Navitas Petro: Sea Lion After FID, How Much Equity Is Still Needed and Who Carries the Execution Risk

The main article already set the broad frame: Shenandoah turned Navitas into a partnership with a real cash engine, but the center of gravity of the risk moved to Sea Lion. This continuation isolates the layer that can disappear behind the FID headline. After the investment decision and after financial close, the key question is no longer whether the project got a green light. It is how much equity still has to be carried to first oil, when that cash burn actually lands, and who ultimately absorbs the risk if execution slips.

The confusion starts with the phrase "financing closed". On December 10, 2025, Sea Lion Phase 1 received FID on a total budget of about $1.8 billion, and on December 19, 2025, financial close followed after the conditions precedent were met. That is a real milestone. But by the report date, actual Sea Lion spending amounted to only about 5% of development costs through first oil. In other words, the financing was signed while almost all of the heavy execution work was still ahead.

This is why the right frame here is all-in cash flexibility. The issue is not how much NPV Sea Lion can show on paper. The issue is how much real capital still has to move from the group into the project before March 2028, and how the risk is split between lenders, the FPSO counterparties and contractors, and the project equity, which in practice means Navitas first and foremost.

That chart matters because it resets the discussion. After FID, Sea Lion is no longer a project that needs to prove it has reserves, regulatory approval, or bank access. It is a project that still has to move through a long chain of spending, construction, and execution before it becomes distributable cash.

The Funding Bridge: $1 Billion Of Senior Debt Does Not Solve The Equity Question

The first number everyone sees is the $1.0 billion of senior debt. That number is correct, but it is only half of the bridge. The updated bank model for Phase 1 points to about $1.8 billion of development costs, including interest reserve accounts and budget-overrun cushions if needed. The harder part starts there.

The central point is that the simple pro rata math captures only part of the burden. If one starts with the $1.8 billion Phase 1 budget, subtracts the $1.0 billion of senior debt, and allocates 65% of the remaining gap to Navitas, the result is roughly $520 million. That is heavy, but still manageable on first read. It is also not the number Navitas itself highlights as the relevant funding burden.

The partnership says the equity it expects to provide for its share of Phase 1 is about $734 million, including the loan component to Rockhopper. That is the part that is easy to miss. Navitas is not only carrying its own 65% share of the uncovered capital. It is also required to provide Rockhopper with an interest-free dollar loan equal to two-thirds of Rockhopper's share of the equity needed for Phase 1. That loan is meant to be repaid out of 85% of Rockhopper's free cash flow from Phase 1 production. In practical terms, Navitas is financing not only its own path to first oil, but also part of its partner's path.

That is why the $734 million figure matters more than the clean pro rata bridge. It already reflects what the company itself sees as the relevant economic exposure, not just the formal ownership split.

There is also a group-level layer that cannot be ignored. In March 2026, the group showed about $886.4 million of cash and investments and about $1.212 billion of net financial debt. At the same time, a $150 million distribution was approved on March 17, 2026. That does not mean Navitas lacks liquidity today. It does mean the Sea Lion bridge is being built out of a balance sheet that already carries meaningful debt, has already chosen to distribute capital, and still needs to fund other projects in parallel.

Where The Cash Burn Actually Sits

The Sea Lion work-program table in the annual report is more useful than it first looks. It shows not only what the project plans to do, but also when the real funding pressure is supposed to hit. The heavy years are not immediate FID weeks. They are mainly 2026 and 2027.

At asset level, the work plan shows about $515.7 million in 2026 and about $863.7 million in 2027, before dropping to about $285.7 million from 2028 onward. Navitas' share in the same table is about $335.2 million in 2026 and about $561.4 million in 2027. That already makes clear where the critical years sit.

That table is not a clean Phase 1-only capital schedule either. In 2026 and 2027 it also includes PL001 exploration planning and preparation for the Central Development Area. That is exactly why it is useful. It shows that the capital pressure around Sea Lion does not arrive as one sterile line item, but as a broader Falklands development package.

But even here, the visible numbers are not the full economic burden. The footnotes say those figures exclude annual FPSO lease payments, exclude operating and maintenance costs, exclude abandonment costs, and also exclude the pre-FID and post-FID loans that NPDP has provided and will provide to Rockhopper subsidiaries. So even the published burn table gives the structure of the pressure, not the full all-in cash claim.

That matters because the FPSO structure pushes part of the cost into the operating phase, but does not erase it. Under the lease agreement, the total fixed lease component over the full initial 12-year term is estimated at about $330 million, and under the base case it represents roughly half of the total lease payments. The rest is variable and linked to actual production, oil price, and FPSO availability. In other words, once first oil arrives, part of the cost burden changes shape, but it does not disappear.

The timing sequence is also tighter than the headline can make it look. The FPSO is expected to be delivered to NPDP in the third quarter of 2026. During that same year, the shipyard upgrade, mooring-system fabrication, on-island construction in the Falklands, dock upgrades, helicopter support, logistics build-out, and additional contracting work all need to move. Drilling and completions are scheduled to start in early 2027. After that come installation, hook-up, commissioning, and only then first oil, which is expected in March 2028.

