8-K: Prairie Operating Co. Reports Record Q3 Production, Reaffirms 2025 Guidance

Prairie Operating Co. announced record third-quarter production and a significant increase in Adjusted EBITDA, driven by successful operational execution and strategic acquisitions in the DJ Basin.

Summary

• Record total production of 23,029 barrels of oil equivalent per day (Boe/d) in Q3 2025, an increase of approximately 10% quarter-over-quarter, with oil comprising about 52% of production.
• Current production rate as of November 14, 2025, is approximately 27,000 net Boe/d, reflecting successful development program execution.
• Third-quarter revenue reached $77.7 million, with realized prices (excluding hedges) of $58.70 per barrel for oil, $12.27 per barrel for NGLs, and $2.15 per Mcf for natural gas.
• Adjusted EBITDA for Q3 2025 was $56.3 million, marking an increase of over 45% quarter-over-quarter.
• Net loss attributable to common stockholders was $22.5 million, or $0.44 basic loss per share for Q3 2025.
• Capital expenditures incurred during the quarter totaled $69.6 million, with net cash provided by operating activities at $57.7 million.
• The company completed the transition services period following the Bayswater acquisition and closed two complementary bolt-on acquisitions, adding approximately 11 net drilling locations and 3,400 net acres.
• Prairie re-affirmed its full-year 2025 guidance, expecting average daily production of 24,000 – 26,000 Boe/d, capital expenditures between $260.0 million – $280.0 million, and Adjusted EBITDA between $240.0 million – $260.0 million.

Sentiment

Score: 7

Explanation: The company reported record production and strong Adjusted EBITDA growth, indicating operational success and effective integration of acquisitions. Reaffirming full-year guidance suggests confidence. However, a net loss attributable to common stockholders and a significant increase in debt temper the overall positive sentiment. The expanded hedging program provides stability.

Positives

• Record total production of 23,029 Boe/d in Q3 2025, a 10% increase quarter-over-quarter.
• Current production rate of approximately 27,000 net Boe/d as of November 14, 2025, demonstrating successful development.
• Adjusted EBITDA increased by over 45% quarter-over-quarter to $56.3 million.
• Successful completion of the Bayswater acquisition transition, assuming full operational control.
• Closed two complementary bolt-on acquisitions, adding 11 net drilling locations and 3,400 net acres.
• Expanded hedging program through 2028, securing favorable commodity pricing.
• Initial results from 9 Opal Coalbank pad wells (acquired as DUCs) exceeded expectations, averaging 525 Boe/d per well (IP30).
• Robust workover program with 31 of 32 wells completed to date, including 18 in Q3.
• Installation of plungers across 183 wells resulted in an average oil production increase of 12.6% per well.
• Net cash provided by operating activities was $57.7 million in Q3 2025.

Negatives

• Reported a net loss attributable to common stockholders of $22.5 million, or $0.44 basic loss per share for Q3 2025.
• Average realized price (excluding effects of derivatives) for natural gas was low at $2.15 per Mcf.
• Average realized price (excluding effects of derivatives) for NGL was low at $12.27 per barrel.
• Significant increase in total liabilities from $103.786 million at December 31, 2024, to $679.264 million at September 30, 2025, primarily due to the Credit Facility and Bayswater acquisition.
• Nine months ended September 30, 2025, shows a net loss attributable to common stockholders of $67.478 million.

Risks

• Future financial performance, business strategies, expansion plans, future results of operations, estimated revenues, losses, projected costs, prospects, plans, and objectives of management are subject to risks and uncertainties.
• Actual results or performance may be materially different from forward-looking statements due to various risks, uncertainties (some beyond control), or other assumptions.
• The list of risks is not exhaustive, and new risk factors may emerge, which management cannot predict.
• The company operates in a very competitive and rapidly changing environment.

Future Outlook

Prairie Operating Co. re-affirmed its full-year 2025 guidance, projecting average daily production between 24,000 and 26,000 Boe/d. Capital expenditures are expected to range from $260.0 million to $280.0 million, and Adjusted EBITDA is anticipated to be between $240.0 million and $260.0 million. This guidance incorporates production, revenue, and expenses from the Bayswater assets starting January 1, 2025, and is based on an active hedging program with oil prices between $60.00-$64.00 per barrel and gas prices at $4.00 per Mcf. The company expects new wells from the Rusch pad to meaningfully contribute to production growth through the remainder of 2025, and the Simpson pad is expected to be fully online in the fourth quarter.

