Equital: Tamar After Phase One, Where the Real Value Unlock Still Depends

The main article argued that the Equital question is not whether Tamar is a high-quality asset. That part is already settled. The real question is how quickly that quality turns into accessible value rather than just earnings or paper value. The completion of Tamar's first expansion phase on February 9, 2026 can easily look like the moment when that bottleneck finally breaks. That is too fast a reading.

What the filings actually show is a different shift. The heavy offshore and platform work has moved forward, but the bottleneck has now migrated to the edge of the system: the compressors at the Ashdod reception facility, the export transport chain, and one very large customer that keeps the pricing question open. Tamar is now less about whether the reservoir can produce, and more about whether the surrounding system can carry, route, and price the expansion properly.

That is the thread that deserved its own continuation. If one reads Tamar only through the February immediate report, it is easy to think the value unlock has already happened. In reality, even after phase one, the move to as much as 1.6 BCF per day is still not complete, broader exports still depend on external infrastructure and timing, Nitzana has already become a heavy capital commitment, and the arbitration with Israel Electric can affect not only future pricing but also the quality of revenue already recognized.

What Was Actually Completed, and What Still Is Not

The February immediate report matters, but it has to be read all the way through. The first phase of Tamar's expansion project was indeed completed on February 9, 2026. It included a third flowline from the wells to the platform, offshore infrastructure, work on the platform, and work at the Ashdod reception facility. The updated cost of phase one stood at about $640 million on a 100% project basis at the approval date, with Isramco Negev 2's share at about $184 million. By December 31, 2025 roughly $630 million had already been invested on the project basis, including about $181 million at Isramco's share.

But phase one is not the whole expansion. The annual report states explicitly that after phase one, Tamar's maximum gas supply capacity into the INGL system stands at about 1.15 BCF per day. That is the hard number after the event. The target of as much as 1.6 BCF per day still depends on the compressor upgrade at the Ashdod reception facility, a separate project that received FID in February 2024 with a total budget of about $24 million, or about $7 million at Isramco's share, and that was still not complete when the financial statements were approved.

That sounds technical, but it is the key point. Anyone jumping from the completion report straight to 1.6 BCF per day is skipping the remaining missing link at exactly the point where gas exits the production system and enters the transmission system. In the immediate report, the operator estimated the compressor upgrade would be completed in the coming weeks, but that same report also carried a clear warning about equipment availability, service providers, regulatory approvals, and the security situation. So phase one removed a real piece of execution risk, but it did not yet complete the capacity jump the market may be tempted to assume.

Put differently, Tamar has moved from a phase of heavy offshore construction into a phase of onshore completion and system integration. That is real progress. But for anyone focused on value realization, the next critical reading point is no longer the third pipeline that has already been laid. It is the Ashdod compressor work that still has to finish the job.

The Bottleneck Has Shifted to Export Routes

Even if Tamar reaches the higher production target, that still does not mean the full commercial value is unlocked. For the expansion to become wider exports, the asset needs more than available gas. It needs available transport. On that point, the filings are much less celebratory than the phase-one headline.

Tamar supplied 10.05 BCM in 2025, almost unchanged from 10.09 BCM in 2024. Of that, 3.07 BCM went to Egypt and 0.20 BCM to Jordan, versus 3.22 BCM and 0.19 BCM respectively in 2024. So the actual starting point is not an export base that was already accelerating in 2025. To break that ceiling, Tamar's partners need more than an upgraded reservoir and platform. They need a functioning export chain.

The annual report lays out that chain fairly clearly:

The strongest proof point here sits inside the amended BOE export agreement. Tamar's partners committed to a base contractual quantity of about 2 BCM per year, plus an additional 4 BCM per year from the date the additional quantities start flowing. The original start date was July 1, 2025, with up to a 90-day delay if the expansion works were not completed, and with further delay if a force majeure event occurred. In practice, BOE was told that the partners estimated the start date would be delayed into the first quarter of 2026.

But the most important clause is another one: the inability to actually deliver all or part of the additional quantities because of lack of transmission capacity or lack of system availability does not count as a breach under the circumstances defined in the agreement. That is a very important reminder that commercial success and infrastructure success are not the same thing. Tamar can have the contract, can have the added production capability, and can still spend time with value waiting on transport.

The tactical move recorded after year-end reinforces the same reading. In December 2025 Chevron notified INGL on behalf of Tamar's partners that the full base capacity would be diverted to the Jordan North line, and in January 2026 INGL approved that diversion effective April 1, 2026. That is not a side note. It shows that the system is still leaning on an interim route before Nitzana exists. In other words, if anyone wants proof that the bottleneck has shifted from below the sea to the transport system, this is it.

Nitzana Is No Longer a Future Idea. It Is a Capital Commitment

Nitzana is often described as a future pipeline. In the filings it has already become a balance-sheet item. This is one of the places where readers can miss the gap between a strategic headline and the actual cash regime underneath it.

