Isramco 2025: Tamar Is Getting More Capacity, but the Cash Still Depends on Price, Midstream and Distribution Discipline

Getting To Know The Company

At first glance, Isramco can look like a simple story: a 28.75% holding in Tamar, some optionality at Shimshon, regular distributions, and a unit that effectively trades around a NIS 6 billion market cap. That description is not wrong, but it misses the real economics. In practice this is not a diversified growth platform. It is a partnership whose current cash generation comes overwhelmingly from one asset, Tamar, and whose next stage depends on whether added physical capacity can actually pass through pricing formulas, export pipes, royalties, tax and distribution discipline.

What is working now is fairly clear. Tamar kept operating reliably, total gas sold in 2025 was almost unchanged at about 10.05 BCM, domestic sales even rose to 6.78 BCM, the first phase of the Tamar expansion was completed after year-end in February 2026, and the gas agreement with Kesem cleared its conditions precedent and entered into force. This is no longer a partnership talking only about reserves on paper.

The active bottleneck sits somewhere else. 2025 showed that for Isramco, more potential volume still does not equal more cash. Revenue from gas and condensate sales, net of royalties, fell from $430 million to $412 million even though total sales volume barely moved. The main reason was not weak demand, but a lower average realized gas price, mostly because export contracts are Brent-linked. So even before reaching the 1.6 BCF per day discussion, the report already makes one thing clear: the economics sit on price, not only on molecules.

That is also what a superficial reader can miss. Anyone looking only at roughly 271 BCM of 2P reserves, a PV-10 of about $1.953 billion, or the higher daily capacity target can easily think the story is now just about opening the taps. That is only part of the picture. The real 2026 question is whether the new capacity, and the capacity still to come, will reach the right customers, at the right price, without the partnership having to bridge the gap through more debt and more refinancing.

The structure of the story also matters. Isramco is not a standard operating corporation. It is a limited partnership run through a general partner, and public unitholders are exposed almost entirely to what Tamar generates and what can then be distributed. So the value question is not only how much the field earns, but how much remains after royalties, levy, financing cost, investments, repayments and distributions.

The quick economic map looks like this:

That chart sets the read early. Tamar is still producing strong numbers, but 2025 was not a clean economic breakout year. It was a year in which the system kept working while price weakened and the partnership moved closer to the stage where it has to prove that new capacity can actually become accessible value.

Events And Triggers

The physical project moved forward, but not yet all the way to full monetization

The first trigger: the first phase of the Tamar expansion was completed on February 9, 2026. That matters because it lifted Tamar's maximum production capacity to about 1.15 BCF per day. But that is still not the end of the story. To reach up to 1.6 BCF per day, the compressor upgrade at the Ashdod receiving terminal still has to be completed, and the report itself warns that completion could be delayed by the security situation.

This matters because a lot of the current narrative is already treating the bottleneck as if it were gone. In practice it has only been pushed further down the chain. Under the existing dual-pipeline system Tamar is still capped at roughly 1.15 BCF per day, and the report explicitly defines that as the current bottleneck of the production system. The first phase solved part of the issue, not all of it.

The money already spent behind that move is also meaningful. By December 31, 2025 investment in the first expansion phase had reached about $630 million on a 100% basis, of which Isramco's share was about $181 million. That is already real cash out the door, not a future plan.

Added field capacity will not become cash without export midstream

The second trigger: even after the compressors are completed, the cash still has to move through export infrastructure. That is where the gap opens between nameplate capacity and capacity that can actually be monetized.

The export-system upgrade outside Israel was already 86% complete at year-end 2025, with a targeted completion in the second half of 2026 and a budget of about $176.5 million for Tamar partners, Isramco's share about $50.7 million. In parallel, the Nitzana project entered into force in October 2025, with an estimated Tamar-partner share of about $286 million, Isramco's share about $82 million, and a targeted completion only in the second half of 2028.

The important point here is not just timing. It is the quality of the commitment. In Nitzana there are already estimated excess costs above the fixed compressor-station cost, and Tamar partners' 50% share of those excess costs is estimated at about $32 million, Isramco's share about $9.2 million. So the future export path comes with cost risk, not only with demand upside.

Kesem adds demand proof, not near-term cash

The third trigger: the gas agreement with Kesem entered into force on February 22, 2026 after all conditions precedent were met. That is clearly positive because it confirms that Tamar partners have additional future outlets for gas, not only reliance on the current customer base.

