Lapidoth-Heletz 2025: Cash Is Ample, but Heletz Is Still Stuck in Permits

Company Overview

Lapidoth-Heletz at the end of 2025 may look, at first glance, like an oil exploration partnership with reserves, a reserve report, and a familiar field. In practice, it is currently a cash-heavy balance sheet with a regulatory option on the Heletz field, not an active oil producer. What is working today is the financial layer, interest income on cash and gains on marketable securities. What is not working is the operating core investors would expect to see here, the restart of production.

That is also the active bottleneck. The partnership holds 100% of the Heletz lease, but production can begin only after it receives the required planning and building approvals. As of the report date, the plan was still waiting to be scheduled for discussion before the district planning committee, while the Environmental Protection Ministry continued to challenge parts of the development plan, especially the reactivation of Heletz 3. So anyone who reads only the reserve tables may think this is mainly a geology story. It is not. Right now it is a planning, environmental, and capital-allocation story.

What does attract attention now is easy to see. At the end of 2025 the partnership had NIS 104.1 million of cash and cash equivalents and another NIS 28.3 million of short-term securities, together NIS 132.5 million of liquid assets. Against that, the oil asset on the balance sheet fell to just NIS 5.8 million, only about 4.2% of total assets. In plain terms, the market looking at Lapidoth-Heletz today sees cash first and the field second.

The immediate market screen adds another layer of friction. Based on the trading snapshot from April 3, 2026, the equity market value stood at about NIS 97.3 million, roughly 26.6% below year-end liquid assets, while daily turnover was only NIS 4,878. That means the debate in the units is not just whether the cash exists. It is whether that cash will ever turn into accessible value for unit holders, and whether there is a real trigger that can move the story from waiting to producing.

Four points a quick read can miss:

• 2025 profit did not come from oil. It came from interest income and securities gains. Economically, this is currently a portfolio-and-cash vehicle.
• The report already contains a timing crack: the reserve section still assumes production resumes in 2026, while the impairment note has already shifted expected restart to 2027.
• The regulatory dispute is no longer generic. It specifically touches Heletz 3, which the Environmental Protection Ministry says should not be reactivated.
• The partnership has no employees, and about 72% of 2025 purchases and service spending came through Lapidoth, management fees, or the general partner. Even the cost base still runs through the controlling group.

The economic map looks like this:

Events and Triggers

The permit is the event, not the reserve table

The central event for Lapidoth-Heletz is still not a drilling campaign, a sale, or a strategic partner. It is a planning discussion that has still not happened. The partnership filed a detailed plan back in September 2018, an updated version in September 2019, submitted an environmental impact statement in November 2021 and supplemental materials in July 2022, yet by the report date it was still waiting for the plan to be scheduled for discussion by the district planning committee. The war delayed the discussion that had been expected in 2023, and in 2025 the partnership mainly added another legal opinion at the planning bureau's request.

That matters because the story is not blocked by a lack of field data or a lack of reserves. It is blocked by the absence of an approved execution path. In resource names, investors can easily get drawn to reserves, contingent resources, and discounted cash flow tables. Here, without approvals, those numbers remain option value rather than operating cash flow.

The Heletz 3 dispute is no longer a side issue

The dispute with the Environmental Protection Ministry became more concrete in 2024, when the ministry argued that Heletz 3 sits in an area of high ecological sensitivity and therefore should not be put back into use. The partnership disputes that view and keeps promoting the well as part of the development plan. This is material, not peripheral. It means the regulatory delay is no longer just a generic timeline issue. It touches the shape of the development plan itself.

The question of historical environmental damage also remains partly open. The partnership continues to argue that it has no legal duty to remediate land it did not contaminate, while at the same time it carries provisions for soil and water contamination treatment and for well sealing obligations. So even if the planning process advances, the environmental layer does not disappear. It merely changes form, from a broad dispute into a more concrete execution cost.

The report itself is already moving the clock

One of the most interesting points in the filing sits inside the filing itself. The reserves and contingent resources section still says the reserve opinion assumes production will restart during 2026. But Note 7, the impairment section for the oil asset, explicitly says the expected restart was updated during 2025 to 2027. This is not just a wording nuance. It suggests the internal picture is not clean even within the same annual report.

The market implication is straightforward. As long as the document itself carries that gap, investors are unlikely to fully underwrite the more optimistic timeline. So even if reserve volumes barely moved, the market can remain unimpressed.

The trading screen adds its own actionability limit

The short-term market trigger is not just the permit. It is also liquidity. A daily turnover of only a few thousand shekels makes any repricing slow, and at times almost random. That is why the discount to cash can persist for a long time even when the balance sheet looks comfortable. This is not a short-interest story, there is no short-interest data available here. It is a thinly traded security where the market is waiting for hard proof, not just a neat balance-sheet number.

