A US oil and gas company that owns minority stakes in thousands of oil and natural gas wells across the Williston Basin's Bakken and Three Forks formations in North Dakota and Montana, while other operators handle the drilling and day-to-day work. Founded in 2013 by energy executive Bob Gerrity, it became an independent public company in 2023 when it was spun off from Jefferies Financial Group. Its name comes from the French word for "speed," and its small team manages its huge well portfolio with a proprietary data system called Luminis.
A $40.2M unrealized hedging gain swung Vitesse to a $33.1M net profit, but debt rose to $158.5M as dividends continued to outpace operating cash flow.
A sharp drop in forward oil prices during the quarter turned a large unrealized hedging loss into a gain, flipping the . rose 11% to $91.0 million and net income was $33.1 million, driven by a $40.2 million non-cash unrealized gain on commodity derivatives that reversed most of the prior quarter's loss. The underlying business generated less cash than a year ago, and debt climbed to $158.5 million as dividends remained the priority.
Key takeaways
was $33.1 million, a swing from a $42.3 million net loss in Q1 2026, driven by a $40.2 million non-cash unrealized gain on commodity derivatives as forward oil prices fell from their March 31 highs.
rose 11% to $91.0 million as a 22% increase in average realized prices before hedging more than offset an 8% decline in production volumes.
General and administrative expense rose to $6.2 million from $0.3 million a year earlier, because the prior-year period included a $7.1 million reimbursement of litigation costs that did not repeat.
Section summaries
Management's Discussion and Analysis
Q2 FY2026 revenue rose 11% to $91M on higher oil prices, but hedging and a prior-year legal settlement masked underlying cost and volume trends.
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Total increased 11% to $91.0M, driven by a 22% rise in average realized prices before hedging, partially offset by an 8% decline in production volumes.
fell 62% to $25.4 million, and for the first six months of the year it was $49.5 million, down from $83.5 million, largely because the prior year included a $24.0 million one-time litigation settlement.
Total debt rose to $158.5 million from $124.5 million at year-end 2025, with $116.5 million still available under the $275 million , while the company paid $44.1 million in dividends during the first half of the year.
The company's commodity derivative position is now sensitive to a 10% move in oil prices by approximately $29 million, up from $9 million at year-end, amplifying the potential for large non-cash swings in reported .
What changed
The Q1 2026 watch item on the proved prescient: of $25.4 million in Q2 remained below the quarterly dividend obligation, and total debt rose to $158.5 million as the company continued to fund the payout with borrowings.
The amended hedge requirements tied to the $275 million , flagged in Q1, are now in effect; the sensitivity of the derivative portfolio to a 10% oil-price move has tripled to $29 million from $9 million at year-end, meaning reported will swing more with oil prices.
The increase flagged in Q1 persisted: DD&A expense rose, driven by higher per-barrel rates attributed to lower SEC oil prices used in reserve estimates, continuing the multi-quarter trend of rising non-cash charges per barrel produced.
The flagged in Q1 was not resolved: the company ended Q2 with just $0.9 million in cash and equivalents, down from $3.2 million at the end of Q1, as derivative-related liabilities continued to pressure liquidity.
What to watch
Whether the $0.525 quarterly can be maintained without further increasing debt, given that first-half 2026 of $49.5 million fell short of the $44.1 million paid in dividends and total debt has risen to $158.5 million.
The outcome of the next redetermination under the , which if reduced from the current $275 million could trigger mandatory repayment with $158.5 million in debt outstanding.
The mark-to-market impact of the crude oil hedge portfolio on reported , where a hypothetical 10% change in NYMEX WTI strip prices now swings the position by approximately $29 million, a threefold increase from year-end.
The trajectory of production volumes, which declined 8% in Q2, to see whether the drop reflects natural decline on Lucero properties or a one-time timing issue.
Oil grew 30% to $86.5M as NYMEX WTI averaged $92.38/Bbl, while natural gas revenue fell 70% to $4.5M due to lower realized prices and the absence of a prior-year legal settlement.
General and administrative expense surged to $6.2M from $0.3M, as the prior-year period benefited from a $7.1M litigation cost reimbursement.
A $22.0M commodity derivative gain was recorded, driven by a $40.2M unrealized gain as forward oil prices fell sharply from March 31 to June 30, 2026.
fell to $49.5M for the six months from $83.5M, largely due to a $24.0M one-time legal settlement received in the prior year.
Total debt stood at $158.5M with $116.5M available under the $275M , and $44.1M in dividends were paid during the first half of the year.
Quantitative and Qualitative Disclosures About Market Risk
Commodity price risk is the primary exposure, managed with derivatives; a 10% oil-price move impacts the derivative position by ~$29M.
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Oil and natural gas prices are volatile and heavily influence , but the exact income impact is indeterminable because expenses also fluctuate with prices.
The company uses derivative contracts ( and ) to reduce commodity-price volatility and achieve more predictable cash flows.
Derivatives are each period, with realized and unrealized gains/losses recorded in net gain (loss) on derivative instruments on the income statement.
A hypothetical 10% change in NYMEX WTI strip prices would change the net commodity derivative position by approximately $29.3M (decrease) or $29.0M (increase).
A hypothetical 10% change in Henry Hub-NYMEX strip prices, related , and NGL prices would change the net derivative position by approximately $1.5M (decrease) or $1.6M (increase).
Interest-rate risk arises from the floating-rate ; a 1% rate change would alter six-month by roughly $0.7M.
From time to time we are subject to legal, administrative and environmental proceedings before various courts, arbitration panels and governmental agencies concerning claims arising in the ordinary course of business. These proceedings include certain contract disputes, addition…
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From time to time we are subject to legal, administrative and environmental proceedings before various courts, arbitration panels and governmental agencies concerning claims arising in the ordinary course of business. These proceedings include certain contract disputes, additional environmental reviews and investigations, audits and pending judicial matters. Based on our current knowledge, we believe that the amount or range of reasonably possible losses will not, either individually or in the aggregate, materially adversely affect our business, financial condition and results of operations.
The results of any litigation cannot be predicted with certainty, and an unfavorable resolution in any legal proceedings could materially affect our business, financial condition and results of operations. Regardless of the outcome, litigation can have an adverse impact on us because of defense and settlement costs, diversion of management resources and other factors.
For additional information regarding our legal proceedings, refer to Note 9 (“Commitments and Contingencies”) to the Condensed Consolidated Financial Statements and to Part I, Item 3, Legal Proceedings, in our Annual Report on Form 10-K for the year ended December 31, 2025.
There have been no material changes to the risk factors disclosed in Part I, Item 1A. Risk Factors, of our Annual Report on Form 10-K filed with the SEC for the year ended December 31, 2025. 43 Table of Contents
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There have been no material changes to the risk factors disclosed in Part I, Item 1A. Risk Factors, of our Annual Report on Form 10-K filed with the SEC for the year ended December 31, 2025.
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