Under the October 2025 transport agreement, the estimated budget for the Nitzana project is about $609 million on a full-project basis. Tamar's allocation in the Ramat Hovav Nitzana line is 41.8%, which puts Tamar's share of the base budget at about $255 million, including about $73 million at Isramco's share. But the report does not stop at that budget. INGL is allowed to update the estimated budget by up to 12%, excluding CPI and FX adjustments, and in a separate agreement Tamar's partners also committed to bear 50% of excess costs at the compressor station beyond the fixed cost defined in the construction arrangement.

At the approval date, Chevron estimated those excess costs at about $64 million on a 100% project basis. That means another roughly $32 million for Tamar's partners and about $9.2 million at Isramco's share. This is how the estimated total funding burden for Tamar's partners rises to about $286 million, including about $82 million at Isramco's share. This is no longer a vague future option. It is a heavy capital commitment that has already entered the thesis.

By the end of 2025 Tamar's partners had already invested about $161 million in Nitzana, including long lead items, with about $46 million at Isramco's share. That matters for two reasons. First, it shows that Nitzana is not simply a 2028 story. It was already consuming cash in 2025. Second, it explains why Equital's consolidated balance sheet already carries NIS 322.9 million under investments in export infrastructure upgrades to Egypt, investments that only begin to amortize once the system enters use.

This is where the distinction between future value and current unlock becomes critical. If Nitzana stays on time and on budget, it can materially widen Tamar's export flexibility. If it keeps getting more expensive or slips further, part of Tamar's improvement will still sit as higher capacity without a full monetization path. For Equital that matters because the route from a strong reservoir to accessible cash still runs through a subsidiary, a partnership, covenant logic, and capital that is already tied up inside a project that is not operating yet.

Kesem Opens Future Demand, Israel Electric Reopens the Price Question

The clearest way to read Tamar right now is through two contracts pulling in opposite directions. The Kesem Energy agreement says Tamar has real future demand. The Israel Electric arbitration says the price on a very large share of gas already sold is still not fully settled.

Start with Kesem. In April 2025 Tamar's partners signed a natural-gas sales agreement with Kesem Energy for a combined-cycle power plant to be built near the Kesem interchange. The agreement became effective only on February 22, 2026. Commercial supply is expected to begin in 2029, at a maximum annual quantity of about 0.8 BCM, for five years or until January 1, 2035, whichever is later. In other words, Kesem is an important demand signal, but not a 2026 fix and not a 2027 fix. It deepens Tamar's commercial future, not the immediate value unlock after phase one.

Israel Electric is different because it is a current-period issue. In 2025 it represented about 42% of Isramco Negev 2's gas-sale revenue, well above any other customer. A non-binding memorandum of understanding was signed in July 2025 between some of Tamar's partners and Israel Electric, but the window for the remaining partners to join expired in October 2025, and in December 2025 Israel Electric opened arbitration in London. The demand is material: it wants the gas price for the minimum committed quantity to be reduced effective January 1, 2025 by the maximum rate permitted under the agreement, 10%. On January 6, 2026 Tamar's partners rejected the claim.

The analytical meaning goes deeper than a legal headline. In the note on critical estimates, the company states that revenue recognized from the Israel Electric amendment is based on an estimate of the expected weighted gas price per unit across the full minimum billing quantity and the operational commitment through the end of the contract. It also states explicitly that the recognized revenue may change mainly because of assumptions around price adjustment at the relevant dates, including the arbitration. That is a point the market can easily miss on first read. The dispute with Israel Electric is not only a threat to future pricing. It also speaks directly to the quality of revenue already sitting in the accounts.

That is why Kesem and Israel Electric do not offset each other in time. Kesem adds future optionality from 2029 onward. Israel Electric already has the capacity to change the interpretation of 2025 and 2026. Anyone reading Tamar only through the amount of gas it may export is missing the fact that its largest customer has reopened the price question at the same time.

Conclusion

The completion of phase one at Tamar is a real event. It reduced execution risk, effectively closed out almost the entire phase-one budget, and moved the center of gravity from heavy offshore buildout to connection, transport, and commercialization. But it still has not unlocked the full value. At the approval date, Tamar stood at about 1.15 BCF per day after phase one, not 1.6. To reach 1.6, the Ashdod compressor work still has to finish. To turn added production into meaningful export growth, Tamar still needs the external transport systems, the marine segment, and ultimately Nitzana. To protect earnings quality, it also needs to resolve the pricing question with Israel Electric.

That is why the right reading for Equital after February 2026 is sharper, but also more patient. Tamar no longer looks like a field struggling to expand. It looks like a field that has expanded and now has to prove that everything around the field can keep up.

Over the next 2 to 4 quarters, the four most important checkpoints are these:

• Completion of the Ashdod compressor upgrade and a practical move from 1.15 toward the target of as much as 1.6 BCF per day.
• Evidence that the additional BOE volumes are flowing through the system in practice, not mainly remaining at the contract level.
• Budget discipline and schedule discipline at Nitzana, which has already become a material capital commitment.
• A clearer outcome in the Israel Electric process, whether through agreement, ruling, or at least a better sense of how much of the 2025 price base really holds.