquids expected to provide a larger contribution.

The UTM Offshore Limited contract could add a stable gas-sales channel once the FLNG project enters operation. The value will depend on the gas price, transportation obligations, capital required to deliver supply and whether the contract includes take-or-pay protection.

No contract value or pricing formula has been disclosed. Investors cannot yet estimate revenue, margins or return on any upstream investment required to support the agreement. The strategic benefit is therefore clearer than the near-term earnings impact.

The agreement also diversifies Seplat Energy Plc’s commercial exposure. The company currently sells oil, domestic gas and natural gas liquids. Supplying an LNG export project could give it indirect exposure to international gas markets without requiring Seplat Energy Plc to fund the entire liquefaction facility.

This opportunity must be balanced against domestic energy needs. Nigeria continues to face shortages affecting power plants and industrial customers. A commercially attractive export contract should not undermine existing supply obligations or expose Seplat Energy Plc to regulatory intervention if domestic gas availability becomes constrained.

Why has Seplat Energy stock remained subdued despite stronger offshore gas optionality?

Seplat Energy Plc shares traded near 515p in London on July 7. The stock was broadly unchanged from the June 30 close but approximately 9.3% below the 568p closing price recorded on June 8. It remained within a 52-week range of 207.5p to 620p and was trading around 17% below the annual high.

The share price had already risen substantially over the preceding year following the completion and integration of the Mobil Producing Nigeria Unlimited acquisition. Investors have rewarded the company for achieving greater production scale, improving free cash flow and reducing leverage.

The UTM Offshore Limited agreement is unlikely to change near-term forecasts because the FLNG project has not reached FID and will require several years of construction. Seplat Energy Plc will not receive full contracted gas revenue until the facility is operating, and the expected start date has not been confirmed in the latest announcement.

Investors are currently more sensitive to Yoho platform reliability, oil prices, offshore production, operating costs and the pace of the company’s capital programme. First-quarter unit production costs increased partly because of Yoho maintenance and weaker volumes, showing that asset reliability remains a more immediate earnings driver.

The stock’s decline from its May high may also reflect profit-taking after a rapid re-rating. A market capitalisation near £3.1 billion and a share price more than double the previous year’s low create a higher standard for new catalysts.

The gas agreement supports longer-term value by establishing another commercial route for Yoho resources. A larger valuation impact is likely to require UTM Offshore Limited to reach FID, disclose the construction timetable and confirm when Seplat Energy Plc expects gas sales to begin.

What regulatory, construction and security risks could still delay Nigeria’s first FLNG project?

The first risk is financial close. A $3 billion project requires lenders and investors to commit funds under terms that remain attractive despite country risk, interest rates and LNG-market uncertainty. Delays in finalising offtake contracts or sponsor equity could move FID beyond the fourth quarter.

The second risk is construction execution. Floating LNG vessels require complex engineering and long-lead equipment, including liquefaction modules, compressors, storage tanks and marine loading systems. Shipyard delays or design changes could raise costs and postpone commissioning.

Feed-gas infrastructure creates another risk. Wells, gathering systems and pipelines must reliably deliver 200 MMscf/d from Yoho. A failure involving offshore facilities could interrupt both existing production and the future LNG supply chain.

Security remains relevant across Nigeria’s petroleum sector. Offshore assets may be less exposed to some forms of onshore pipeline vandalism, but marine security, theft, sabotage and community relations still require sustained investment.

Regulatory stability will affect financing. Investors need confidence in fiscal terms, gas pricing, export permissions, foreign-exchange access and the enforcement of project contracts. Unexpected policy changes could increase the return demanded by lenders and equity partners.

LNG-market conditions could also shift before the project enters operation. Significant new supply is scheduled from the United States, Qatar and other exporters. A well-contracted project can withstand weaker spot prices, but an under-contracted development would face greater exposure to market oversupply.

What milestones should investors watch before UTM Offshore begins construction?

The first milestone will be LNG offtake disclosure. UTM Offshore Limited must identify credible buyers and show that a sufficient portion of the 1.8 million-tonne annual capacity is commercially supported.

The second milestone will be an updated project cost and engineering configuration. Investors need confirmation that the $3 billion estimate remains realistic after inflation and design refinement.

The third milestone will be financing commitments. Sponsor equity, debt, export credit support and any new strategic investors must be documented before the final investment decision can be considered bankable.

The fourth milestone will be confirmation of the engineering, procurement and construction structure. JGC Corporation and Technip Energies completed front-end engineering work, but the full construction award and shipyard strategy must still be clarified.

The fifth milestone will be upstream development disclosure from the NNPC Limited and Seplat Energy joint venture. Required wells, compression, pipelines and facility modifications will determine whether the 200 MMscf/d commitment can be delivered on schedule.

The sixth milestone will be the formal final investment decision targeted for the fourth quarter of 2026. A board-level sanction supported by financing and construction notices would move the project from development into execution.

The final milestone will be a credible commissioning date. The project has experienced repeated timetable changes, so investors should rely on a schedule linked to contracted construction milestones rather than an aspirational start-up year.

Key takeaways on what UTM’s gas agreement means for Nigeria, Seplat and LNG investors

• UTM Offshore Limited has secured a 15-year agreement for 200 MMscf/d of gas from the NNPC Limited and Seplat Energy joint venture.
• The supply will come from the Yoho field and support a proposed floating LNG facility designed for 1.8 million tonnes per annum.
• The agreement removes an important feed-gas obstacle but does not constitute a final investment decision or construction sanction.
• UTM Offshore Limited still needs LNG buyers, committed financing, updated construction costs and full EPC arrangements.
• The project is owned 72% by UTM Offshore Limited, 20% by NNPC Limited and 8% by the Delta State Government.
• Floating LNG could help Nigeria monetise offshore gas without depending on extensive new onshore pipeline infrastructure.
• Seplat Energy Plc could gain a long-term gas-sales channel without directly assuming the entire $3 billion liquefaction investment.
• The contract value, gas pricing mechanism and capital required at Yoho have not been disclosed.
• Seplat Energy shares remain well above their 52-week low but have fallen approximately 9% over one month as investors focus on operations and near-term cash flow.
• LNG offtake, financing closure, EPC awards and the targeted fourth-quarter 2026 FID are the decisive next catalysts.