But the timing matters. Commercial supply is expected to begin only in 2029. Volumes are up to about 0.8 BCM per year on a firm basis, for five years or until January 1, 2035, whichever is later, and total revenue at the Tamar-partner level is estimated at roughly $700 million to $800 million. In other words, the contract is important as a commercial signal, but it is not the solution for 2026 or 2027 cash flow.

Domestic pricing is still open

The fourth trigger: in July 2025 a non-binding memorandum of understanding was signed between some Tamar partners and IEC on a gas-price adjustment effective January 1, 2025, an adjustment to the operating price effective July 1, 2028, and an option for additional supply in 2026 to 2028 plus roughly 2 to 3 BCM per year in 2031 to 2035. But in September 2025 the general partner's board decided it was not in the partnership's interest to promote the amendment at that stage, and in December 2025 IEC opened arbitration in London asking for the maximum 10% reduction from January 1, 2025.

That is a real yellow flag. IEC accounted for 42% of 2025 revenue. So Isramco cannot be read only through Brent and export. A large part of the economics still runs through a domestic anchor buyer that is actively pressing for a lower price.

Sheshinski uncertainty and funding uncertainty both narrowed, but neither disappeared

The fifth trigger: in February 2026 a settlement was signed with the Israel Tax Authority in relation to disputed Sheshinski levy years and agreed adjustments for 2023 to 2024 levy reports. The partnership estimates the additional payment at about NIS 69 million, roughly $22 million, but also makes clear that this had no material 2025 P&L effect because the provision had already been updated earlier.

At the same time, in January 2026 the undrawn $40 million balance of the long-term credit line was extended to January 10, 2027, with any amount drawn becoming a loan of up to seven years. That is not a distress signal, but it is a clear reminder that the partnership still wants flexibility against an investment queue that remains open.

Efficiency, Profitability, And Competition

The core 2025 story is not weaker activity. It is weaker monetization quality. Tamar sold almost the same amount of gas as in 2024, but less money stayed with Isramco.

Revenue from gas and condensate sales, net of royalties, fell from $430 million to $412 million. EBITDA fell from $348 million to $334 million. Net profit fell from $145 million to $116 million. That is not a collapse, but it is also not the year in which expansion already pushed the partnership into a better economic tier.

That is the central read of 2025. The problem was not that Tamar could not sell gas. The problem was that the pricing structure more than offset the stability in volumes.

The mix shifted slightly toward the domestic market, but not enough to offset export pricing

In 2025 domestic-market sales rose to 6.78 BCM from 6.68 BCM. Egypt volumes fell to 3.07 BCM from 3.22 BCM, and Jordan rose slightly to 0.20 BCM from 0.19 BCM. So the weakness did not come from a collapse in demand. It came from a combination of maintenance work in the fourth quarter and the fact that the export-linked part of the business became less supportive on price.

That chart prevents a common reading mistake. It is easy to look at 2025 and conclude Tamar lost volume. That is not what happened. The partnership actually strengthened the domestic share slightly. But when the export piece is Brent-linked, even a moderate drop in price can erase the improvement in mix.

Two customers still carry most of the economic read

IEC and BOE remain the two main revenue anchors. In 2025 IEC accounted for 42% of revenue, up from 37% in 2024. BOE accounted for 34%, down from 38%. The rest came from private power producers, industrial customers and a Jordanian customer.

That means the market should read Isramco not only through broad gas demand, but through specific contracts. The IEC contract is already in live arbitration over price. The BOE contract includes a Brent-based formula with a floor, and if average Brent in a contract year drops below $50, the buyer can reduce the annual minimum quantity by up to 50% with respect to non-additional volumes. Even if this was not triggered in 2025, it is a reminder that demand is not just a function of capacity. It is also a function of contract quality.

The fourth quarter was a reminder of what happens when the system slows down

In the fourth quarter Tamar sold about 2.15 BCM versus 2.47 BCM in the comparable quarter, mainly because of roughly 16 days of maintenance work. Net revenue fell to $93 million from $108 million, and EBITDA dropped to $66 million from $85 million. Net profit still rose slightly to $40 million from $37 million, but that was not because the business became structurally stronger. It was the result of a different combination of levy, financing and provisioning effects.

That is a useful reminder that even after higher capacity is installed, a single-asset partnership remains highly sensitive to any operating interruption, planned or otherwise.

