PetroTx in the First Quarter: Gas Prices Restored Profit, Debt Still Sets the Pace
PetroTx moved back to profit in the first quarter on stronger gas prices, lower costs and a friendlier accounting impact from gas hedges. Cash still declined, the 24-month cash forecast depends on deferred payments, a small rights issue and controlling-shareholder support, and the Baxterville completion work remains outside the funded base case.
The first quarter makes PetroTx look better than the net profit line alone suggests: the partnership moved from loss to profit, operating profit turned positive, and production costs declined after the Alabama field sale at the end of 2025. But this is still not a clean business inflection. Reported revenue barely grew at the headline level, and the real ex-Alabama improvement came mainly from higher gas prices while both gas and oil volumes declined. Operating cash flow was positive, yet cash fell to only $650 thousand after bond principal and interest payments. The more important signal sits in the 24-month cash forecast: getting through the next two years depends on deferred management fees and royalties to controlling shareholders, a small equity raise, royalty-payment scheduling and future oil and gas prices. The quarter improves the profit picture, but it does not remove the active bottleneck: how a small and commodity-sensitive asset base funds bonds, legacy royalties and future development that still lacks a clear funding source.
Company Snapshot
The partnership is a very small oil and gas exploration and production vehicle focused on assets in the United States. Its active assets are mainly in Mississippi and Texas, and its economics are simple but highly sensitive: volumes sold multiplied by commodity prices, less royalties, operating costs, depletion and finance costs. This is an existing-asset cash and leverage story, not a fast growth story. The real question is not whether one quarter can show accounting profit, but how much cash remains after debt service and what investment is required to preserve or increase production.
The current operating map is clearer than before. Mississippi is the core asset: it contributed $1.63 million of the $2.03 million first-quarter revenue, while Texas contributed $311 thousand and Alabama contributed $96 thousand from transportation and other services. Oil and gas asset investments on the balance sheet are also concentrated in Mississippi, with $19.0 million of the $19.5 million total. Texas exists, but it does not change the risk profile on its own.
Baxterville is the point that keeps the story from becoming simple. The partnership has two horizontal wells drilled in late 2022, and completing them is intended to support higher gas output in Mississippi. The partnership currently has no financial resources to complete that work. It is reviewing alternatives, including bringing in a partner to fund the work, raising equity or raising debt. Until that happens, the potential sits above the current cash flow, not inside it.
Gas Prices Restored Profit Before Production Recovered
First-quarter revenue was $2.03 million, up only 4% year over year. That direct comparison is slightly misleading because Alabama was sold at the end of 2025. Excluding Alabama, revenue increased by $459 thousand, or about 29%, mainly because the average gas price rose by about 39%. At the same time, sold gas volumes declined by 4.6% and sold oil volumes declined by 8%. Profitability improved before the operating base strengthened.
The return to positive operating profit came from two directions. The first was the gas price, which averaged $5.49 per unit in the quarter. The second was the cost base: oil and gas production costs, including depletion, fell to $851 thousand from $1.33 million in the comparable quarter. A meaningful part of that improvement reflects the Alabama sale and lower depletion, not only operating efficiency that can be repeated at the same pace every quarter.
Net profit also received accounting help. Net finance expenses fell to $118 thousand from $1.05 million in the comparable quarter, mainly because of changes in the value of gas-price hedges. The current quarter included $67 thousand of derivative income, compared with an $825 thousand derivative expense a year earlier. That is nearly a $0.9 million swing in finance costs, and it explains a large part of the move from a $1.15 million loss to $344 thousand of net profit.
The hedge position matters for the forward read. The partnership did not enter new hedge transactions during the quarter, but at the end of March 2026 it had open SWAP positions for 412.5 thousand MMBtu through the end of 2026, at an average hedge price of $3.46. That provides some protection, but it also shows that first-quarter profit benefited from an average gas price well above the future average prices referenced for 2026 and 2027. If actual prices move closer to those forward levels rather than to the first-quarter level, improvement will have to come from volumes, costs or financing, not only from price.
