Skip to content
    PROP
    Earnings call· Jun 2026(Q2 FY26)

    Prairie Operating Q2 FY26 earnings call PROP

    Aug 17, 2026 Source

    Executive summary

    Prairie Operating Co. Q2 FY26 — Capital Structure Simplified, Operational Efficiencies Drive Production Growth

    Prairie Operating Co. delivered a transformative Q2 FY26, marked by significant capital structure simplification through preferred stock refinancing and warrant reduction. The company also demonstrated strong operational execution in its DJ Basin development, achieving efficiencies like a new hole design saving over $40,000 per well and driving August production to 27,000 BOE/day. While full-year guidance was adjusted to preserve liquidity and align with operating performance, the focus remains on disciplined capital allocation and converting high-quality inventory into sustainable cash flow.

    Highlights

    5
    • Production increased approximately 4% year-over-year to 21,866 BOE per day in Q2 FY26.

    • August month-to-date production increased to approximately 27,000 net BOE per day.

    • Successfully drilled first 3-mile lateral and achieved over $40,000 per well savings with a new hole design.

    • Adjusted EBITDA for H1 FY26 increased approximately 65% to $71.1 million.

    • Reduced outstanding preferred balance from $148.5 million to $78 million and anniversary warrant coverage from 1.25:1 to 0.65:1.

    Concerns

    4
    • Full-year 2026 average daily production guidance adjusted to 23,000-25,000 BOE per day.

    • Full-year 2026 capital expenditures guidance adjusted to $185 million-$195 million.

    • Negative natural gas realization of -$1.30 per Mcf in Q2 FY26 due to weaker CIG pricing.

    • Credit facility had $436 million outstanding with only $39 million of availability at quarter end.

    Guidance & targets

    5
    CategoryTargetConfidence
    Full-year 2026 average daily production
    23,000 to 25,000 BOE per day
    high materiality
    High
    Full-year 2026 capital expenditures
    $185 million to $195 million
    high materiality
    High
    Full-year 2026 adjusted EBITDA
    $180 million to $190 million
    high materiality
    High
    Q3 FY26 average daily production
    26,000 to 28,000 BOE per day
    medium materiality
    Medium
    Q4 FY26 average daily production trend
    small decline
    medium materiality
    Medium

    Operational metrics

    41
    Production volume
    2 million BOE
    Q2 FY26

    Total production for the quarter.

    Average daily production
    21,866 BOE per dayincreased approximately 4% compared with the second quarter of 2025
    Q2 FY26

    Includes 72% liquids and 50% oil.

    Liquids percentage of production
    72%
    Q2 FY26

    Company-wide production mix.

    Oil percentage of production
    50%
    Q2 FY26

    Company-wide production mix.

    August month-to-date production
    27,000 net BOE per day
    August 2026

    Reflects contribution from recently completed wells, excluding Burnett and Castor pads.

    Wells drilled
    12 wells
    Q2 FY26

    All wells completed below AFE.

    Average measured depth
    19,100 feet
    Q2 FY26

    Average for wells drilled in Q2 FY26.

    Average rate of penetration
    390 feet per hour
    Q2 FY26

    Average for wells drilled in Q2 FY26.

    Average spud-to-rig release time
    6.65 days
    Q2 FY26

    Average for wells drilled in Q2 FY26.

    Well cost savings (7 7/8-inch hole design)
    $40,000+
    Q2 FY26

    Trials generated realized savings, planned for significant portion of upcoming Niobrara development program.

    Wells drilled
    27 wells
    YTD 2026

    Wells delivered below AFE.

    Average measured depth
    18,700 feet
    YTD 2026

    Average for wells drilled YTD 2026.

    Average rate of penetration
    377 feet per hour
    YTD 2026

    Average for wells drilled YTD 2026.

    Average spud-to-rig release time
    6.2 days
    YTD 2026

    Average for wells drilled YTD 2026.

    Total revenue
    $98.9 millionincrease of approximately 45% compared with the prior year period
    Q2 FY26

    Company-wide revenue.

    Oil revenue
    $93.5 million
    Q2 FY26

    Component of total revenue.

    GAAP net income attributable to common stockholders
    $193.8 million
    Q2 FY26

    After preferred stock dividends and remeasurement adjustments. Includes noncash impacts related to derivatives, income taxes and fair value adjustments.