Efficiency, Profitability and Competition

The central point in 2025 is that Lapidoth-Heletz's profitability is not oil-field profitability. It is securities-portfolio profitability and interest income on cash. Total income rose 36.5% to NIS 13.395 million, but the composition tells the real story: NIS 9.215 million came from fair-value gains, interest, and dividends on securities measured through profit or loss, while another NIS 4.180 million came from finance income on deposits.

That is exactly what a first read can miss if it looks for signs of operating production returning. The partnership did not sell oil, did not generate production revenue, and did not run an active field. 2025 was a better year at the bottom line, but it was better because capital markets and interest rates were supportive, not because the Heletz asset resumed economic activity.

The expense structure tells a similar story. This is not the cost base of an active producer. In 2025 the partnership recorded NIS 393 thousand of operating costs, NIS 1.161 million of oil-asset impairment, NIS 2.978 million of general and administrative expense, and NIS 837 thousand of finance expense. In other words, the heavier lines are still headquarters, impairment, and FX-related items, not the cost of running a producing field.

There is also an earnings-quality issue. Comprehensive profit rose to NIS 6.168 million, up 32.0% from 2024, but cash flow from operating activity fell to only NIS 128 thousand. The gap between a NIS 6.2 million profit figure and essentially flat operating cash flow is not an accounting error. It reflects the fact that much of the profit came from fair-value movements rather than from cash generated by the field.

Even the cost base underlines that the operating platform is not yet independent. The partnership has no employees, it is managed through the general partner, and the report explicitly says Lapidoth supplies a material share of the drilling-related materials and services. In addition, purchases from Lapidoth, management fees, and general-partner-related service items totaled NIS 2.042 million in 2025, or 72% of all purchases from suppliers and service providers. Anyone looking for an autonomous operating moat needs to recognize that the partnership still relies heavily on the controlling group.

From a competition perspective, the field is not really competing today in an active production market, because there is no production. So the more relevant competitive question right now is about access to drilling services, contractor availability, and project cost inflation. The company itself says changes in crude prices affect contractor and equipment availability as well as project cost. That means even if approval arrives, the economics of restarting production will depend not only on barrels in the ground, but also on service cost and timing.

Cash Flow, Debt and Capital Structure

Cash flexibility is wide, but not because the existing business is productive

If we use an all-in cash-flexibility frame, Lapidoth-Heletz looks comfortable. It has no financial debt, its activity has been funded entirely from equity, and year-end liquidity consisted of NIS 104.1 million of cash and cash equivalents plus NIS 28.3 million of short-term securities. In that sense, balance-sheet room is real.

But if we switch to a normalized cash-generation frame, the picture changes materially. The existing business, meaning a partnership with no current production, does not really generate meaningful operating cash from an active oil asset. Cash flow from operating activity was only NIS 128 thousand. So Lapidoth-Heletz's current strength is not operating strength. It is stockpiled cash.

That distinction matters. Investors are not buying a producer that funds itself today. They are buying an entity with enough capital to finance waiting, and which appears capable of covering an initial development phase as well, if and when approval arrives.

The securities portfolio is both a cushion and a source of volatility

That cushion does not sit entirely in plain bank deposits. Out of NIS 132.5 million of liquid assets, NIS 28.3 million was held as financial assets measured at fair value through profit or loss, including about NIS 24 million invested in the VAR Equity hedge fund. That means about 18.1% of the partnership's liquidity already sits in a market product.

That helps explain 2025 profit, but it also adds another layer of volatility. According to the sensitivity tables, a 10% move in the securities portfolio would change profit or loss by about NIS 2.834 million, while a 10% move in the dollar would change profit or loss by about NIS 1.383 million. So even before the field moves, Lapidoth-Heletz's reported numbers remain sensitive to capital markets and FX.

There are obligations, but not a classic funding-pressure story

Total liabilities at the end of 2025 stood at only NIS 7.194 million, of which NIS 5.149 million related to environmental provisions, well-sealing obligations, and similar items. That provision actually fell by about NIS 237 thousand during 2025. At the same time, the partnership maintains a US$2 million autonomous bank guarantee in favor of the state in connection with the Heletz lease, extended through December 31, 2027.

This is not a covenant or bank-wall story. It is a picture of a partnership whose main risk is not an overburdened balance sheet but a field that keeps waiting, plus environmental and regulatory obligations that can drag on longer than expected.

If the story turns, the cash pile will stop being a cash pile

Another point that matters: according to the discounted cash flow tables, the initial development phase carries net capital costs of about US$8.092 million in the opening development year. So even if the story finally moves forward, the cash will not remain idle cash. It will start becoming project investment. That is the core distinction between cash that exists today and value that is actually accessible to unit holders.

Outlook and Forward View

Finding one: 2026 still looks like a regulatory bridge year, not a clean production year.
Finding two: the recognized reserve base still exists, but it is much smaller than the broader resource envelope, so it is important not to confuse option value with certified reserve value.
Finding three: the field's economics remain highly sensitive to discount rate, oil price, and timing, so another delay can keep eroding accounting value even without a change in reserve volumes.
Finding four: if approvals do advance, the partnership has enough cash to fund an initial development phase without near-term debt pressure.

