8-K: Prairie Operating Co. Soars with 400% Revenue Growth

Prairie Operating Co. announced record second-quarter 2025 financial and operational results, driven by significant production growth and strategic acquisitions in the DJ Basin.

Summary

• Total revenue reached $68.1 million, marking an approximate 400% increase quarter-over-quarter.
• Record total production hit 21,052 barrels of oil equivalent per day (Boe/d), with approximately 50% oil, representing an approximate 540% increase quarter-over-quarter.
• Net income attributable to common stockholders was $48.5 million, or $1.04 basic earnings per share.
• Adjusted EBITDA surged to $38.6 million, an increase of over 600% quarter-over-quarter.
• The company acquired over $600.0 million of producing oil and gas assets.
• A hedging program was initiated, securing favorable commodity pricing through 2028.
• The Credit Facility Agreement with Citibank was amended, adding two additional banks to the syndicate and reaffirming the borrowing base at $475.0 million.
• Capital expenditures incurred during the quarter totaled $56.6 million.
• Net cash provided by operating activities was $9.7 million.
• The team size increased from 20 to 59 employees, and the portfolio of operated wells grew from 34 to over 360.
• 18 wells were drilled and 9 wells were completed during the quarter, with 17 wells turned to sales in the first half of 2025.
• Average spud-to-total-depth times improved to 5.3 days, and well costs remained within 5% of AFE, with the most recent pad averaging approximately $5.6 million per well.
• The 11-well Rusch pad was successfully executed on time and within budget, with first production expected early in the third quarter.
• The company implemented U-shaped lateral designs and deployed an electric frac fleet, significantly reducing emissions and completion costs.
• Plunger lift systems were installed on 30 wells, and three high-return workovers were brought back online in June and July.

Sentiment

Score: 9

Explanation: The filing reports exceptionally strong financial and operational growth across all key metrics, including revenue, production, and EBITDA, driven by successful strategic acquisitions and operational efficiencies. The company has significantly expanded its asset base, improved liquidity, and implemented a robust hedging program, positioning it for continued growth and cash flow generation. While there's a six-month net loss, the Q2 performance is overwhelmingly positive and indicative of a strong turnaround and growth trajectory.

Positives

• Significant revenue growth of approximately 400% quarter-over-quarter to $68.1 million.
• Record total production increase of approximately 540% quarter-over-quarter to 21,052 barrels of oil equivalent per day (Boe/d).
• Strong net income attributable to common stockholders of $48.5 million, or $1.04 basic earnings per share.
• Adjusted EBITDA surged over 600% quarter-over-quarter to $38.6 million.
• Successful acquisition of over $600.0 million of producing oil and gas assets, expanding inventory depth and improving capital efficiency.
• Implementation of a hedging program securing favorable commodity pricing through 2028.
• Credit Facility Agreement amended, adding two banks and reaffirming the borrowing base at $475.0 million, enhancing liquidity.
• Successful integration of Bayswater assets and significant increase in team size from 20 to 59 employees.
• Increased operated well portfolio from 34 to over 360.
• Improved average spud-to-total-depth times to 5.3 days.
• Successful execution of the 11-well Rusch pad, drilled on time and within budget.
• Advancement in technical leadership with U-shaped lateral designs for extended lateral lengths and maximized drainage.
• Deployment of an electric frac fleet, significantly reducing emissions and completion costs.
• Efficient zipper frac operations, averaging 14 stages per day and peaking at 18 stages per day.
• Early pressure data from Opal-Coalbank pad suggests strong reservoir communication, with all nine wells flowing oil within the first week.
• Installation of plunger lift systems on 30 wells for production optimization.
• Successful return to online status of three high-return workovers in June and July.
• Strong liquidity of $98.7 million as of June 30, 2025, including $88.0 million available under the Credit Facility.
• Leverage of approximately 1x, indicating a strong financial position.

Negatives

• Capital expenditures incurred of $56.6 million, which represents a significant cash outflow, although it is part of the company's growth strategy.
• General and administrative expenses increased to $16.443 million for the quarter ended June 30, 2025, compared to $8.512 million for the same period in 2024.
• Net income attributable to common stockholders for the six months ended June 30, 2025, was a loss of $(44.971) million, compared to a loss of $(17.551) million for the same period in 2024, indicating significant losses or adjustments in the first quarter.
• Diluted earnings per share for Q2 2025 was $0.18, significantly lower than basic earnings per share of $1.04, indicating substantial dilution from convertible instruments.