The All-In Cash Bridge Is Still Tight
This is where operating cash flow has to be separated from all-in cash flexibility after actual cash uses. Operating cash flow was $680 thousand, a positive figure relative to the partnership’s scale. But after $100 thousand of net controlling-shareholder loan inflow, $1.01 million of bond principal repayment and $231 thousand of bond interest, cash declined by $460 thousand. That is the all-in cash flexibility after actual first-quarter cash uses, and it is still narrow.
The balance sheet explains why it matters. Cash fell to $650 thousand against current liabilities of $6.6 million and a consolidated working-capital deficit of about $4.9 million. The auditor drew attention to this position, and the partnership was required to present a 24-month cash forecast. At the end of March it was compliant with the Series B bond covenants: equity of $9.1 million versus a $6 million minimum, net financial debt to EBITDA of 2.1 times versus a ceiling of 6 times, and net financial debt to net CAP of 28% versus a ceiling of 70%. The issue is not an immediate covenant breach. The issue is how little room remains between current operations, debt service, legacy royalties and future investment.
The cash forecast makes that point clearly:
| Point in Time | Forecast Cash Balance | Main Cash Burden |
|---|---|---|
| End of Q2 2026 | $161 thousand | A $580 thousand payment for the identified royalty owner, alongside an equity raise of about $189 thousand |
| End of Q4 2026 | $899 thousand | An additional equity raise of about $211 thousand and positive cash flow, with no bond repayment in that quarter |
| End of Q1 2027 | $110 thousand | Bond repayments and finance costs of about $1.2 million |
| End of Q1 2028 | $113 thousand | Bond repayments and finance costs of about $1.16 million in the final quarter of the forecast |
This is not only an operating forecast. It includes financing assumptions and controlling-shareholder behavior. The controlling shareholders committed to exercise all of their rights, to support the capital raise so that their equity investment reaches at least $400 thousand if total proceeds fall short, and to provide up to $150 thousand in January 2027 if needed for the bond repayment. In practice, the post-balance-sheet rights issue raised about $189 thousand, leaving about $211 thousand of remaining controlling-shareholder investment commitment. That improves the probability of getting through the payment schedule, but it also shows that the operating business alone still does not create a comfortable cushion.
Two note-level points are the main yellow flags. The first is legacy royalties: there is a liability of about $3 million for unidentified third-party royalty owners, and in April the partnership reached an arrangement to transfer $100 thousand per year to the State of Mississippi from 2026 through 2031, with the $2.4 million balance due by November 1, 2032, subject to the partnership’s financial capacity and to those amounts not being paid to unidentified royalty owners. In addition, a royalty owner identified in December 2025 is owed about $0.6 million, and the partnership is still negotiating a 12-installment payment schedule. The second point is that the forecast excludes planned future investments in oil and gas assets in Mississippi and Texas because their execution remains uncertain. In other words, the forecast tests the cash survival of the existing base, not full funding for a production step-up.
Conclusion
The first quarter is better on an accounting basis, but it does not yet prove that the partnership has moved into a comfortable financial position. Profit came from a mix of stronger gas prices, the removal of Alabama from the base, lower depletion and production costs, and a sharp improvement in the derivative line. Against that stands an all-in cash bridge that is still being squeezed by bond principal and interest, and a forecast that reaches trough cash balances of a little more than $100 thousand.
For investors, the point is not that the partnership faces an immediate wall. The market is more likely to measure it by three narrow items: whether actual gas prices remain high enough versus the forecast assumptions, whether the raises and controlling-shareholder support arrive on time, and whether royalty payments are scheduled without consuming the cash base. The real improvement point would be the ability to fund the Baxterville completion, or a similar development step, without forcing another heavy dilution or debt burden on unitholders. Until then, first-quarter profit is a positive signal, but funding remains the bottleneck, not the income statement.
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