Tamar Raises Capacity, Sales and Distributions Decide Shareholder Cash

The May 29 Tamar filings mark a real operating step: from May 28, maximum daily production capacity increased to about 1.35 BCF (billion cubic feet of gas), after two of the three compressors at the Ashdod receiving facility were upgraded. Tamar is now between the first expansion stage completed in February and the target of up to about 1.6 BCF per day, which still requires the third compressor. The update improves the reservoir's ability to serve demand, but it does not give every listed security the same cash outcome. Actual sales still depend on Israeli and export demand, transmission capacity and additional supply agreements. The same reservoir event reaches a direct partner, a royalty company and a holding company through different routes. The next proof point is no longer only engineering progress. It is the volume of gas sold, the customers that receive it and the cash that moves into distributions.

Two Compressors Have Already Changed Production Capacity

ISRAMCO, TAMAR PETROLEUM, NAPHTHA, EQUITAL and TOMER ENERGY published nearly identical filings on May 29. The operator, Chevron Mediterranean Limited, notified the Tamar partners that maximum daily capacity had increased to about 1.35 BCF per day. The new point is not the existence of the expansion project. It is that Tamar has already crossed part of the gap between prior capacity and the expansion target.

On February 9, the first expansion stage was completed. It included a third transmission pipeline from the wells to the production platform, offshore infrastructure, the platform and the Ashdod receiving facility. At that date, the compressors had not yet been upgraded, so the target of up to about 1.6 BCF per day still depended on that work.

At the end of March, Tamar was still presented with maximum production capacity of about 1.15 BCF per day, alongside the operator's estimate that the compressor upgrade could lift the reservoir to up to about 1.6 BCF per day. The May 29 filings place Tamar between those two points: below the full target, but above the capacity that existed before two Ashdod compressors were completed.

In the gas sector, a reservoir creates value for investors when available capacity meets customers, transmission, prices, taxes, debt service and distributions. About 1.35 BCF per day is a stronger operating base. Its effect on each listed exposure depends on the company's place in the cash route.

Sales Still Have to Fill the Capacity

The filings define the economic limit of the progress: actual gas sales depend on domestic demand, export demand, transmission capacity and additional supply agreements. That is the route through which Tamar capacity becomes revenue and cash.

The domestic side has one concrete support point. On February 22, the gas sales agreement with Kesem Energy became effective after the buyer met its financing condition. The gas is intended for a combined-cycle power plant near the Kesem interchange. That gives Tamar a specific domestic demand route rather than only a general expectation of higher electricity consumption.

The export path is less immediate. At the end of March, about 93% of the work on the transmission upgrade outside Israel had been completed, against a budget of about $176.5 million, after cumulative Tamar partner investment of about $144 million. Completion is estimated for the second half of 2026. The Nitzana project in Israel's transmission systems had accumulated investments of about $127 million, while its estimated completion date is the second half of 2028. The offshore Ashdod-Ashkelon section is expected in the third quarter of 2026.

The domestic allocation order can also affect the new capacity. A draft emergency gas regulation published for public comments on March 26 proposed absolute priority for Israeli domestic consumers, so exports would be allowed only if additional quantities remain after domestic allocation. The regulation has not been published in binding form, but it shows why production capacity is not enough on its own.

Production capacity is now advancing faster than parts of the transmission and export systems. Blue Ocean Energy is the clearest example: in April, the Tamar partners notified it that the start date for additional quantities had been deferred because of equipment and contractor availability issues defined as force majeure. The May 29 filing shifts the focus from the reservoir itself to the sales, transmission and contract path.

Direct Exposure Differs From Royalties and Holding Companies

For ISRAMCO and TAMAR PETROLEUM, the link between added capacity and the financial statements is the most direct. ISRAMCO holds 28.75% of Tamar, and TAMAR PETROLEUM holds 16.75%. If more capacity becomes sales, they should see it through their share of gas revenue, operating cash from the reservoir and distribution capacity after investments, taxes and debt service.

There is still no shortcut. ISRAMCO approved a distribution of about $70 million on May 17, before the new capacity filing, which shows that Tamar already produces distributable cash. The next question is whether incremental capacity increases that base without being absorbed by transmission investments, export delays or contract timing. For TAMAR PETROLEUM, the same point is sharper because the company is a focused Tamar exposure.

TOMER ENERGY is different. It is not a Tamar working-interest partner, and its Q1 disclosure states that it holds rights to receive overriding royalties (a royalty on sales value before some costs) from Tamar and Dalit. Additional capacity helps only if it increases the revenue base from which the royalty is calculated. If capacity is not sold, or if sales are delayed by export timing, the cash effect can be weaker than the operating change at the reservoir.

NAPHTHA and EQUITAL receive the Tamar event through a holding chain. NAPHTHA holds Israeli oil and gas activity through ISRAMCO, alongside U.S. activity and real estate. EQUITAL holds oil and gas through NAPHTHA and real estate through Airport City. The increase in Tamar capacity therefore has to pass through actual sales, reservoir surplus, distributions from the partnership, subsidiaries and then holding-company distribution decisions.

That chain can move cash. On May 6, NAPHTHA approved a dividend of about NIS 200 million, and EQUITAL's share through Yoel is expected to total about NIS 177 million. The distribution proves that cash can move up the group. It does not prove that the new capacity has already moved through the same route.

RATIO, NAVITAS PETRO and MODIIN belong to the energy universe, but they are not direct Tamar-capacity exposures. RATIO is tied to Leviathan, NAVITAS PETRO operates in international oil and gas projects, and MODIIN is an exploration and development partnership. They are relevant sector context, not direct cash routes from this filing.

The Next Proof Comes From Volumes, Contracts and Distributions

The Tamar read now depends on three proof points. The first is completion of the compressor upgrade and progress toward up to about 1.6 BCF per day. The second is actual sales, especially if additional quantities reach export agreements and domestic power customers. The third is cash movement: distributions by the direct partners, royalties reaching TOMER ENERGY, and cash moving through NAPHTHA to EQUITAL. Until that evidence appears, the May 29 filing is an important operating improvement for Tamar, not proof that every listed exposure has already received the same cash benefit.