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 of which are beyond the company's control), or other assumptions.
• The company operates in a very competitive and rapidly changing environment, which can introduce new and unpredictable risk factors.
• Management cannot predict all risk factors or assess the effects of all factors on the business, nor the extent to which any factor or combination of factors may cause actual results to differ materially from forward-looking statements.
• Should one or more risks or uncertainties materialize, or should any of the company's assumptions prove incorrect, actual results may vary in material respects from those projected in forward-looking statements.

Future Outlook

Prairie Operating Co. expects full-year 2025 average daily production to range between 24,000 and 26,000 BOEPD, with capital expenditures projected between $260.0 million and $280.0 million. Adjusted EBITDA is anticipated to be between $240.0 million and $260.0 million. This guidance is based on an active hedging program covering 85% of current daily production, an average working interest of 75% or greater, and commodity price assumptions of $60.00 $64.00 per Bbl for oil and $4.00 per Mcf for gas. The company also anticipates lower cost realizations in the third quarter and beyond due to integration efforts and reduced outsourced consultant expenses, as it continues to ramp production through development of its drilling inventory.

Management Comments

• "The second quarter highlighted our tremendous growth rate. We delivered record production, achieved new highs in adjusted EBITDA, and closed our third strategic acquisition in under a year – further solidifying our position as an oil-weighted consolidator in the DJ Basin." Edward Kovalik, Chairman and Chief Executive Officer.
• "Through disciplined capital allocation, operational control, and technical execution, we’ve built a platform that is well-positioned to generate sustainable returns." Edward Kovalik, Chairman and Chief Executive Officer.
• "Our recent acquisitions – all sourced off-market and executed at compelling valuations – have expanded our inventory depth, improved capital efficiency, and created a clear path for continued growth." Edward Kovalik, Chairman and Chief Executive Officer.
• "We also completed the integration of the Bayswater assets acquired earlier this year, increased the size of our team from 20 to 59 employees, increased our portfolio of operated wells from 34 to over 360, and implemented robust internal systems for accounting, land administration, and production optimization." Edward Kovalik, Chairman and Chief Executive Officer.
• "As a result, we’ve laid the groundwork for lower cost realizations in the third quarter and beyond, as we continue to ramp production through development of our drilling inventory, and save costs previously associated with outsourced consultant expenses." Edward Kovalik, Chairman and Chief Executive Officer.
• "Our second quarter results highlight the steps we’ve taken to strengthen Prairie’s financial and operating foundation." Gregory Patton, Executive Vice President and Chief Financial Officer.
• "Our ability to stand up a rig, kick off a continuous frac program, transition the operations of acquired assets, and implement all new accounting and productions systems, is a true testament to our team’s abilities." Gregory Patton, Executive Vice President and Chief Financial Officer.
• "To date, we have grown EBITDA more than six-fold, expanded our credit facility, and closed over $600.0 million in accretive acquisitions." Gregory Patton, Executive Vice President and Chief Financial Officer.
• "We also broadened analyst coverage, further enhancing our visibility in the market." Gregory Patton, Executive Vice President and Chief Financial Officer.
• "With leverage of approximately 1x, enhanced liquidity, and attractive pricing locked in through 2028, Prairie is well positioned to generate cash flow and pursue strategic growth opportunities." Gregory Patton, Executive Vice President and Chief Financial Officer.
• "We are looking forward to optimizing our cost structures, which we believe will translate directly into stronger margins, higher returns, and additional free cash flow." Gregory Patton, Executive Vice President and Chief Financial Officer.

Industry Context

The company operates in the Denver-Julesburg (DJ) Basin, a key oil and liquids-rich region in the United States, focusing on Niobrara and Codell formations. Its strategy of being an "oil-weighted consolidator" through off-market acquisitions at compelling valuations suggests a focus on inorganic growth and market share expansion within this specific basin. The deployment of an electric frac fleet aligns with broader industry trends towards reducing emissions and improving operational efficiency, while innovative well designs like U-shaped laterals indicate a push for maximizing resource recovery in constrained areas, a common challenge in mature basins. The hedging program reflects a proactive approach to managing commodity price volatility, a critical factor in the energy sector.

