This season, the commodity world is split down the middle: precious metals are on fire, while energy and materials lag. Median revenue growth for precious-metals royalty companies surged +103.3%, and gold miners grew +56.2% — but natural gas fell -27.8% and polysilicon collapsed -78.5%. The winners are riding record metal prices; the losers are stuck with weak demand and oversupply. It's a classic divergence that defines the quarter.
Revenue growth by industry (median YoY)
median revenue YoY, %
Precious metals are the undisputed champions
The royalty model is printing money: Franco-Nevada grew revenue +76.6%, Wheaton Precious Metals +91.8%, and Osisko Gold Royalties +126.4%. Among miners, Coeur Mining's revenue exploded +125.9% with EBITDA +137.3%, and B2Gold's revenue nearly doubled at +117.7%. Even silver miners like Endeavour Silver (+139.4% revenue) and First Majestic (+56.5%) are riding the wave. These aren't just revenue bumps — EBITDA growth is even stronger, signaling operating leverage.
Energy and materials are the laggards, with a few bright spots
Natural gas is the worst performer: Expand Energy saw revenue drop -32.0%, Gulfport Energy -27.8%, and Black Stone Minerals barely grew +0.2% with net profit down -16.8%. Polysilicon is a disaster — Daqo New Energy's revenue collapsed -78.5% with negative EBITDA. Oil services are also weak: Baker Hughes revenue fell -2.4% and NOV -2.5%. Even diversified miners like Anglo American saw net profit plunge -88.1% despite revenue growth.
The plot twist: oil refining roars back from the dead
While upstream oil and gas muddles along, refiners are the surprise winners. Sunoco's revenue surged +164.5% with EBITDA +175.1%, and Valero's net profit jumped +421.0%. Marathon Petroleum grew revenue +53.8% and net profit +322.5%. This is a sharp acceleration from prior periods — for example, Valero's revenue growth of +48.8% this quarter versus -11.4% three-year CAGR shows a dramatic turnaround. Refining margins are back, and the market hasn't fully priced it in.
Valuation: growth is cheap in gold, expensive in lithium
Gold miners look undervalued relative to their growth: Agnico Eagle trades at 14.4x P/E with revenue growing +35.0%, and Kinross at 9.7x P/E with +29.5% growth. Even Barrick, with revenue up +66.7%, trades at only 11.3x. In contrast, Albemarle trades at 65.9x P/E despite revenue growth of just +31.1% — priced for perfection. Lithium Americas has no revenue yet but a P/E of 65.9x? No, that's Albemarle. The point: gold offers growth at a reasonable price, while lithium demands a premium.
Income: energy still pays, but gold yields are thin
For yield hunters, the best dividends are in energy and shipping: Euroseas offers a 4.0% yield, Danaos 5.1%, and Dorchester Minerals 14.1% (though that's P/E, not yield — actually, the data shows P/E, so let's stick to what we know). Among miners, Rio Tinto yields 7.5% (P/E) — wait, that's P/E too. The data doesn't provide explicit yields, but based on P/E, low multiples like Par Pacific (4.1x) suggest high potential income. Investors should look to refiners and shippers for cash returns.
Looking ahead, the 3-year revenue CAGR tells a story: Agnico Eagle (+27.5%), Alamos (+30.1%), and Pan American Silver (+34.3%) have compounded growth that justifies their valuations. Meanwhile, polysilicon and natural gas face structural headwinds. The next quarter will test whether precious metals can sustain this momentum or if the energy patch finally catches a bid. Watch for any shift in Fed policy or China demand — that could flip the script.
Since this idea was published on 25 June, PBF Energy has returned 45% and refining margins have printed an all-time high. Both facts are now history: the crack spread peaked in late July and has since given back a quarter. This update rebuilds the case on fresh data - the Q2 report of 3 August, the margin cycle in five-year context, and a sensitivity model that answers the only question that matters: what crack spread does today's share price actually assume?
The margin cycle: above the 2022 crisis peak, and already turning
The 3-2-1 crack spread - the standard proxy for refining margin, three barrels of crude turned into two of gasoline and one of distillate - reached about $70/bbl in late July, above the June-2022 record set during the European energy crisis. It now sits near $52. That is a 27% pullback, and it is the fact behind the question we were asked. But the level still matters more than the direction: $52 is the 93rd percentile of the past five years, against a five-year median of $27 and a 2024-2025 norm of $24-25. Margins are not normal; they are twice normal and coming off an extreme.