So the right question for 2026 is not whether there is oil in the ground. It is whether a real path is finally opening to produce it. In year-type terms, this is neither a breakout year nor a reset year. It is a waiting year with a sharp regulatory proof test. If the plan reaches committee discussion and moves forward, the market can start looking at the cash not just as a cushion but as executable capital. If that does not happen, Lapidoth-Heletz will remain for another year a partnership that earns from markets while holding an option on a field, not an operating production business.

The reserve tables themselves provide an anchor, but also a disciplined framework. As of January 1, 2026, the partnership presents 607 thousand barrels of 1P reserves, 955 thousand barrels of 2P reserves, and 1.369 million barrels of 3P reserves. That is the currently recognized reserve base. Beyond that, there is a broader contingent-resource layer, 3.108 million barrels at 2C and 7.848 million barrels at 3C, but the company itself says these relate to the Dolomite development project, whose chance of realization is less than reasonable, and therefore they cannot be treated as reserves.

That distinction is critical in resource names. Anyone mentally adding 3C into the current investment case is missing the difference between identified upside and a reserve base that can support today's economics.

The discounted cash flow tables also need careful handling. In the summary NPV table, after-tax 2P value stands at US$16.40 million with no discounting, US$11.14 million at a 5% discount rate, US$7.72 million at 10%, US$5.41 million at 15%, and US$3.79 million at 20%. In other words, field value is extremely sensitive to cost of capital and time. The company explicitly warns that these figures represent present value, but not necessarily fair value.

That sensitivity is already flowing through the accounts. The impairment note uses after-tax discount rates of 18.5% for Heletz 3 and 13.75% for Heletz A41, and shows that a 5% move in the discount rate can shift the oil asset's value from NIS 5.8 million down to about NIS 4.8 million or up to about NIS 7.25 million. So timing is not just a narrative issue. It is one of the economic variables driving asset value.

What must happen over the next 2-4 quarters for the thesis to strengthen? First, the plan has to reach committee discussion and move onto a clearer approval path. Second, the partnership needs to show how the Heletz 3 dispute is resolved, because that goes directly to the core development plan. And third, it needs to show the market how the cash pile moves from passive financial holding to financing a development program with a credible timetable.

Risks

The first risk is regulatory and environmental. As long as the permit process does not advance, field economics remain delayed. Beyond that, the company itself says it cannot currently estimate the economic significance and scope of historical environmental remediation. That is not proof of an immediate cash drain, but it is real uncertainty.

The second risk is single-asset concentration. Lapidoth-Heletz does not own a diversified producing portfolio. It owns the Heletz lease. That means there is no operating diversification. If Heletz does not move, there is no alternative production engine.

The third risk is capital allocation. The partnership is allowed to invest its cash to preserve value and generate return, and it is clearly doing that today. But as long as there is no production, those returns can also blur the reading of the business by creating accounting profit that looks stronger than the underlying field economics.

The fourth risk is related-party dependence. There are no employees, Lapidoth provides staffing and drilling-related services, and a large share of supplier spending runs through the controlling group and the general partner. That does not automatically make the structure problematic, but it does mean investors need to assess governance and capital allocation, not just geology.

The fifth risk is value accessibility. The market is already showing that it will not fully credit cash or reserves without a credible timeline to production. With trading liquidity this thin, that discount can remain in place for a long time.

Conclusions

Lapidoth-Heletz ends 2025 with one very reassuring fact and one very unresolved one. The reassuring part is the balance sheet, a large cash position, no financial debt, and real funding flexibility. The unresolved part is that the operating activity the partnership exists for still has not restarted, and even inside the report the timetable is already slipping. In the near term the market is likely to focus less on the number of barrels and more on whether the committee process finally moves, whether Heletz 3 stays in the plan, and whether the cash pile starts to look like development capital rather than another year of waiting.

Current thesis: Lapidoth-Heletz is currently a cash vehicle with a regulatory option on Heletz, not an active producer.
What changed versus the prior reporting cycle: the cash pile grew, profit rose, but the field itself slipped another step in timing, and the gap between reserve-case value and executable value became clearer.
Counter thesis: if approvals advance, the current discount looks too harsh for a debt-free vehicle with 100% of the lease and a recognized reserve base.
What could change the market reading in the short-to-medium term: a real committee discussion, a constructive update on Heletz 3, or, on the other side, another timeline push beyond 2027.
Why this matters: because the real debate here is not whether subsurface potential exists, but whether that potential will ever become accessible value for unit holders.

Over the next 2-4 quarters the thesis strengthens if the planning process advances, if the Heletz 3 dispute becomes clearer, and if the market gets a credible development bridge between the cash pile and the field. It weakens if 2027 turns out to be optimistic as well, or if the balance sheet keeps generating financial-market profit while the operating asset remains stuck in place.