    Basic EPS
    $1.75
    Q2 FY26

    GAAP basic earnings per share.

    Diluted EPS
    $0.23
    Q2 FY26

    GAAP diluted earnings per share.

    Adjusted EBITDA
    $34 million
    Q2 FY26

    Non-GAAP financial measure.

    Net cash provided by operating activities
    $52 million
    Q2 FY26

    Operating cash flow.

    Cash capital expenditures
    $98.5 million
    Q2 FY26

    Reflecting concentration of development and turn-in-line activity.

    Total revenue
    $182.3 millionincrease of approximately 125% compared with the prior year period
    H1 2026

    Company-wide revenue for the first six months.

    Adjusted EBITDA
    $71.1 millionincrease of approximately 65%
    H1 2026

    Non-GAAP financial measure for the first six months.

    Net cash provided by operating activities
    $94.3 million
    H1 2026

    Operating cash flow for the first six months.

    Cash capital expenditures
    $132.6 million
    H1 2026

    Capital spending for the first six months.

    Total production
    4.1 million BOE
    H1 2026

    Total production for the first six months.

    Average daily production
    22,500 BOE per day
    H1 2026

    Average daily production for the first six months.

    Borrowing base credit facility
    $475 million
    as of June 30

    Total borrowing base and aggregate elected commitments.

    Outstanding under credit facility
    $436 million
    as of June 30

    Amount drawn on the credit facility.

    Availability under credit facility
    $39 million
    as of June 30

    Remaining available liquidity on the credit facility.

    Oil swaps coverage
    2.7 million barrels
    H2 2026

    Part of the commodity hedge portfolio.

    Natural gas swaps coverage
    7.6 million MMBtu
    H2 2026

    Part of the commodity hedge portfolio.

    Preferred stock principal outstanding (original)
    $148.5 million
    18 months ago

    Original principal units outstanding associated with the Series F Preferred stock.

    Preferred stock principal outstanding (year-end)
    $121 million
    year-end (prior period)

    Outstanding balance of preferred stock at prior year-end.

    Preferred stock principal outstanding (current)
    $78 million
    end of last quarter

    Outstanding balance of preferred stock as of Q2 FY26.

    Anniversary warrant coverage (original)
    1.25:1
    original inception

    Original coverage ratio for the anniversary warrant.

    Anniversary warrant coverage (current)
    0.65:1
    today

    Current coverage ratio for the anniversary warrant, reduced from original.

    Well cost for stand-alone 2-mile laterals
    $5.2 million to $5.5 million
    current

    Cost for 2-mile laterals on a stand-alone pad.

    Well cost for step-out 2-mile laterals
    $5.4 million to $5.6 million
    current

    Cost for 2-mile laterals utilizing a pad with permits to develop an offset DSU.

    Extra pipe cost for step-out laterals
    $100,000 to $200,000
    current

    Additional cost for pipe to get to an offsetting DSU for step-out laterals.

    Industry KPIs

    5
    MetricValueDetails
    D c efficiency rig activity12 wells drilled (Q2), 27 wells drilled (YTD)wells
    Realized price differential$94.21 per barrel (oil), $21.64 per barrel (NGLs), negative $1.30 per Mcf (natural gas)USD
    Basin level production volume21,866 BOE per dayBOE per day
    Cost of supply unit cash cost$6.85 (LOE), $1.22 (T&P), $4.01 (Ad valorem & production taxes), $6.01 (G&A)USD per BOE
    FCF shareholder distributions

    Risks & headwinds

    4
    Weaker CIG pricing for natural gasQ2 FY26

    Negative natural gas realization of -$1.30 per Mcf in Q2 FY26

    Mitigation: Commodity hedge portfolio provides meaningful downside protection and improved visibility into future cash flows.

    Colorado Parks and Wildlife seasonal restrictionsQ2 FY26

    Planned pause between Opal Coalbank and Burnett pads, impacting timing of new well activity

    Mitigation: Incorporating additional planning around seasonal operating restrictions to improve execution certainty.

    Liquidity constraints on credit facilityNear-term

    $39 million availability on $475 million credit facility as of June 30

    Mitigation: Adjusting full-year guidance to preserve and increase liquidity; working with banks on credit facility modifications, including a minimum production threshold.

