Tamar Petroleum 2025: Capacity Is Rising, Debt Has Been Reset, but the Cushion Is Still Thin

Getting To Know the Company

Tamar Petroleum is not a classic exploration company and it is not a field operator. It is essentially a thin listed wrapper sitting on one asset, a 16.75% interest in Tamar and Dalit, while Chevron runs the field. That matters because the right way to understand the company does not start with the question of whether Tamar is a good reservoir. It is. System availability was above 99%, and Tamar's 2P gas reserves stood at 271.4 BCM on a 100% field basis. The real question is how much of the cash generated by that asset actually reaches shareholders of the listed company, and how many hands take a cut on the way up.

What is working now is fairly clear. In 2025, Tamar sold 10.05 BCM of gas versus 10.09 BCM in 2024, so volume barely changed. Revenue fell to $299.7 million and net income fell to $49.7 million, but this was not a year of operating weakness in the sense of lost demand or asset deterioration. The main hit came from a 2.8% decline in the average gas price, largely because part of the export book is linked to Brent. At the same time, cash flow from operating activities before taxes and levies actually rose to $207.6 million.

The main friction sits somewhere else. At the end of 2025 Tamar Petroleum held total liquidity of $115.2 million against $654.8 million of bond debt, while still facing expansion spending, export infrastructure, an early redemption of Series B and an aggressive distribution policy. A reader looking only at the 44% LTV and the $365.7 million accumulated surplus could come away feeling comfortable. That is a mistake. This is not an immediate debt-distress picture, but it is a picture of a still-thin cushion at the listed-company level.

Another easy point to miss is how lean the company itself is. At the end of 2025 it employed only 8 people, 5 of them senior officers. That is not just biography. It explains why Tamar Petroleum looks more like a public financing and distribution vehicle for Tamar cash flows than like an energy company with its own operating engine. That is why any change in debt structure, contract terms, expansion spending or dividend policy moves almost directly into the equity thesis.

The Economic Map in Brief

Events and Triggers

The first trigger: on February 9, 2026 the first stage of Tamar's expansion project was completed, meaning the third pipeline and the related offshore and onshore infrastructure. That is a meaningful step because it removes part of the engineering bottleneck that had been capping Tamar. But it still does not equal 1.6 BCF per day. Even after that first stage, maximum production capability at the report date was still 1.15 BCF per day, and the missing step was the compressor upgrade at the Ashdod receiving terminal. The story improved, but it did not finish.

The second trigger: the FAJR project had already reached 86.8% completion by the end of 2025, with $131 million invested on a 100% basis and about $22 million as Tamar Petroleum's share, while targeted completion remains the second half of 2026. This matters because without export transportation, additional production capacity does not automatically become revenue. Anyone looking at the forward sales curve without tying it back to FAJR and Nitzana is seeing only half the picture.

The third trigger: the Nitzana project became effective in October 2025, but this is a longer-cycle item. The budget is estimated at $609 million on a 100% project basis, with Tamar partners funding 41.8% and Tamar Petroleum's share estimated at $43 million, plus around $5.4 million exposure to its share of estimated cost overruns. By the end of 2025, $161 million had already been invested at the project level, yet completion is still estimated only for the second half of 2028. Export growth is therefore likely to come in stages, not in one clean jump.

The fourth trigger: on January 15, 2026 Tamar Petroleum signed its bank financing agreement, on February 18 the $300 million of loans were drawn, and on March 1 Series B was fully redeemed early for about $313 million including principal and interest. That solves a real maturity-profile issue, but it does not reduce leverage. The company is replacing listed debt with bank financing, together with a pledge over 7.5% of Tamar in favor of the bank, new financial covenants and a reserve deposit of up to $23 million. In other words, a significant part of the cash flow now answers to a different creditor structure, but the debt did not disappear.

The fifth trigger: on February 22, 2026 the Kesem gas agreement became effective for supply to a combined-cycle power plant near the Kesem interchange. The contract provides for firm supply of up to 0.8 BCM per year from the start of commercial delivery and for a term of five years or until January 1, 2035, whichever is later. This strengthens the domestic demand layer, but it does not create immediate cash because it still depends on the power plant entering commercial operation and on actual consumption ramping over time.

The sixth trigger: on December 29, 2025 the venture took a final investment decision to drill the Tamar 12 and Tamar 3ST development wells. The total budget is $466.5 million on a 100% basis, with Tamar Petroleum's share at $78.1 million. That is positive for long-term redundancy and production maintenance, but it is also a reminder that the next few years are not only harvest years. They are also investment years.

Trigger Map for the Next 2 to 4 Quarters

Efficiency, Profitability and Competition

In 2025 the issue was price, not volume

The 2025 story starts with the gap between quantity and price. Total Tamar gas sales stayed almost flat, 10.05 BCM versus 10.09 BCM in 2024, but the revenue mix shifted. Domestic-gas revenue rose to $186.2 million from $179.1 million, while export-gas revenue fell to $109.4 million from $126.2 million. In other words, the company benefited from a stronger domestic market but was hit by weaker export pricing.