Cash Flow, Debt And Capital Structure

Isramco needs to be read through two different lenses, and mixing them up is a mistake.

On solvency and covenant metrics, the balance sheet still looks comfortable

At year-end 2025 net financial debt stood at about $330 million, versus $300 million at end-2024 and $298 million at end-2023. Gross debt stood at about $441 million, against roughly $111 million of cash, securities and deposits. At the same time, the PV-10 of 2P reserves stood at about $1.953 billion, so net financial debt was only around 17% of PV-10.

Put simply, this is not a partnership that looks unable to service debt today. The financial covenants also still look comfortably away from the edge. The report explicitly states compliance with both the bank and bond covenants, and the debt remained rated ilAA, with Maalot revising the outlook to stable from negative in August 2025.

The flexibility layer also still exists. Out of the $150 million long-term facility, $110 million has been drawn and $40 million remained undrawn and was extended to January 2027. In addition, there is a $100 million short-term line that was undrawn as of the financial statement approval date. So the story here is not near-term liquidity stress tomorrow morning.

On an all-in cash flexibility basis, the picture is tighter

This is where the lens needs to change. If the question is not "is Isramco solvent" but rather "how much cash really remains after all uses," 2025 looks different.

Operating cash flow was strong at $229 million. But against that sat real cash uses: $113 million of bond principal repayment, $13 million of interest paid, $130 million of distributions, $39 million of investment in oil and gas assets, $51 million of investment in transportation infrastructure, and $73 million of investment in deposits and restricted deposits. So once the full picture is taken into account, operating cash by itself was not enough.

The analytical point is sharp. Isramco is still generating strong operating cash, but it is no longer living only off that cash. 2025 also included a new bond issuance of about NIS 416.4 million net, roughly $124.7 million, and an additional $40 million bank draw. Without those two sources, the cash gap for the year would have been material.

That is why 2025 is better described as a funding bridge between a strong asset and a heavy queue of investments and distributions, not as a year of clean excess cash.

Even the distribution story now requires more discipline

Isramco distributed about $130 million in 2025, more than annual net profit of $116 million, and almost 57% of operating cash flow. That is not automatically the wrong move, because Tamar is still a mature, high-quality producing asset. But it does mean that "strong cash flow" now has to be read together with the question of whether distributions are being paid from true surplus, or from a strong asset that is simultaneously carrying expansion, export midstream, repayments and cash-buffer management.

Outlook And Forward Read

Finding one: 2026 looks more like a bridge year than a harvest year. Tamar's expansion is moving, but the most important monetization channels for the added capacity do not fully mature this year.

Finding two: the bottleneck has shifted from the subsea segment into the monetization chain. The compressors are not finished yet, the export-system upgrade outside Israel is targeted only for the second half of 2026, Nitzana only for the second half of 2028, and Kesem only begins in 2029.

Finding three: Tamar's investment queue does not end with the first expansion phase. In December 2025 Tamar partners approved a final investment decision for two new development wells, Tamar 12 and Tamar 3ST, in a total budget of about $466.5 million on a 100% basis, Isramco's share about $134 million, with execution expected to begin in the second half of 2027 and continue into the fourth quarter of 2028.

Finding four: the reserve uplift at Tamar SW is real, but not frictionless. Reserves now include the state's share of the field following the August 2025 arrangement, but Isramco is paying an additional 5.9% override royalty from July 2025 and completion still depends on conditions precedent and negotiations with the remaining expired Eran license holders.

The next year will be tested on conversion, not on headlines

Management does not use these words, but analytically 2026 is a conversion year. The asset already works, reserves are large, regional demand looks supportive, and in Egypt the report itself points to a 2025 gas deficit of about 20.4 BCM, with imports of about 21.4 BCM against exports of only about 1 BCM. At the same time, the report cites an outside forecast under which Israeli gas demand could grow by about 31% by the end of the decade. In other words, demand is not the main weak point here.

The question is different: how much of that demand will actually flow to Tamar, through which pipes, under which contracts, at what price, and with how much additional capital still needed before it gets there.

What has to happen for the thesis to strengthen

The first event is completion of the Ashdod compressor upgrade without a meaningful delay. Until that happens, the 1.6 BCF per day target remains a target rather than a reality.

The second event is continued progress in the export-system upgrade outside Israel toward the second-half-2026 target. Without it, even if Tamar can physically produce more, its ability to convert that into export sales remains constrained.