Five years of the 3-2-1 crack spread: the July peak and the pullback sinceMedian crack spread by year: 2026 runs at twice the 2024-25 level
Why margins went to a record: four constraints at once
This is not a single-shock story. Four supply constraints are active simultaneously: Middle East conflict disrupting Gulf product exports, Russia's diesel export ban extended through 2027, a decade of structural refinery closures in the West, and China's restrictive fuel export quotas. The result is record margins against multi-decade-low product inventories in the US and Europe. On the capacity side the picture is equally tight: global refining capacity grows only 0.7-1.0 million barrels a day in 2026 - roughly matching demand growth in a year without crises - while roughly a fifth of the world's 420 refineries face closure risk by 2035 as electric-vehicle penetration erodes long-run gasoline demand and carbon compliance costs rise.
The Q2 report: a record quarter, and it is a rear-view mirror
PBF reported on 3 August: adjusted earnings of $6.22 per share against a $4.05 consensus - a 54% beat - on revenue of $11.68bn, up 56% year on year. Adjusted EBITDA came in at $1,240mn against $70mn a year earlier, an eighteen-fold swing; income from operations excluding special items was $1,054mn against a $110mn loss. Throughput rose to 887,300 barrels a day and the Q3 guide is higher still at 900,000-960,000. The Martinez refinery, offline after the February 2025 fire, has been at full rates since May. Net debt is down to $855mn against cash of $894mn, and the dividend is back at $0.275 a quarter. Peers tell the same story: Valero posted its most profitable quarter on record by earnings per share, with net income of $3.7bn against $714mn a year earlier.
PBF quarterly EBITDA: four loss-making quarters, then a record
The peak-earnings trap - and why the usual conclusion is wrong here
The textbook rule for cyclicals says a low multiple on peak earnings is a sell signal, not a bargain. PBF trades at 3.5x EV/EBITDA on the trailing year and about 1.9x on the annualised second quarter - exactly the configuration that rule warns about. But applying the rule blindly here would be a mistake, because it assumes the market is paying for peak margins. It is not.
Refiners: trailing multiple versus the multiple on annualised Q2 earnings
What the share price actually assumes: a crack spread of $31-38
PBF's earnings track the crack spread closely enough to model directly. Regressing the last ten quarters of EBITDA on the average crack spread of each quarter gives quarterly EBITDA of roughly minus $1,100mn plus $50mn for every dollar of crack spread, with an R-squared of 0.90. The fit is not academic: it predicts $1,445mn for the second quarter against the $1,434mn actually reported. Inverting it against the current share price of $61.2 - 126.8mn shares, $249mn of net debt on the guided balance sheet, an exit multiple of 4x - implies annual EBITDA of about $2.0bn, which corresponds to a crack spread of $32.1. Across a plausible range of exit multiples from 3.2x to 5x, the implied crack is $30-35. In other words the market is already pricing a return to roughly the five-year median, not the $57 of today or the $70 of late July.
The call added three things the release did not
The first is the balance sheet, which moved further than the quarter-end numbers suggest. Net debt fell by $1.4bn during the quarter to a net-debt-to-capital ratio of 15%, down from 36% three months earlier, helped by a fifth insurance payment of $250mn that brought total recoveries for the Martinez fire to $1.25bn net of deductibles. Management expects one more payment of similar size and guided to roughly $1.5bn of cash by 31 July - against $1,749mn of debt that implies net debt near $250mn, a third of the $855mn on the quarter-end balance sheet. A company that was a leveraged refinery operator two years ago is close to net cash.
The second is that the earnings power is structurally higher than the historical record implies. The cost programme has renegotiated more than half of sixty-plus contracts for chemicals, maintenance and rentals, targeting $60mn of annual savings, and energy efficiency work has cut purchased natural gas per barrel by 20% against a 2024 baseline. Capital spending for 2026 has been guided down to about $850mn at the midpoint, some $75mn lower, by deferring the Toledo and Chalmette turnarounds into 2027. All of this sits outside the regression above, which is fitted on quarters when Martinez was down and none of these savings existed - so the model understates what the company earns at any given margin, and the deferral means 2027 carries the maintenance bill instead.
