Northern Oil And Gas ((NOG)) has held its Q2 earnings call. Read on for the main highlights of the call.

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Northern Oil and Gas used its earnings call to stress that momentum is clearly turning in its favor. Management pointed to double‑digit EBITDA growth, a surge in free cash flow, record gas volumes and expanding inventory, while being frank about Waha‑related curtailments, higher LOE from aging wells and a stubborn valuation discount in the public market. Overall, the tone was constructive, with risks framed as manageable.

Strong Adjusted EBITDA and Free Cash Flow Improvement

Adjusted EBITDA climbed 17% sequentially as Northern Oil and Gas converted stronger pricing and production into higher cash earnings. Free cash flow jumped more than 400% from the prior quarter to $159 million, signaling a rapid improvement in cash generation that gives the company more flexibility for capital deployment.

Production Growth and Record Gas Volumes

Total production rose 9% year over year, underscoring continued growth across the portfolio. Natural gas volumes were the standout, hitting a record with 35% year‑over‑year growth and a 5% sequential increase, helped by the Utica joint venture in Appalachia plus outperformance in the Williston and Uinta basins.

Material Oil Price Realization Improvement

Unhedged net realized oil prices improved 36% from the first quarter, sharply boosting revenue leverage to crude markets. On the gas side, realizations ran near 90% of Henry Hub and, when hedges are factored in around the Waha basis, reached roughly 123% of the relevant benchmark, highlighting effective risk management.

Cost and Capital Efficiency Metrics

Production expenses per BOE fell 4% year over year, showing progress on operating cost control despite aging assets in the mix. Normalized well costs held steady at $761 per lateral foot, and the company spent $196 million in budgeted capex for the quarter, split between $151 million on drilling and completion and $45 million on its ground game.

Balance Sheet Strength and Liquidity

Northern ended the quarter with more than $1 billion in total liquidity, giving it ample capacity to support drilling, completions and opportunistic deals. Management repeatedly emphasized that the current balance sheet can fund both ongoing development and selective inorganic growth without stressing the company’s financial position.

Shareholder Returns and Buyback Activity

Shareholder returns were a major focus as the company repurchased 2.95 million shares, roughly 3% of shares outstanding, at an average price of $20.37. The board also lifted the buyback authorization to about $243 million and maintained a $0.45 per‑share quarterly dividend, which was covered several times over by second‑quarter free cash flow.

M&A and Inventory Expansion

On the deal front, Northern closed its Duvernay joint development in early June and completed the Parallax acquisition, described as a self‑funding asset with around 20 years of inventory and breakevens below $50. Its ground game added more than six net wells in the quarter and expanded the drilled‑and‑completed list to about 52 net wells.

Positive Forward Financial Outlook

Management outlined a strip‑based outlook that calls for $1.4–$1.5 billion of adjusted EBITDA for 2026, funded by $850–$900 million of D&C capital. That spending profile is expected to yield roughly $375–$500 million or more of free cash flow, with the dividend fully covered and room for additional returns or growth.

Operational Outperformance Across Basins

Operationally, the Williston and Uinta basins exceeded internal expectations, helping offset weakness elsewhere. Early wells from the Utica joint venture are also performing well as operators push longer laterals and better decline profiles, which is improving productivity and enhancing inventory quality across the portfolio.

Waha Curtailments and Permian Logistics Pressure

Second‑quarter results were dented by significant curtailments tied to weak Waha gas economics, forcing Northern to pull back activity and volumes in the Permian. Prior logistical bottlenecks in the region also weighed on output and have led management to signal a cautious near‑term production cadence until conditions normalize.

Operating and LOE Dynamics

Management noted that its LOE includes gathering, transportation and other items that peers may report differently, complicating cost comparisons. Aging well bases and higher historical workover costs have pressured operating expenses and could keep LOE elevated unless growth in more advantaged basins adds scale and improves unit economics.

Market Valuation Disconnect

A major theme was frustration with what management sees as a wide valuation gap between asset value and the stock’s current pricing. They contrasted an internal asset value estimate north of $7 billion with a roughly $4.6 billion enterprise value, arguing that the market is not fully recognizing the depth and profitability of the company’s inventory.

Exposure to Weather and Commodity Volatility

Northern acknowledged that its outlook remains exposed to weather‑driven demand shifts and commodity price swings, including potential impacts from El Niño. Winter seasonality in gas markets, along with broader price volatility, can affect realized prices and operating decisions, making risk management and hedging strategies crucial.

Leverage and Capital Allocation Perception

Management conceded that its use of leverage to fund inventory and acquisitions has created perception issues for some investors. While they believe they can monetize assets to reduce debt if needed, the current leverage profile remains a concern in parts of the market and shapes views on capital allocation and risk.

Operational Curtailments Still Required

Even as Waha pressures begin to ease, curtailments in the second quarter cut near‑term volumes and will require renewed activity to fully restore production. Management pointed to three net turn‑in‑lines slated to contribute to third‑quarter volumes, but emphasized that rebuilding cadence will take time.

Forward-Looking Guidance and Cash-Flow Focus

Guidance centers on sustaining strong cash‑flow generation, with 2026 adjusted EBITDA guided to about $1.4–$1.5 billion. With planned D&C capital of $850–$900 million, Northern expects to deliver approximately $375–$500 million or more of free cash flow while keeping the dividend well covered and preserving balance sheet strength.

Northern Oil and Gas’ earnings call painted a picture of a company moving from consolidation into cash‑rich execution, backed by record gas volumes, disciplined costs and expanding inventory. While Waha‑related curtailments, leverage optics and valuation discount remain watch points, management’s message was that operations and cash flow are trending in the right direction, supporting continued shareholder returns.