The third event is greater clarity on price. If the IEC arbitration ends without a material hit to the anchor domestic price, and if the export contracts keep holding the floor on price and quantity, the market will have a better basis for believing that extra capacity can become real value.

The fourth event is capital discipline. Isramco has to show that even with ongoing investments, with Tamar 12 and Tamar 3ST ahead, and with distributions continuing, debt is not becoming a permanent bridge between every distribution and every project.

Risks

The first risk is single-asset concentration

Almost all of Isramco's current economics sit on Tamar. Shimshon, Dekel and Dalit are not current cash substitutes. Dalit is still classified as a contingent resource dependent on project approval and a reasonable expectation of gas sales, and Dekel remains a pre-drill prospect. So any disruption, delay or pricing erosion at Tamar hits almost the entire story at once.

The second risk is customer concentration and contract structure

When 76% of revenue comes from two customers, pricing formulas matter more than broad demand headlines. IEC is already in arbitration with the partnership. BOE remains tied to Brent and to volume-adjustment mechanisms. This is not a theoretical risk. It is part of the actual profit engine.

The third risk is that new capacity gets stuck in the middle of the chain

Field expansion, compressor upgrades, the export system outside Israel and Nitzana are not the same project. Any one of them can delay the next step. So even if field capacity rises, the ability to convert it into sales at the right pace still depends on a chain of projects, regulation, equipment availability and the security environment.

The fourth risk is that the distribution cushion narrows before the growth arrives

2025 already showed that the partnership can generate a lot of operating cash and still need external financing once distributions, repayments and investments are all included. If the investment queue remains heavy and price remains less supportive, distributions to unitholders could increasingly depend on financing choices, not only on operating surplus.

The fifth risk is that Tamar SW is still not fully closed economically

The removal of Tamar SW's production cap rests on the August 2025 agreement with the state, but if the conditions precedent are not satisfied by April 16, 2026 or a later agreed date, the parties would need to reach alternative arrangements, and if that fails the agreement could terminate and the production cap could return. In addition, negotiations are still ongoing with the remaining rights holders in the expired Eran license. So even the reserve uplift still comes with a regulatory and commercial friction layer.

Short Sellers

The short-interest data does not point to a crowded bearish position in Isramco. As of March 27, 2026 the short position stood at about 8.08 million units, with an SIR of 1.66 and short float of 0.40%. That is below the sector average in short float, 0.54%, and slightly below the sector average in SIR, 1.718.

The read from that is simple. The market may be skeptical about how fast capacity becomes cash, but it is not leaning aggressively against the name through unusually crowded short positioning. This looks less like a classic market fight and more like a fundamental debate around monetization, pricing and capital structure.

Conclusions

Isramco ends 2025 with a good base asset, a regional demand backdrop that still supports the story, and real physical progress at Tamar. That is the positive side. The main blocker is that the partnership still has not proved that the added capacity will quickly become more free cash, mainly because export pricing weakened, the price versus IEC is open, and the investment and funding layer remains heavy. In the near and medium term, the market is likely to react far more to compressor completion, export-midstream progress and contract clarity than to another large reserve number.

Current thesis in one line: Tamar is getting physically stronger, but Isramco still has to prove that this strengthening will reach unitholders as real cash rather than getting stuck in price, midstream or funding.

What changed: in 2025 the central question stopped being whether Tamar can work and became whether more capacity, more reserves and more future contracts truly change the distribution economics now rather than only in a longer-dated narrative.

The counter-thesis: this read may prove too cautious, because demand still looks supportive, Kesem is already in force, the first expansion phase is complete, and the balance sheet still looks far from stressed. If the compressors are completed on time and pricing remains reasonable, Isramco could look stronger already by 2027.

What could change the market interpretation: timely completion of the compressors, progress in export midstream, a reasonable outcome in the IEC arbitration, and proof that distributions are not eating into cash flexibility.

Why it matters: because in Isramco the value is not set by gas volume alone, but by how much of that gas can actually be sold through a route, at a price and under a capital structure that allows it to become sustainable distributions.

What must happen over the next 2 to 4 quarters: the compressors need to be completed, the export-system upgrade outside Israel needs to keep moving toward its second-half-2026 target, domestic pricing clarity needs to improve, and the partnership needs to preserve capital discipline while Tamar investment continues. What would weaken the thesis is a compressor delay, additional pricing pressure, or a continued situation in which each distribution step also requires another layer of financing.