That sequencing changes the quality of the risk. This is no longer mostly a geology story. It is a sequencing story. Shipyard work, moorings, subsea equipment, supply base, helicopters, drilling rig, hook-up, and commissioning all need to line up. If one piece moves, the impact may not immediately look dramatic in NPV terms, but it can matter a great deal for the equity bridge and for the debt timetable.

The group-level debt profile reinforces that reading. The March 2026 presentation shows gross debt of about $2.280 billion in 2026, peaking at about $2.304 billion in 2027, and still around $2.181 billion in 2028 before falling more sharply to about $1.541 billion in 2029. That is not proof that every dollar of that debt belongs to Sea Lion. It is proof that Sea Lion's build years overlap with the group's peak leverage years.

That is why the real question is not simply whether funding exists. It is whether enough flexibility remains around it. In a structure like this, even a limited slippage in timing or cost can move quickly from a project issue into a group-level capital issue.

Who Actually Carries The Execution Risk

Signed contracts do not make execution risk disappear. They only divide it. And when the layers are separated, the lenders and contractors look better protected than the equity does.

The lenders are the clearest example of why "financing closed" is not the same thing as "risk closed". The Sea Lion financing is non-recourse and split between the two partners. There is not even a cross-default provision between the two partner financing packages, which means a default event at one partner does not automatically force a default event at the other. Put differently, the financing is built so banks can fund the project without being the first absorbers of operational chaos at one partner.

The completion tests tell the same story. Project completion for the lenders is not March 2028, and it is not simply first oil. It only occurs after a completion test that includes Phase 1 development and at least 90 days of sustained commercial production at the required volumes, plus additional conditions such as an updated reserves report, no borrowing-base shortfall, no debt-to-equity breach, and a funded debt-service reserve account. So even if first oil arrives on time, the financing structure still waits for a stability proof before it treats the project as truly complete.

The triggers are also sharp. Among other items, they include an event that could prevent project completion by March 31, 2029, a delay of more than six months to first oil, a 20% fall in oil price forecasts, and contractor insolvency that materially affects the project. This is not the language of upside sharing. It is the language of lender protection.

The FPSO and contractor layer is more mixed. On the positive side, there is real contractual structure here. The FPSO currently operates in the North Sea, there is a lease agreement, an EPC agreement, an O&M agreement, step-in rights, liquidated-damages mechanisms for delays, and an overall liability cap. In addition, the parent company of the lessor group gave NPDP an unlimited corporate guarantee securing the obligations of the lessor group under the lease, EPC, and O&M agreements.

But that does not mean all execution risk is outsourced. The EPC package is estimated at about $428 million and is based mostly on a cost-plus structure, with only a limited fixed-price element. The O&M agreement also relies on an annual budget approved by NPDP, but beyond that includes reimbursement on a cost-plus basis. That is a critical point. The contracts divide operational responsibility and give NPDP enforcement rights, but they do not push all cost risk out to the contractor. A meaningful part of that risk still lands economically on equity.

Navitas' own guarantee structure points in the same direction. The guarantee it gave the lessor is limited to the early-termination fee only, up to about $109 million including Rockhopper's share, and it declines from first oil onward. That is a narrow and specific guarantee. It is not a full completion guarantee for the project.

Then there is the layer that is easiest to miss: Rockhopper. On paper, the project finance is split proportionally and the facilities are separate. Economically, Navitas still carries part of the partner's funding burden through the interest-free loan equal to two-thirds of Rockhopper's required equity contribution. Until the project is producing and 85% of Rockhopper's free cash flow starts paying that loan back, Navitas is carrying not only its own execution burden as operator, but also part of the partner's capital burden.

That is why the answer to "who carries the execution risk" cannot be one name. Contractors carry defined performance obligations. Lenders carry protected credit exposure. But the residual risk, the layer that gets hit if timing moves, if cost control weakens, if completion is delayed, or if a partner needs more support, still sits with project equity. And within that equity, Navitas carries an especially heavy share.

The Bottom Line

Sea Lion after FID is not really a story about debt availability. The debt is available. It is a story about the quality of the equity bridge and about who absorbs the risk until the margin for error closes. At headline level, this is a $1.8 billion Phase 1 project with $1.0 billion of senior debt. At the level of Navitas' economics, it is a roughly $734 million equity package with most of the real execution burden still ahead.

The project is also not at a point where one can say the heavy lifting is already behind it. By the report date, only about 5% of development costs to first oil had actually been spent. The FPSO is due only in the third quarter of 2026. Drilling and completions are due only in early 2027. And for the lenders, even first oil is not the finish line. It is only the start of the proof phase.

If the thesis has to be stated in one sentence, it is simple: Sea Lion is no longer an approval risk, but it remains an equity and sequencing risk. As long as the FPSO, moorings, Falklands infrastructure, drilling, and completions stay on track, the heavy equity bridge is manageable. If one of those links moves, the weight falls first on project equity, and within that mostly on Navitas.

That is what the market should now measure. Not another reserves slide. The real checkpoints are FPSO delivery in 2026, the start of the drilling campaign in early 2027 without a material cost drift, and staying on track for March 2028 without moving too close to the March 2029 trigger zone. If those hold, the $734 million burden will look like a heavy but workable bridge. If they do not, it will become clear that the $1.0 billion of senior debt mainly bought protection for the banks, not calm for the equity.