The Antero acquisition drove Q2 production up 75% and adjusted EBITDAX up 131% year over year. The $19.12 base value implies about 33% upside from the verified $14.34 October 23 close, after deducting $550M debt, a $350M preferred priority and the tax-receivable liability from a peer-derived enterprise value. Large development spending, energy prices and complex ownership limit conviction. The $9.67 bear case implies roughly 33% downside.
The ten components sum to 71/100. The risk/reward score reflects a +33% modeled base gap against a roughly 33% bear loss; $475M FY26 EBITDAX is an analyst assumption, not management guidance.
GPOR/CNX/RRC observed TTM EV/EBITDA = 3.83x/4.25x/7.17x; median 4.25x. A +3.5% adjustment (4.25x × 1.035 = 4.40x, rounded) reflects Q2 production growth of 75%, capped because the increase is acquisition-led and capital intensive; target 4.40x. This is an analyst judgment rather than a direct forward multiple, since peer multiples are trailing while forecast EBITDAX is forward. Applied to an illustrative FY26 EBITDAX $475M: H1 reported $211.939M plus modeled H2 $263.348M, rounded to a $475M FY2026E base. The bridge uses the midpoint of company production guidance (360 MMcfe/d × 365 days = 131,400 MMcfe), subtracts H1 actual production (58,652 MMcfe), and applies the reported Q2 adjusted EBITDAX margin of $3.62/Mcfe to the implied H2 volume (72,748 MMcfe): 72,748 × $3.62 ÷ 1,000 = $263.348M. This implies about 395 MMcfe/d in H2, above the Q2 run rate of 348.5, and assumes no deterioration in realized unit economics. It is an analyst scenario, not company EBITDAX guidance; the margin can change with commodity prices, mix, costs and hedging. The implied nominal multiple remains 4.40x; the entire bridge sums to $19.12, with no generic risk haircut. Independent asset check: SEC pro-forma December 2025 proved-reserve PV-10 $1.603B plus $240M proxy for the 60%-owned acquired midstream purchase cost = $1.843B EV. After the same claims, that yields about $15.23/sh, 20% below base; PV-10 uses old commodity prices, omits unproved acreage and is not an October appraisal. Sensitivity: ±1.0x on $475M moves FV by ±$7.49 (39% of base), so multiple selection is a major limitation. Probability-weighted scenario value ≈ $17.29. Bull conversion is modeled separately to prevent double-counting preferred. ⚠️ Not investment advice. Valuation change versus the September 17 coverage: The September 17 coverage used a $525M FY2026 adjusted EBITDAX estimate and published a $22.64 per-share fair value. The revised base uses $475M, applying Q2 unit economics to the midpoint of company production guidance. At that production level, the earlier $525M estimate would require about $313M H2 EBITDAX, or $4.30/Mcfe, roughly 19% above the reported Q2 margin of $3.62/Mcfe. The lower EBITDAX assumption accounts for most of the change in modeled per-share value. These are analyst scenarios, not company EBITDAX guidance; no Q3 operating results have been released. Revisit the estimate when Q3 results and updated realized margins become available.
| Component | Assumption | USD/share |
|---|---|---|
| Core E&P enterprise value | $475M FY2026E adjusted EBITDAX × 4.40x, divided by 63.422M as-exchanged common economic units. Analyst estimate, not company guidance. | +32.954 |
| Senior notes, face amount | -$550M 7.625% senior notes due 2031 / 63.422M units; no revolver draw at June 30. | -8.672 |
| Cash at June 30 | +$25.883M reported cash / 63.422M units; June balance, not an October estimate. | +0.408 |
| Series A senior preference | -$350M initial liquidation preference / 63.422M units; base assumes no conversion below the $21.39 conversion price. The $343.6M accounting carrying value is not its contractual priority. | -5.519 |
| Tax receivable obligation | -$3.592M June 30 recorded TRA liability / 63.422M units; future payments may change. | -0.057 |
| FV base case | ($2,090M − $550M + $25.883M − $350M − $3.592M) / 63.422M units | = $19.12 |
Insider check: former CFO David Sproule sold 275,000 shares at $17.43 for $4.793M on March 18, 2026, after exchanging units on March 13. The SEC-reported $17.43 is below published March 18 daily lows ($17.51 in Quiver; $17.75 in ChartExchange), and the Form 4 does not identify the execution venue. SEC code S permits either an open-market or private sale. He resigned as CFO in August when Cary Baetz was appointed. In September Baetz bought ~$300K and director Scott Gieselman bought ~$364K. Review these as distinct transactions.
