Ring Energy's Third Quarter 2026 Earnings Conference Call - RING ENERGY INC

Explicit Guidance:

• Q4 2026 Oil Sales Volumes: 12,900–13,500 bbl/day (adjusted for divestitures).
• Q4 2026 Total Sales Volumes: 20,400–21,200 BOE/d.
• Q4 2026 Operating Expenses (LOE): $9.80–$10.30/BOE.
• Q4 2026 Capital Spending: $43–$48 million.
• Full Year 2026 Free Cash Flow: Expects return to positive free cash flow as Q4 capital spending steps down, driven by a "deliberate decision" to invest ahead in Q3 using surplus proceeds; full-year adjusted free cash flow remains positive despite Q3 negative results.
• 2027 Oil Sales Volumes: 13,200–14,300 bbl/day.
• 2027 Total Sales Volumes: 21,000–23,000 BOE/d.
• 2027 Capital Spending: $135–$165 million.
• 2027 Well Count: 20–30 new horizontal wells, specifically featuring laterals >1.5 miles.
• 2027 Operating Expenses (LOE): $9.70–$10.50/BOE.
• 2027 Production Growth Expectation: ~10% growth on a "slightly lower" capital spending program compared to previous years.

Business-Segment Outlook:

• Development Model Shift: Transitioning to a "more capital-efficient" model utilizing co-developed 1.5-mile and 2.0-mile horizontal laterals on the Central Basin Platform (CBP) and Northwest Shelf; expects significant inflection in capital efficiency and "production per dollar spent" in 2027.
• Inventory Expansion: Actively leasing acreage in the CBP and Southern Northwest Shelf to expand undeveloped inventory; aims to capitalize on "stacked pays" and deeper, oil-charged zones previously considered uneconomic via vertical drilling.
• Operational Strategy: Adopting pad drilling (2–5 wells per location) with shut-in of offset production during completion to minimize frac interference; expects "lumpy" production profiles in the short term but higher sustained production delivery over multiple quarters.
• Well Performance: New wells in Crane County (5 completed two-mile laterals) and Andrews County (two 1.5-mile laterals) are meeting or exceeding expectations; EUR/ft metrics similar to prior years but with 5 proved horizontal targets vs. 2 previously.

Market and Competitive Outlook:

• Commodity Price Environment: Management anticipates a "higher for longer" oil price environment; views current high prices and the market's interest in deeper plays as catalysts for asset sales and reinvestment.
• Capital Efficiency: Believes the pivot to longer laterals will allow 2027 growth at lower or similar capex levels compared to prior years, significantly improving returns per barrel.
• Competitive Landscape: Notes current competition for acreage has been primarily private entities; believes public competitors are not yet active in the deeper Central Basin Platform zones but anticipates future activity as technology validates economics.
• Gas Pricing: Permian natural gas pricing volatility remains a factor; management actively manages basis exposure given the "meaningful relief" and improved realizations seen in Q3 as takeaway capacity came online.

Macro / Industry Outlook:

• Debt and Leverage Targets: Targeting long-term leverage of <1.25x; confident in achieving leverage <1.0x in 2027 if oil prices remain high (>$80/bbl) or potentially by Q3/Q4 2027 if prices stabilize around $75/bbl.
• Liquidity and Balance Sheet: End-of-quarter debt at $350M (down $70M from YoY); liquidity increased to $236M; remaining fully compliant with covenants.
• Hedging Requirements: Current revolving credit facility requires 50% hedging for months 13–24 until leverage drops below 1.25x and borrowing base drawdown falls below 50%. Goal to reduce hedge requirement to 25% or zero based on leverage improvements.
• Borrowing Base Redetermination: Expected in December; management anticipates positive movement from banks given debt reduction progress.

Strategic Initiatives:

• 2027 Capital Front-Loading: Capital spend in 2027 is weighted toward the first half to maximize production duration; full-year spend expected to be $135–$165M.
• Asset Monetization: Completed $30.5M in non-core asset sales (130 BOE/d, 63% oil) in Q3; proceeds used to reduce debt ($10M) and acquire leasehold interests ($18.8M) to offset the central basin footprint.
• Infrastructure Investment: $64M invested in Q3 to advance long-lateral programs and supporting infrastructure (water handling, frac pads), a prerequisite for the 2027 efficiency pivot.
• Hedge Strategy Enhancement: Strengthened oil hedge position for H1 2027, increasing downside protection on ~59% of H1 2027 oil volumes; additional swaps designed to maintain free cash flow positivity even if WTI falls to $65.

Risks and Headwinds to Outlook:

• Implementation Lag: Benefits of the new development program (longer laterals, pad drilling) may take "a couple of quarters" to fully manifest in financials due to production profile lumps and shut-in periods.
• Commodity Price Sensitivity: Future capital spending decisions (curtailment vs. expansion) and leverage targets are dependent on realized oil prices; a price drop could impact the timeline to reach <1.25x leverage.
• Operational Execution: Risk of frac interference or lower-than-expected well performance on new pads, though management is encouraged by early results.
• Competition: Potential for other public or private entities to recognize the value of deeper zones, potentially increasing acreage acquisition costs.
• Covenant Constraints: Failure to achieve leverage targets by specific price levels could extend the duration of mandatory hedging requirements.

Management Tone on the Future:

• Confidence Level: High confidence in the 2027 outlook; management describes the current position as "catapulting the company 1.5–2 years forward" regarding financial stability and debt reduction.
• Strategic Clarity: Emphasis on "disciplined execution" and "durable per-share value"; leadership expresses excitement about the "momentum" built in 2026 and the transition to a more capital-efficient business model.
• Forward-Looking Adjustments: Clear shift from prior year focus (defensive portfolio management) to aggressive organic growth (2027 volumes up 10%) funded by disciplined capital allocation and a stronger balance sheet.

Miscellaneous:

• Well Count Specifics: Q3 included 8 drilled/7 completed wells (6 in Crane, 2 in Andrews).
• Q3 Financials Context: Adjusted EBITDA margin improved to 56% (up from 52%) despite a 6% decline in realized price; adjusted cash flow from operations up 7% to $50.4M.
• Geology Update: Confirmed "all oil-charged" zones on the Central Basin Platform and Southern Northwest Shelf; 100-year-old basin being re-evaluated as economic via new horizontal/frac technologies.