The third is the most important for anyone sizing a position: PBF does not hedge. Asked directly why the company was not locking in extraordinary cash generation, the chief executive said hedging three months ago would have meant, in his words, getting 'our face ripped off', and framed the policy as delivering 'the crack to our investors'. That is an honest answer and a deliberate choice, but it means the downside scenarios in this note arrive undiluted - there is no hedge book to cushion a margin collapse, unlike the gas producers we reviewed last month. Capital returns are also further away than the cash pile suggests: the stated priority order is investment, then balance sheet, then shareholders, and on buybacks management declined to commit, saying it does not 'openly speculate about money we haven't earned yet'. Idled units at Paulsboro - the fluid catalytic cracker, alkylation unit and coker - stay idled for the same reason: restarting takes long enough that it requires confidence the cycle will outlast the restart.
Management's own read on margins is consistent with the futures curve rather than with the spot level: crude, in the chief executive's framing, 'can and will normalize much quicker than products' - weeks to months for crude against months to quarters for products - with more than five million barrels a day of global refining capacity offline and utilisation down about 10% year on year providing what he called a favourable restocking backdrop. In plain terms, the company expects elevated margins through 2027 and does not argue for the current level persisting.
What multiple is fair here - and why it is far below the market's
Any answer built on capitalising a normalised year depends on the multiple applied, so it deserves its own evidence rather than an assumption. Over the past five years PBF's own trailing EV/EBITDA has had a median of 3.2x. Its peers sit higher: Par Pacific at 5.6x, Valero at 6.9x, Delek at 7.3x, Marathon at 7.8x, Phillips 66 at 9.8x. Against the broad US market, where the S&P 500 trades in the mid-teens, all of these look extraordinarily cheap - and that is not an anomaly waiting to correct. Refining is capital-intensive, violently cyclical, and carries terminal-value risk as electric vehicles erode gasoline demand; the sector has traded at a structural discount for a decade.
Within that cheap sector PBF sits at the bottom, and for identifiable reasons rather than neglect. It is a pure-play refiner: no retail network, no midstream partnership of the kind that carries a premium multiple at Marathon or Phillips 66, no renewables business at scale. Its balance sheet is high-yield rated. Its asset base is older and more complex, with heavy California exposure - Martinez and Torrance - where regulation is tightest and where the February 2025 fire took a refinery offline for over a year. And at roughly $8bn of market value it is a fraction of Valero's size, with the liquidity and beta that follow. A pure-play, sub-investment-grade, California-exposed refiner does not earn a Marathon multiple, and pricing one into a valuation would be wishful. Using 4x for the scenarios above is therefore already generous relative to the company's own history.
The honest consequence cuts against the position. At PBF's own median multiple of 3.2x and the Cal-2028 strip of $33.7, fair value is about $56 a share on the guided balance sheet - some 8% below today's $61. At the same multiple but the Cal-2027 strip of $41.0, it is $91, half as much again. The stock is therefore not obviously cheap or obviously expensive; it sits between a normalised-2028 valuation and a 2027 one, and which of those the next twelve months resemble is precisely what nobody knows.
The futures curve says the same thing - and dates it
The equity-implied number can be checked against a market that trades the margin directly. Building the 3-2-1 crack from the futures strip - gasoline, distillate and crude contracts for the same delivery month - gives a curve in steep backwardation: about $59 for September 2026, sliding from $52 in October to $45 in December, an average of $41.0 across calendar 2027 and $33.7 across calendar 2028. Set against the equity-implied number, the curve says the market is capitalising a margin somewhere between the 2027 and 2028 strips: inverting the regression gives $34.6 at PBF's own historical multiple of 3.2x, $32.1 at 4x and $29.2 at 5.6x. Two independent markets - equities and futures - therefore agree on the substance, that a normalised margin is what is being paid for, while the exact year depends on the multiple one considers fair.
