EONR — Q2 2026 Financial Report Analysis

EON Resources is a small oil producer with two waterflooded fields in the New Mexico part of the Permian Basin. In the second quarter of 2026 its oil and gas sales rose 50% to $5.44M, almost entirely because oil sold for $95.79 a barrel against $65.37 a year earlier. The net loss narrowed to $0.69M from a restated $2.96M. That improvement came from below the operating line, though. The operating loss widened to $1.27M from $0.32M. Hedges gave back $21.68 of every barrel's price, and costs per barrel rose. The 10-Q was filed on October 22, more than two months after the normal deadline. It still carries going-concern doubt, with $0.69M of cash against a $22.6M working-capital deficit.

Results

Q2 2025 figures are as restated in this 10-Q (Note 11). The restatement took the originally reported Q2 2025 net loss of $1.30M (-$0.06 a share) to $2.96M (-$0.13). A BOE (barrel of oil equivalent) counts six thousand cubic feet of gas as one barrel of oil, so oil and gas volumes can be added together.

Higher oil prices, mostly given back by hedges

The average NYMEX oil price was $95.75 a barrel in Q2, against $64.63 a year earlier. EON sold at $95.79 before hedges. A hedge here is a contract that locks in a price range on part of future production. It protects the company when prices fall and costs it money when they rise. In Q2, settled hedge contracts cost EON $1.21M in cash, or $21.68 a barrel. A year earlier they had added $6.90. After hedges, EON got $74.10 a barrel against $72.26, so most of the 48% jump in oil prices never reached the company.

The $0.95M "gain on derivatives" in revenue combines that $1.21M realized cash loss with a $2.16M unrealized gain. The unrealized gain is a paper revaluation of contracts that haven't settled yet. It reverses Q1, when the same contracts lost $3.27M on paper. For the half year, hedges cost $2.63M, $1.52M of it in cash. At June 30 the hedge book was a $1.05M net liability, against a $0.06M asset at December 31.

Operations got more expensive, not less

• Lease operating expense (LOE, the day-to-day cost of running the wells) was $2.51M, or $40.79 per BOE. That compares with $39.43 a year ago and $37.02 in Q1. The filing blames "additional cost related to the South Justis Field."
• Production taxes, transportation and processing rose to $0.70M from $0.32M. That is 13% of oil and gas sales, against 9%.
• General and administrative costs (overhead) rose 31% to $2.38M, or $38.59 per BOE, "primarily due to increased professional fees." The restatements and late filings are not free.
• Depletion (DD&A, the non-cash charge that spreads the cost of the oil fields over the barrels produced) rose to $2.14M from $0.46M. Per BOE it went from $7.66 to $34.70. The filing gives two reasons. Development spending on the Seven Rivers waterflood added to the cost base. Fewer barrels now count as proved reserves, because an extra 5% overriding royalty was conveyed to Virtus and some reserves were reclassified from proved to probable.

Field costs, production taxes and overhead added up to about $90.80 per BOE, against a realized $68.69 after hedges. G&A includes some non-cash stock compensation ($0.68M for the half year), but the gap is still wide. Our rough calculation from the filing's line items: oil, gas and water-service revenue, minus settled hedges, production taxes, LOE and G&A, comes to about -$1.26M for the quarter, before depletion and unrealized hedges. The same calculation gives about -$0.36M for Q2 2025.

Takeaway: Oil near $96 should have been the quarter that turned EON cash-positive. Instead, hedges took back $21.68 a barrel, production fell 11% from Q1, and field costs and overhead rose, so the operating loss widened to $1.27M. The smaller net loss comes from 2025's debt costs dropping out and non-cash revaluation gains. It does not show the business earning more.

What the headline numbers hide

The net loss improved for reasons outside operations. In Q2 2025 there was $3.17M of non-operating expense: $1.65M of interest, a $0.91M loss on exchanging notes for convertibles, and a $0.76M fair-value loss on conversion features. This quarter those items netted to a $0.004M gain. Interest fell to $0.18M after the senior term loan and private notes were paid down and settled in 2025. Fair-value gains of $0.35M on note conversion features and $0.44M on the CEO's founder-share put option offset $0.61M of debt-discount amortization. Both fair-value items depend on EON's share price and can reverse in a later quarter. A $0.58M tax benefit, booked by reducing the deferred tax liability, also cut the loss. No cash comes in from it.

Revenue includes paper gains. Without the $2.16M unrealized hedge gain, the operating loss would have been about $3.43M.

Positive cash flow came from paying bills later. Operating cash flow for the first half was +$0.21M, against -$2.30M a year earlier. Q1 alone was -$0.31M, so Q2 brought in roughly $0.5M. But revenue and royalties owed to other interest owners grew $2.09M in six months to $7.11M. Accrued liabilities added $1.03M of cash, while receivables rose $0.94M. Holding on to royalty owners' money is not a lasting funding source.

Deferred pay became debt. In the half year, officers, directors and other employees agreed to turn $3.45M of unpaid salary and bonuses into promissory notes at 15% interest, due July 2029. That is why "related party notes payable" jumped to $3.75M from $0.20M. The company is still being kept running partly by its own people choosing not to be paid in cash.

Expensive short-term funding. Two new merchant cash advances in May and June brought in $1.47M of cash. A merchant cash advance is a lender buying future receipts for cash today. EON must repay $2.11M in weekly instalments through February 2027, about 43% more than it received, within nine months. On October 9, 2026, EON borrowed another $1.5M unsecured at 28% interest, with 165,000 warrants attached.

Dilution is doing much of the work in EPS. The loss per share fell to -$0.01 partly because the average share count rose from 22.6M to 55.4M. Shares outstanding stood at 55.4M at June 30.

Controls and the restatement trail. Management again concluded that disclosure controls were not effective. The material weaknesses it lists include too few accounting staff, a lack of segregation of duties, and accounting for complex financial instruments. Q2 2025 was restated in this filing. On October 13 the company also filed a 10-K/A restating FY2025, which cut FY2025 DD&A by $3.54M and the net loss by $2.63M. After the quarter, the IRS opened an examination of the 2023 federal tax return (no amount accrued). The 10-Q itself arrived about ten weeks after the usual 45-day deadline for a quarterly report.

Going concern. The note says substantial doubt "has not been alleviated." The $150M White Lion equity line has raised $11.1M so far from 17M shares sold. It can't be used until a new S-1 registration is effective, and the filing says that is still the case.

Did last time's read hold up?

Our Q1 2026 report named three things to watch. The Q2 10-Q did arrive, but only on October 22, long after its deadline. The S-1 that would reopen the equity line is still not effective. LOE per BOE did not fall back toward the low $30s; it rose to $40.79. None of the three moved in EON's favor.

Outlook

The filing gives no production, cost or capital-spending guidance. Management's plan is unchanged: cut costs, keep hedging proved production, and sell shares once the S-1 is effective. Spending on the oil fields was $2.49M in the first half, paid for with $2.82M from new convertible notes rather than from operations.

EON produces about 680 BOE a day from 438 net wells, down from 472 a year earlier. At that size, it needs LOE and overhead together well below $60 per BOE, or hedges that let it keep more of high oil prices, before it can cover its costs. Neither is in view in this filing. Three things to watch in the Q3 2026 10-Q, normally due in mid-November: whether it arrives on time; whether production recovers toward Q1's 759 BOE a day as injector wells come back online; and whether the S-1 becomes effective. Until it does, the 28% notes and merchant cash advances are the only funding in sight, and their cost adds to the losses.