Management Comments

• "The third quarter represented another major step forward for Prairie as we continue to execute across all areas of our business."
• "With the Bayswater transition now complete, Prairie has assumed full operational control and is running at full capacity across our expanded DJ Basin footprint."
• "Our strategy remains clear and disciplined. We're focused on building long-term shareholder value through a combination of high-return organic development, continued operational optimization, and selective, accretive acquisitions."
• "The progress we've made this year has set the stage for continued momentum into 2026 and beyond."

Industry Context

Prairie Operating Co.'s focus on the Denver-Julesburg (DJ) Basin, particularly the Niobrara and Codell formations, aligns with a broader industry trend of optimizing production from established, liquids-rich basins in the U.S. The successful integration of the Bayswater assets and complementary bolt-on acquisitions indicate a strategy of consolidation and organic growth within a key domestic shale play. The expanded hedging program through 2028 suggests a proactive approach to managing commodity price volatility, a common practice among independent energy producers to stabilize cash flows and support development programs in a fluctuating market environment. The emphasis on operational optimization, such as workover programs and plunger installations, reflects an industry-wide drive for capital efficiency and maximizing per-well productivity in mature fields.

Comparison to Industry Standards

• The filing does not provide specific comparisons to industry benchmarks or competitor results.

Related Party Transactions

• Subordinated note related party: $1,458k as of Sep 30, 2025.
• Subordinated note warrants, at fair value related party: $300k as of Sep 30, 2025.
• Payments of the Subordinated Note related party: $(3,214)k during the nine months ended Sep 30, 2025.
• Proceeds from the issuance of the Subordinated Promissory Note related party: $3,000k during the nine months ended Sep 30, 2024.

Stakeholder Impact

• Shareholders: Potential for long-term value creation through organic growth and accretive acquisitions, supported by record production and increased Adjusted EBITDA. However, the reported net loss and increased debt levels could be a concern. Hedging program aims to stabilize returns.
• Employees: Full operational control post-Bayswater acquisition and running at full capacity suggests stable or growing employment opportunities within the expanded DJ Basin footprint.
• Customers: Increased production capacity from new wells and optimized existing assets ensures a consistent supply of oil, natural gas, and NGLs.
• Creditors: Increased debt from the Credit Facility ($417.0 million) indicates higher leverage, but $68.6 million in liquidity and strong operating cash flow ($57.7 million in Q3) provide some comfort regarding debt servicing capacity.
• Suppliers: Ongoing development programs (Noble, Simpson, Rusch pads) and workover initiatives suggest continued demand for services and equipment.

Next Steps

• Finalize completion activities on six newly drilled wells at the Simpson pad, with the pad expected to be fully online in the fourth quarter of 2025.
• Continue to see meaningful production contribution from the 11 wells on the Rusch pad through the remainder of 2025.
• Complete the robust workover program targeting 32 wells across the third and fourth quarters.
• Continue to build long-term shareholder value through high-return organic development, continued operational optimization, and selective, accretive acquisitions.
• Maintain momentum into 2026 and beyond.

Key Dates

Recommendation

While Prairie Operating Co. demonstrates strong operational performance with record production and significant Adjusted EBITDA growth, the reported net loss attributable to common stockholders and the substantial increase in debt warrant a cautious approach. The reaffirmation of guidance suggests stability, and the hedging strategy mitigates commodity price risk. However, the company is still in a growth phase, heavily investing in acquisitions and development, which carries inherent risks. A "hold" recommendation allows investors to observe the company's ability to translate operational gains into sustained profitability and deleveraging, especially as the acquired assets are fully integrated and new wells come online. The long-term strategy appears sound, but the current financial structure requires careful monitoring.

Keywords

Oil and Gas, Energy Company, DJ Basin, Niobrara Formation, Codell Formation, Production, Adjusted EBITDA, SEC Filing, Q3 2025 Results, Prairie Operating Co., PROP, Exploration and Production, Hedging, Acquisitions, Capital Expenditures