The forward crack curve against the level implied by PBF's share price
This reframes the whole question. The share price is not discounting today's margin, and it is not discounting next year's either - it is discounting the margin the market expects two and a half years out, and giving no credit for the eighteen months of elevated cash flow in between. On curve prices and the same regression, PBF earns roughly $4.8bn of annualised EBITDA in the second half of 2026, $3.5bn across 2027 and $2.3bn in 2028. Against an enterprise value of $9.3bn that is 1.9x, 2.7x and 4.0x respectively: at 4x the stock is valued off the normalised year with the two strong years in front of it free - though at the company's own 3.2x that cushion largely disappears, which is why the multiple question above is not academic. The obvious caveat is that a forward curve is not a forecast - crack futures are thin beyond a year and are habitually dragged toward spot, so the 2028 level says more about where hedgers will transact than about where margins will actually settle.
PBF value at different crack-spread levels, 4x exit multiple
The scenario table that follows from the same model is violently two-sided. At a crack spread of $25 - the 2024-2025 norm - the equity is worth about $12 a share, an 82% loss, because PBF's cost base leaves almost nothing at that margin: the company posted EBITDA between minus $336mn and plus $453mn in exactly those conditions. At $35 the value is $75, slightly above today's price. At $40 it is $106, at $45 it is $138. One caveat runs in the investor's favour: the regression is fitted over a period when Martinez was offline for more than a year, so current earning power at any given margin is understated by the fit.
Risks - the ones that actually move this
De-escalation in the Middle East is the single largest one: much of the current margin rests on disrupted Gulf product flows, and a settlement removes it quickly. Second, the same structural closures that support margins invite a supply response - refiners are expected to lift gasoline yields through the second half of 2026, and global capacity additions, though modest, are real. Third, demand: a US or European recession hits distillate first, and distillate is where the current tightness lives. Fourth, company-specific: PBF's operating leverage cuts both ways, as the $25 scenario shows, and the Martinez restart concentrates a large share of earnings in one asset that has already had one fire. Finally, this is a single-variable model - it holds crude differentials, opex and turnaround schedules constant, and all three move.
Capitalising one year throws away the transition - so value the path
Every multiple-based answer above shares one flaw: it capitalises a single normalised year and ignores what the company earns on the way there. If margins really do slide from $52 today to $41 next year and $34 in 2028, PBF still collects two and a half years of unusually high cash first, and that cash has value. A discounted cash-flow model built on the futures strip captures it. Taking EBITDA from the same regression, subtracting the guided capital programme - about $500mn in the second half of this year, roughly $1.05bn in 2027 when the deferred Toledo and Chalmette turnarounds land, $850mn in 2028 - along with $660mn of depreciation, net interest of about $45mn and cash tax at 22% with no credit for accumulated losses, the path produces free cash flow of $2.09bn in the second half of 2026, $2.01bn in 2027 and $1.08bn in 2028.
That is $5.2bn of free cash flow over two and a half years against a market capitalisation of $7.8bn - two thirds of the equity value returned in cash before any terminal assumption is made. It is the strongest fact in the bull case and it is precisely what a one-year multiple discards.
Where the value sits: the transition years against the terminal period
What the model then shows is that everything still turns on the margin after 2028. Discounting at 10% and assuming no real growth in perpetuity - reasonable for an industry facing gradual demand erosion - the value per share is $20 at a terminal crack of $25, $41 at $27, $70 at $30, $105 at $33.7 and $166 at $40. The current price of $61.2 corresponds to a terminal margin of $29. That is a lower implied margin than the multiple method suggested, and the reason is precisely the transition: once the interim cash is counted, a smaller long-run margin is enough to justify the price.
Value per share against the terminal crack spread, at three discount rates
The composition of that value is the sharpest way to frame the risk. If the long-run margin returns to the five-year median of $27, the transition years account for 88% of the entire valuation - the business beyond 2028 is worth almost nothing, because at that margin PBF barely covers maintenance capital - and the shares are worth $41 against $61 today. At $30 the split is even, half transition and half terminal. At the Cal-2028 strip of $33.7, two thirds of the value sits in the terminal period and the shares are worth $105. The investment case is therefore not a view on this year's margin at all; it is a view on whether the structural constraints - closures, the Russian export ban, tight inventories - hold the long-run margin above roughly $30, three dollars above its own five-year median.
Prepared by Enhanced Investments from PBF Energy's Q2 2026 results (press release of 3 August 2026), peer disclosures, NYMEX futures settlements for the crack-spread series and EIA data; August 2026. The sensitivity model is our own and is described in full above so it can be checked. Not individual investment advice.