| Item | FY2024 | FY2025 | H1 2026 | FY2026E / guidance |
|---|---|---|---|---|
| Revenue ($M) | 259.0 | 356.4 | 325.9 | No company revenue guidance |
| Adjusted EBITDAX ($M) | 195.7 | 261.0 | 212.0 | 475 analyst estimate; no EBITDAX guidance |
| Production (MMcfe/d) | N/D | 211.8 | 324.0 | 345–375 company guidance |
| Development capex ($M) | N/D | N/D | 240.6 | 450–500 company guidance |
| Total incurred capex ($M) | N/D | N/D | 259.9 | No all-in guidance |
| Net debt, period end ($M) | N/D | 148.0 | 524.1 | Year-end target ≤1.0x leverage |
FY2024–25 historical adjusted EBITDAX and FY2026 H1 data are company-reported; FY2026E $475M is this report's assumption, derived from the production-guidance midpoint and Q2 reported adjusted EBITDAX margin. Revenue guidance is not published. Development capex differs from total incurred capex; figures are labeled accordingly. The Q3 hedge disclosure is preliminary and is not inserted as a full Q3 income statement.
| Metric | Q2 2025 | Q3 2025 | Q4 2025 | Q1 2026 | Q2 2026 |
|---|---|---|---|---|---|
| Revenue ($M) | 74.5 | 79.7 | 117.1 | 154.9 | 171.0 |
| Adjusted EBITDAX ($M) | 49.7 | 60.0 | 94.0 | 97.3 | 114.7 |
| End cash ($M) | 6.3 | 4.6 | 2.85 | 72.98 | 25.88 |
| Production (MMcfe/d) | 198.7 | ~216 | 271.6 | 299.3 | 348.5 |
Oil-and-gas E&P companies do not present a comparable retail-style gross-margin series; adjusted EBITDAX and production are the relevant operating measures. Q2 2025–Q2 2026 rows use company earnings and presentations, with cash values rounded. Revenue includes consolidated GAAP presentation and can be affected by derivative accounting.
Business model — Appalachian upstream with owned gathering
The Q2 output mix included 216.8 MMcf/d natural gas and 12.4 Mbbl/d oil, plus NGLs. Ten Ohio Utica wells were turned into sales during Q2, including wells from the acquired acreage. The business is capital-intensive: the economic thesis depends on turning acquired inventory into durable cash flow after the $450–500M development program, not merely growing volume.
Legal, regulatory and risk analysis
Review of the latest 10-Q, 8-Ks, insider filings and targeted litigation/short-seller searches found no substantiated new company-specific class action, SEC investigation or shelf offering in the past 90 days. This is a search result, not a guarantee that no claim exists. The material recent filings were the August CFO transition, October hedge update and October analyst-field-tour presentation.
SWOT analysis
- +Q2 production 348.5 MMcfe/d, up 75% year over year
- +Adjusted EBITDAX $114.7M in Q2, up 131%
- +$875M unused revolving capacity at June 30
- +Owned gathering handles ~70% of gross gas volumes
- −Cash only $25.9M against $550M notes
- −$350M Series A ranks ahead of common
- −High $450–500M annual development budget
- −Small public float and complex Up-C ownership
- →Integration of acquired Ohio Utica wells and $25M synergy goal
- →Potential conversion of preferred if common value exceeds $21.39
- →Year-end leverage target ≤1.0x EBITDAX
- →Deep dry gas Utica pilot can add future inventory
- !Lower oil/gas prices or Appalachian basis widening
- !Well underperformance with capex already committed
- !Preferred dividends and change-of-control protections
- !Further insider or legacy-owner supply into thin Class A float
Summary by assessment area
- Real Q2 operating growth and high adjusted EBITDAX margin
- June liquidity $900.9M includes $875M unused revolver
- Base fair value $19.12, about 33% above the $14.34 reference close
- Confirmed Q3 results on November 9 can test integration assumptions
- $475M FY2026E EBITDAX is an analyst estimate, not guidance
- The bridge deducts debt, Series A preference and TRA, then uses 63.422M economic units
- Scenario-weighted value is about $17.29; commodity and capital-spending paths matter
- Analyst target consensus $21.44, above this model's $19.12
- Bear value ~$9.67 is about 33% below the reference close
- Large capex budget can consume operating cash despite production growth
- Former CFO's SEC-reported $4.79M March sale and small public float warrant attention
- The preferred instrument can divert returns from common equity
Sources: Infinity Q2 2026 release , SEC June 30 Form 10-Q , Infinity Q3 derivative update , Infinity FY2025 release , SEC pro-forma reserves PV-10 , SEC former CFO Form 4 , SEC March unit exchange Form 4 , SEC transaction code S definition , SEC CFO transition 8-K , SEC October 19 presentation notice , StockAnalysis INR price, shares and ratios , StockAnalysis October 23 price history , StockScan October 23 price history , Quiver March price history , ChartExchange March price history , StockAnalysis RRC statistics , StockAnalysis CNX statistics , StockAnalysis GPOR statistics , Investing analyst targets , MarketBeat short interest Reference market price used: INR $14.34, NYSE close 2026-10-23, cross-checked with StockAnalysis (S&P Global feed) and StockScan; 52-week range $11.13–$19.59. $14.34 × 63.422M economic units ≈ $909M as-exchanged common market value; Class A alone is 18.642M listed shares and cannot be used as the sole denominator for consolidated equity. The latest complete financial statement is June 30, 2026. Forward EBITDAX, multiples, asset proxy and scenario weights are analyst assumptions. This document is for informational purposes only and does not constitute financial or investment advice.