Comparison to Industry Standards

• Average spud-to-total-depth times improved to 5.3 days, driven by field execution and optimized rig operations, indicating strong operational efficiency.
• Well costs remained within 5% of AFE, with the most recent pad averaging approximately $5.6 million per well, demonstrating cost control. The company aims to drive 2-mile well AFE down towards $5.0 million per well, indicating a focus on cost competitiveness.
• The successful execution of the 11-well Rusch pad, drilled on time and within budget, highlights effective project management.
• The use of Schlumberger's Neosteer rotary steerable system achieving average rates of penetration exceeding 450 feet per hour on the Rusch pad showcases adoption of advanced drilling technology.
• The implementation of U-shaped lateral designs positions the company as a technical leader in the DJ Basin, enabling extended lateral lengths and maximizing drainage, which is an advanced technique for resource recovery.
• The electric frac fleet deployment significantly reduced emissions and completion costs, aligning with industry best practices for environmental stewardship and operational efficiency.
• The zipper frac on the Opal-Coalbank pad achieved excellent efficiency, averaging 14 stages per day and peaking at 18 stages per day, while sustaining 22 hours of daily pumping time, indicating high operational intensity and efficiency compared to conventional methods.
• Leverage of approximately 1x is a healthy financial position, especially for a company undergoing significant acquisition-driven growth, suggesting prudent financial management compared to highly leveraged peers.

Corporate Governance

Related Party Transactions

• Subordinated note related party balance of $1,458 thousand as of June 30, 2025 (down from $4,609 thousand as of Dec 31, 2024).
• Subordinated note warrants, at fair value related party balance of $538 thousand as of June 30, 2025 (down from $4,159 thousand as of Dec 31, 2024).
• Payments of the Subordinated Note related party totaling $(3,214) thousand for the six months ended June 30, 2025.
• YA II PN, LTD., a Cayman Islands exempt limited company, converted the remaining $11.3 million of the initial $15.0 million convertible promissory note in exchange for 2.1 million shares of Common Stock during the six months ended June 30, 2025.

Stakeholder Impact

• Shareholders: Significant positive impact due to strong financial performance (revenue, production, net income, EBITDA growth), strategic acquisitions, and enhanced liquidity. Potential for dilution from convertible instruments (reflected in diluted EPS).
• Employees: Positive impact due to significant increase in team size from 20 to 59 employees, indicating job creation and growth opportunities.
• Customers: Indirect positive impact through increased production and potentially more stable supply from a growing and efficient energy producer.
• Suppliers: Increased business opportunities due to higher capital expenditures ($56.6 million in Q2) and ongoing drilling/completion activities (18 drilled, 9 completed wells).
• Creditors: Positive impact due to strengthened financial foundation, expanded credit facility, and low leverage (approx. 1x), indicating improved creditworthiness.

Next Steps

• Continue to ramp production through development of drilling inventory.
• Optimize cost structures to translate into stronger margins, higher returns, and additional free cash flow.
• Evaluate another 25 to 30 wells for Q3 plunger lift system implementation.
• Meet or exceed full-year turn-in-line (TIL) target.
• Drive 2-mile well AFE down towards $5.0 million per well.
• First production expected early in the third quarter from the 11-well Rusch pad.

Key Dates

Recommendation

The company demonstrated exceptional growth in Q2 2025, with revenue up 400% and production up 540% quarter-over-quarter, alongside a 600% increase in Adjusted EBITDA. Strategic acquisitions totaling over $600 million have significantly expanded its asset base and operational footprint in the DJ Basin. The strengthened balance sheet, evidenced by a reaffirmed $475 million credit facility and low leverage of approximately 1x, provides ample liquidity for continued growth. The proactive hedging program through 2028 locks in favorable commodity prices, mitigating future price volatility risks. Operational efficiencies, including improved drilling times and the deployment of an electric frac fleet, suggest sustainable cost reductions and margin expansion. While the six-month net income is negative due to prior period factors and dilution from convertible instruments is present, the underlying operational and financial trajectory is overwhelmingly positive, indicating strong future cash flow generation and returns. This filing signals a company rapidly scaling and executing its strategy effectively, making it a compelling investment opportunity.

Keywords

Oil and Gas, Energy, DJ Basin, Exploration and Production, E&P, Niobrara, Codell, Crude Oil, Natural Gas, NGL, Production, Revenue, EBITDA, Hedging, Acquisitions, Capital Expenditures, Financial Results, SEC Filing, Form 8-K, Prairie Operating Co., PROP