    Potential warrant-related dilution from Series F Preferred stockOngoing

    Anniversary warrant coverage was 1.25:1 at inception

    Mitigation: Reduced outstanding preferred balance from $148.5 million to $78 million and anniversary warrant coverage to 0.65:1; actively pursuing refinancing solutions.

    What to watch in Q3 FY26

    4

    Burnett pad initial production rates

    Next quarter (Q3 FY26 results)
    CurrentIn flowback, not yet cutting hydrocarbons
    TargetInitial production rates and contribution to overall volume

    Why it matters

    Key indicator of success for a new pad in a derisked area, impacting Q3/Q4 production.

    Burnett is in the flowback stages right now. It is interconnected to all the necessary infrastructure, but we have not cut hydrocarbons as of this morning. I would expect any moment, we will start seeing cutting hydrocarbons.

    Q&A highlights

    6

    Is the Burnett pad online, what are its initial rates, and how will production trend for Q3/Q4?

    The Burnett pad is in flowback and not yet cutting hydrocarbons, so its production is not included in the 27,000 BOE/day August figure. The Castor pad is also in completion. Production is expected to be around 26,000-28,000 BOE/day for Q3, with a small decline exiting the year.

    Burnett is in the flowback stages right now. It is interconnected to all the necessary infrastructure, but we have not cut hydrocarbons as of this morning. I would expect any moment, we will start seeing cutting hydrocarbons. So we'll be able to talk a little bit more about that. So those wells are not factored into that approximate 27,000 net barrels a day factor.

    asked by Leo Mariani · answered by Gregory Patton

    2 min read5 chapters

    Detailed Narrative

    01

    Capital Structure Simplification

    Prairie completed a meaningful partial refinancing of its Series F Preferred stock, reducing the outstanding preferred balance from an original $148.5 million to $78 million as of the end of Q2 FY26. The company also decreased the anniversary warrant coverage from its original inception of 1.25:1 to 0.65:1. These actions, along with extending the anniversary warrant date to August 31, 2026, aim to increase liquidity, improve financial flexibility, and align management and the Board around disciplined execution. Management is actively pursuing multiple avenues to address the remaining balance and refinance the preferred stock.

    02

    Operational Efficiencies and Drilling Performance

    The company continued to demonstrate steady progress in drilling performance, completing 12 wells in Q2 FY26 (2 Codell, 10 Niobrara), with 8 drilled in a single run and all completed below AFE. Prairie successfully drilled its first 3-mile lateral and achieved significant cost savings of over $40,000 per well by implementing a smaller 7 7/8-inch hole design in trials on the Castor pad. This efficiency is planned for a significant portion of the upcoming Niobrara development program, lowering well costs without compromising performance. Year-to-date, 27 wells have been drilled, averaging 18,700 feet in measured depth and 6.2 days spud-to-rig release.

    03

    DJ Basin Development and Production Momentum

    Prairie completed drilling operations at the Elder, Opal Coalbank, Burnett, and Castor pads during 2026. The Opal Coalbank wells began producing near the end of June, contributing to a significant increase in average month-to-date production for August to approximately 27,000 net BOE per day. The Burnett pad is currently in flowback stages, and the Castor pad is in completion stages, with their contributions expected to further impact production. This performance reinforces the quality of the DJ Basin asset base and provides encouraging momentum for the second half of the year.

    04

    Management and Board Refresh

    During the quarter, Prairie Operating Co. transitioned its management team and refreshed its Board of Directors. New directors were welcomed, bringing enhanced experience and perspectives to strengthen oversight and strategic decision-making. These changes are part of a broader effort to position the company for its next phase of growth and ensure disciplined execution and long-term shareholder value creation.

    05

    Credit Facility Management

    The company has been actively working with its banks to modify the reserve-based credit facility, including the introduction of a minimum production threshold. This modification is designed to balance continued development with liquidity availability, ensuring the company can progress its development plan without excessive growth or a complete shutdown. As of June 30, the facility had $436 million outstanding against a $475 million borrowing base, leaving $39 million of availability.

    AI-generated summary of the company’s earnings call. Not investment advice.