That matters because it means Tamar's operating base did not crack in 2025. What weakened was pricing quality on the export side of the portfolio. It also explains why a reader focused only on the top line gets a story that is too negative, while a reader focused only on forward volume projections gets a story that is too optimistic.

The fourth quarter was a reminder that the story is still uneven

The fourth quarter of 2025 was weaker than the full-year picture. Total field sales fell to 2.15 BCM from 2.47 BCM in the comparable quarter, with export down to 0.85 BCM from 1.04 BCM and the domestic market down to 1.30 BCM from 1.43 BCM. Tamar Petroleum's own natural-gas revenue fell to $66.7 million from $76.1 million. The company links that mainly to maintenance work, which is important because it suggests the quarter does not necessarily point to structural weakening, but it does show how quickly maintenance and operating interruptions feed into the numbers.

The quarter also exposed the real quality of the annual cost improvement. On a full-year basis, gas and condensate production cost fell 4.2% to $45.7 million, helped in part by a transmission-fee credit under a settlement with Natgaz and by lower maintenance. But in the fourth quarter itself production cost rose 15.8% to $15.3 million, mainly because of maintenance and operating work. That means part of the annual cost improvement was not a clean new run-rate, but also a function of timing and a partial one-off credit.

Profitability looks acceptable, but the state and the debt take a large share

Profit from ordinary operations before levy fell to $157.8 million, and profit from ordinary operations after levy fell to $92.9 million. What really matters is that the petroleum and gas levy still rose to $64.9 million even as revenue declined. The company explains that the levy is calculated on a cash basis, so lower investment increased the levy base. Put simply, when revenue weakens, the state's take does not necessarily weaken with it. Sometimes it does the opposite.

Financing also remains a meaningful drag. Net finance expense did fall to $28.1 million from $30.9 million, but that is still a large number for a business that is effectively a single-asset holding layer. And there is another point under the surface: as the company moves from expansion into harvesting, part of the spending that was capitalized in 2025 will stop sitting quietly on the balance sheet and will return through depreciation, finance cost or both.

Competition matters less than the contract terms

At a superficial level Tamar can be framed against Leviathan and Karish as a simple competitive story. In practice, the key question right now is less about who else sells gas and more about the terms under which Tamar sells, through which pipes and under what commercial and regulatory certainty. Israel Electric still represented 42% of revenue, BOE 34% and Dalia 9%. BOE also accounted for 59% of trade receivables at year-end 2025. The company says credit risk is low because of the security mechanism and past experience, but concentration of that size still deserves to be called by name.

Cash Flow, Debt and Capital Structure

Two cash pictures, and they need to be kept separate

Tamar Petroleum has to be read through two different cash lenses. The first is normalized / maintenance cash generation: cash flow from operating activities before taxes and levies reached $207.6 million. That is a good picture of the asset's underlying cash-producing power before the state takes its share and before financing and capital-allocation choices are applied.

The second, and more relevant for financial flexibility, is all-in cash flexibility. After income tax and levy, operating cash flow fell to $151.1 million. From there the company still had to pay $61.0 million of bond principal, $33.4 million of interest, a $30 million dividend, and $52.8 million of investment in oil and gas assets and other long-term assets. On that bridge, operating cash did not by itself cover all actual uses of cash, and the company also relied on pulling down deposits to preserve liquidity.

That is the heart of the story. A reader seeing $207.6 million before taxes and levies could conclude that the company throws off a very large cash surplus. Once the full cash picture is laid out, 2025 looks more like a year in which strong operating cash did not automatically become clean excess liquidity. That is why the $100 million dividend approved after year-end looks far less obvious when viewed through the cushion question.

The refinancing fixed the maturity profile, not the dependence on capital structure

At the end of 2025 the company had two bond series outstanding, $349.5 million in Series A and $305.3 million in Series B, alongside total liquidity of $115.2 million and net financial debt of $577.7 million. The 44% LTV looks manageable, and the covenant room itself is not tight. Historical debt-service coverage was 1.89, economic equity stood at $1.073 billion, and reported equity was about $448 million, well above the floors.

But the early-2026 refinancing changed the quality of risk. Tamar Petroleum received $300 million of loans and a $100 million revolving credit line. In return, the bank received a pledge over 7.5% of Tamar Petroleum's Tamar rights. At the same time, 9.25% of the company's Tamar rights were already pledged to holders of Series A. In other words, almost the entire 16.75% Tamar holding now sits under a split lien structure. That is not a technical detail. It means value exists, but access to that value is already divided among multiple creditor layers before common shareholders.

The bank terms tell the same story. The covenants do not look pressing against 2025 numbers: minimum economic equity of $350 million, net financial debt to EBITDA not above 4.5, LTV not above 75%, and historical and forward debt-service coverage not below 1.1. So this is not a wall-coming-at-you story. It is a story of a company that can refinance on decent terms because the base asset is strong, but pays for that access with liens, a reserve deposit and tighter control over cash movement.

