• Free Cash Flow: $136 million in Q1, with $94 million after dividends.
• Adjusted EBITDA: Approximately $435 million, a record for NOG.
• Total Average Daily Production: Approximately 135,000 BOE per day, up 2.5% from Q4.
• Oil Production: Approximately 79,000 barrels per day, flat versus Q4.
• Gas Production: Contributed 42% to production mix, up 6.5% sequentially and 14% year over year.
• Cash Operating Costs: Down nearly $2 per BOE from one year ago and $1 per BOE from last quarter.
• CapEx: Nearly $250 million in Q1, with 57% allocated to the Permian.
• Liquidity: Over $900 million, including $34 million of cash on hand and $870 million of availability on a revolving credit facility.
• Net Debt: Reduced by approximately $90 million in the quarter, with net debt to LQA EBITDA ratio around 1.3 times.

• Warning! GuruFocus has detected 4 Warning Signs with NOG.

Release Date: April 30, 2025

For the complete transcript of the earnings call, please refer to the full earnings call transcript.

Positive Points

• Northern Oil & Gas Inc (NYSE:NOG) operates with a highly adaptable model, allowing for flexibility in capital allocation based on market dynamics.
• The company generated $136 million in free cash flow in Q1 2025, showcasing strong financial performance.
• Over 60% of expected production is hedged for 2025, providing resilience against commodity price fluctuations.
• NOG's Q1 production increased by 13% year-over-year, with significant contributions from the Uinta and Appalachian basins.
• The company has maintained 21 consecutive quarters of positive free cash flow, totaling over $1.7 billion since 2020.

Negative Points

• Market volatility and changing commodity prices present challenges for future planning and capital allocation.
• Oil differentials came in above the high end of the guided range, reflecting disruptions and seasonal widening.
• There is uncertainty regarding potential changes in activity levels and capital spending due to fluctuating commodity prices.
• Service pricing, particularly in drilling, remains relatively sticky, limiting cost relief opportunities.
• The company faces challenges in larger M&A activities due to widened bid-ask spreads in a volatile market.

Q & A Highlights

Q: Can you provide more color on the production cadence for the rest of the year given the macro uncertainty? A: Chad Allen, CFO: We expect production cadence to be flat for the first three quarters, with Q2 and early Q3 marking the lowest activity levels. CapEx will be sequentially down in Q2, and we anticipate Q4 to have the highest production levels, barring any significant pullbacks in spending. The situation remains fluid due to volatile commodity pricing.

Q: How does current service pricing compare to the start of the year? A: Adam Dirlam, President: We've seen about a 10% decrease in normalized AFE costs, driven by a 20-25% increase in lateral lengths. Drilling rates have been sticky, but we see some relief in completions. We are keeping estimates and guidance flat as per the beginning of the year.

Q: Has the recent volatility in oil and gas outlook led to more potential sellers of non-operator interests? A: Adam Dirlam, President: Yes, we've screened 100 transactions in Q1 and another 100 in April. Operators and non-operators are looking to pare back CapEx, leading to more opportunities. We are being selective and running downside scenarios to ensure full-cycle returns.

Q: In a scenario where CapEx is at the low end of the range, what would maintenance CapEx be for 2026 and 2027? A: Nicholas O'Grady, CEO: Maintenance CapEx would be about $850 million, assuming current drilling costs remain unchanged.

Q: Are production taxes and gas prices expected to trend back into the range for the year? A: Chad Allen, CFO: Yes, production taxes are expected to move back into the guided range as our Permian production, which has higher taxes, grows.

For the complete transcript of the earnings call, please refer to the full earnings call transcript.