Oil Above $100 Hits Producers, Refiners and Airlines Differently

Brent's move above $100 on July 23 is not good news for every energy company, nor equally bad news for every airline. Navitas, Energean, InPlay and Modiin market oil output, so the price reaches revenue relatively quickly, but hedges, available production and debt determine how much remains in cash flow. For NewMed and Ratio, Brent enters only some gas-pricing formulas under defined contract terms. Bazan and Ashdod Refinery market refined products, making crack spreads, margin hedges, inventory value and funding more important than the crude price alone. Paz and Dor Alon can pass prices to customers, but they fund inventory and taxes before completing collection. At El Al, unusually thin remaining hedge coverage leaves more of the jet-fuel increase exposed. This is a ranking of the speed and directness of price transmission, not a valuation ranking or a share-price forecast.

Producers Receive the Price Quickly, but Not on Every Barrel

The most direct exposure belongs to companies currently producing and selling oil. Even within that group, output and hedging matter at least as much as the screen price.

Navitas averaged roughly 55 thousand boe per day net in the first quarter, including about 42 thousand barrels of oil per day. That is direct exposure, but Shenandoah's financing agreements require portions of forecast production to be hedged unless coverage ratios permit relief. A higher price lifts revenue on unhedged barrels, not every barrel with equal force.

At Energean, a July operating change increased the size of the exposure itself. The second liquids train expanded FPSO processing capacity from 18 to 31 thousand barrels per day. The company expects second-half liquids production of 17 to 21 thousand barrels per day, up from 10 thousand in the first half. Capacity is not revenue, but delivery within that range would tie a larger share of sales to Brent while the price is elevated.

InPlay produced 8,813 barrels of oil per day in the first quarter. Against that, it had second-quarter hedges covering 5,165 barrels per day through swaps and collars, with some upside capped around $62 to $72. It is a direct producer, but price certainty has already replaced much of its immediate upside exposure.

Modiin completed the purchase of a 12.5% interest in the producing Big Foot field in July. The acquired interest was producing roughly 4,500 to 5,000 boe per day when the transaction was signed, about 96% oil. Alongside the direct commodity exposure is approximately $91 million of bank financing with coverage ratios, a reserve account and a cash-sweep mechanism. Higher oil improves asset revenue but does not ensure immediate cash transfers to the partnership.

Delek Group has an additional holding-company layer. Ithaca produced roughly 126 thousand boe per day in the first quarter, but cash reaches the parent only after the subsidiary's investment, hedging and distribution decisions. A high oil price that reduces hedge values is not automatically equivalent to a higher parent dividend.

Israeli gas does not offer the same shortcut. NewMed provided an explicit 100% Leviathan revenue calculation: about $2.55 billion for 2026 using a $63 Brent assumption, versus approximately $2.88 billion using an average of around $90 with all other variables unchanged. The roughly $330 million increase proves that the linkage matters, but it is not a linear $100 sensitivity. In the first quarter, a 33-day shutdown and lower sales volume outweighed the potential pricing benefit.

Refiners Earn the Crack Spread and Fund the Inventory

For refiners, expensive crude immediately raises inventory value and the credit needed to acquire it. Operating profit improves only when gasoline, diesel and other product prices rise by more than crude and logistics costs.

Bazan reported a first-quarter adjusted refining margin of $12.7 per barrel, up from $6.8 a year earlier. It had also hedged 7.3 million barrels of 2026 refining margin at an average of about $13.5 per barrel. As margins rose, the company deposited approximately $69 million against margin calls by the end of March. In early May, the remaining 4.2 million barrels carried a hedge liability of roughly $47 million. The hedge protects economic margin but draws cash before physical sales settle.

The company also accelerated the purchase of 1.5 million barrels of availability inventory in April. The inventory's current value was estimated at about $115 million, with payment deferred to October plus market interest. The transaction saved a recurring availability fee but converted expensive oil into a visible funding requirement.

Ashdod Refinery illustrates the accounting mismatch. The crude-price spike produced futures losses while inventory remained recorded at cost and did not immediately show the economic offset. Product-margin hedges carried a $54 million loss at the end of March, while 165 thousand tonnes of inventory remained unhedged. Despite strong margins, first-quarter operating cash flow was negative $62 million. High oil can therefore coexist with a good margin and cash pressure in the same report.

Distributors and Airlines Pay Before Passing the Price Through

Fuel distributors can update customer prices, but payment and collection are not symmetrical. Paz explains that higher product prices increase working-capital needs and financing costs while also producing temporary inventory gains. The company does not hedge petroleum-product price risk. Dor Alon recorded a NIS 3.7 million inventory gain in the first quarter, yet operating cash flow fell to zero mainly because working capital increased. Paying excise tax near procurement while extending longer credit to customers turns the oil price into a funding issue.

The cost direction is clearer for airlines. El Al monetized most of its June to December 2026 hedges in March and April following the fuel-price spike. At the end of March, outstanding transactions covered only about 14% of planned consumption through February 2027, alongside roughly $20 million of locked hedge income for June through December. Using the end-April curve, the company estimated that April to September fuel expense after hedging would be about $200 million higher year over year. Load factors, passenger yield and capacity now have to absorb more of the increase.

Israir said it was examining hedging mechanisms and updating product prices, but the prepared disclosure did not provide quantitative coverage comparable with El Al's. The two airlines therefore cannot be assumed to have equal protection.

Conclusions

The fastest exposure to Brent above $100 sits with producers that have live output and barrels not locked by hedges. Energean has just expanded liquids capacity, Navitas is already producing at scale, while InPlay and Modiin add different hedge and financing constraints. The Leviathan partnerships benefit under some contracts, but the effect is partial and still depends on sales volume and reservoir availability.

Refiners are not clean oil-price proxies. They require strong product margins and funding for inventory and collateral. Fuel distributors first face working-capital demand, while airlines face a recurring operating expense. El Al's reduced remaining protection makes fuel prices, passenger yield and capacity its most important near-term data. The comparison does not establish which share is cheap or expensive because the multiples, leverage and valuation bases are not cleanly comparable across these roles. It does establish where the next proof will appear: production and realized price for producers, formulas and volume in gas, spreads and collateral in refining, working capital in distribution, and fuel expense after hedging in aviation.