What can mislead a reader

It is easy to read the Series B redemption as though Tamar Petroleum cleaned up its balance sheet. That is not what happened. The company executed a debt swap and also said it expects to recognize about $10 million of additional finance expense in the first quarter of 2026 because of the early redemption. In addition, on February 22, 2026 the Tamar venture signed a settlement with the Tax Authority over prior levy years, and the company estimates an additional payment of about $14 million. None of these items threatens stability on its own, but together they are a reminder that parties outside the core operating flow still take cash out of the structure.

Outlook and Forward View

First finding: 2026 looks like a bridge year, not a breakout year. Tamar's field sales forecast rises to 12.1 BCM in 2026 and 13.7 BCM in 2027, but that jump still depends on the compressors, FAJR, transportation capacity and actual demand. This is not volume that is already sitting in the bank.

Second finding: the expansion does not create equal value at every layer. At the operating layer it raises the production ceiling. At the commercial layer it opens room for more exports and new contracts. But at the shareholder layer it also brings more investment, more depreciation, potentially more levy, and a continued need to keep financing tight. Capacity growth should therefore not be translated automatically into accessible equity value.

Third finding: the Kesem contract and future demand are better understood as proof that Tamar remains relevant, not as proof that cash flow will immediately become cleaner. Up to 0.8 BCM per year is an important number, but it is not yet the same thing as a near-term cash engine. It still depends on a power plant that has not yet entered commercial operation and on consumption that has to materialize over time.

Fourth finding: the domestic story can still move even without an operating event. Tamar Petroleum chose not to join the October 2025 memorandum of understanding with Israel Electric, and on December 9, 2025 Israel Electric initiated LCIA arbitration seeking up to a 10% reduction in the gas price applied to the minimum billable quantity from January 1, 2025. Against a customer that represents 42% of revenue, that cannot be pushed into the footnotes.

The next year should therefore be judged through four checkpoints. First, whether the compressors are actually completed so the step-up in capacity becomes real instead of remaining partly theoretical. Second, whether FAJR progresses on time so that more exports become genuinely available in the second half of 2026. Third, whether the dispute with Israel Electric is resolved without doing too much damage to the domestic anchor price. Fourth, how aggressive the distribution policy remains after a $100 million dividend.

In that sense, 2026 is not a proof year for the field itself. Tamar has already proved the quality of the asset. It is a proof year for the listed wrapper, the debt structure and the company's ability to turn expansion spending and volume forecasts into a more credible and more accessible cash story.

Risks

The first risk is value access. As long as 7.5% of the rights are pledged to the bank and another 9.25% are pledged to Series A, almost none of Tamar Petroleum's Tamar holding can be viewed as fully free. That does not eliminate the value of the asset, but it does constrain the freedom to refinance, sell, distribute or restructure around it.

The second risk is domestic pricing, not only export pricing. The main 2025 hit came from Brent, but any forward view also has to track Israel Electric. If the arbitration ends in a meaningful price cut, it would hit exactly the layer that is supposed to balance export volatility.

The third risk is cumulative execution. Each project on its own looks reasonable: the third pipeline is done, the compressors are expected soon, FAJR is 86.8% complete, Nitzana is moving and new development wells were approved. But once all of that is stacked onto the same years, even a small delay in each item can push back the point at which added capacity really becomes more sales and more cash.

The fourth risk is concentration. The company depends on one field, three main customers and specific export routes. BOE alone represented 34% of revenue and 59% of receivables at the end of 2025. The company says the security mechanism reduces credit risk, but concentration at that level still raises the thesis' sensitivity to any commercial or logistical disruption.

The fifth risk is capital allocation. A $100 million dividend in April 2026 can be read as a vote of confidence. It can also be read as a reduction of the protective layer just as compressors, export projects, the Israel Electric arbitration and the new wells all move into investor focus. The answer to which reading turns out to be correct will only come in the next reports.

Conclusions

Tamar Petroleum exits 2025 in a better operating position than the headline decline in earnings suggests. Tamar kept selling at almost stable volumes, the domestic market strengthened, the first expansion stage was completed, and the company managed to replace Series B with bank financing before any real stress emerged. But the equity story is still not clean, because that value still has to pass through financing, liens, levies, follow-on investment and an unusually large dividend.

What is likely to drive the market's near- to medium-term reaction is not another reserves line or another slide showing 15 BCM in 2030. The market will focus on whether the compressors are actually finished, whether FAJR stays on schedule, whether Israel Electric can push down the anchor price, and whether enough room still remains for shareholders after all of that.

Current thesis: Tamar Petroleum still sits on a high-quality gas asset, but in 2026 the story is about monetization and capital structure, not only about a strong reservoir.

What changed this year is that the central bottleneck moved from a nearby Series B maturity to the question of what really remains after refinancing, liens and the dividend.

The strongest counter-thesis is that this view is too cautious: LTV is low, covenant room is wide, exports are about to expand, and the dividend itself signals management confidence in the company's cash-generating power.

What could change the market reading over the near to medium term is the combination of three things: completion of the compressors, a not-too-damaging resolution on pricing with Israel Electric, and evidence that the company can carry both the investment path and the distribution policy without narrowing the cushion further.

Why this matters: with Tamar Petroleum, the question is not whether there is value in the field. There is. The question is how much of that value remains accessible to common shareholders after the state, creditors, infrastructure needs and capital allocation take their share.