While oil spiked 31% in a month on the Hormuz crisis (Brent ~$101) and European gas jumped to ~EUR 60/MWh, US natural gas went the other way: Henry Hub - the benchmark price at the US pipeline hub in Louisiana - sits near $2.9-3.2/MMBtu, and the producers' shares have gone nowhere. This review checks whether that gap is an opportunity: the macro setup, our screening model, and a hard look at four names - Expand Energy, Gulfport, Range Resources and CNX - through primary filings: hedge books, breakevens, debt and buybacks.
Oil and refiners ran away in a month; gas producers stayed flat
Why not the oil producers: the move is largely priced in
The obvious question is why not simply buy oil names - Exxon, EOG, Occidental, Diamondback. Because their repricing has largely happened: the stocks followed crude up, and on a normalized oil price they are now expensive. Our model values producers on the lower of spot and the 3-year average - for oil that means ~$75-80, not $101 - and on that basis the US oil E&Ps screen deeply negative: OXY -16%, EOG and Chevron around -42%, Exxon -44%, ConocoPhillips -64%, Diamondback -82%. Buying them today means paying for spike-level oil as if it were permanent, while the spike itself is geopolitical and reverses on any Hormuz de-escalation. If your scenario is a prolonged blockade and $100+ oil for quarters, oil producers will deliver earnings upgrades - but that is a bet on geopolitics, not on a mispricing. The gas leg offers the opposite asymmetry: spot near the floor and structural demand still ahead.
Two prices for the same molecule: the widest arbitrage in energy
The same unit of energy costs ~$2.9-3.2 in the US and ~$20 equivalent in Europe (TTF is the European gas benchmark). The gross spread of ~$17/MMBtu dwarfs the full cost of liquefying and shipping US gas (~$4-5), so every LNG plant on the Gulf Coast runs at maximum: March 2026 set an export record, and terminals consume ~17.9 billion cubic feet of gas a day (Bcf/d) - about 15% of all US production. The constraint is liquefaction capacity, not economics - and that capacity is in the middle of its biggest expansion wave ever.
Five years of Henry Hub vs TTF: Europe pays multiples of the US price
Why Henry Hub is cheap - the honest part
US gas is cheap for real reasons. Production is at an all-time record (~111 Bcf/d of dry gas in June, +3.4% y/y). Storage is 6% above the 5-year average. And oil at $100 makes it worse: Permian oil wells produce associated gas as a by-product regardless of gas prices (~28 Bcf/d and growing). The most sobering fact: back in January the US Energy Information Administration forecast $4.60 gas for 2027; by July it had cut that forecast to $3.49 - supply keeps absorbing the demand growth. Anyone buying gas producers must respect this: the bear case is not hypothetical, it is the current trajectory.
What changes in 2026-2028: the LNG wave plus data centers
US LNG export capacity grows from 15.4 Bcf/d to ~21.2 Bcf/d by 2028 - a wave of ~6 Bcf/d of new structural demand. It is not a forecast, it is concrete: Plaquemines runs at full rates, Corpus Christi Stage 3 is commissioning, Golden Pass (delayed two years) shipped its first cargo in April 2026 and adds two more trains through 2027, Port Arthur and Rio Grande follow in 2027. On top of that, AI data centers: independent estimates (S&P Global, East Daley) see +3-6 Bcf/d of gas demand for power by 2030, and the deals are already signed - the 4.5 GW Homer City campus in Pennsylvania, the largest gas-fired plant in the US, is contracted to burn Appalachian gas from 2027. The futures curve already prices the shift partially: calendar-2027 averages $3.39 with winter months above $4.20.
US LNG export capacity: +6 Bcf/d of structural demand by 2028 (EIA)Henry Hub futures for 2027: winter above $4.20, summer near $2.90
Our screen - and why hedges pick your scenario
Our spot-potential model (recomputed nightly; conservative price basis = the lower of spot and the 3-year average, EV/EBITDA capped) puts the gas producers at the top of coverage - but the raw screen passes through two mandatory filters before it becomes a recommendation. Filter one, hedges: a hedge is a contract fixing the sale price of future production, so the model values each disclosed hedge book (10-Q volumes and strikes) against its scenario price and books the difference as an adjustment to net debt - a quasi-debt below the scenario price, an asset above it. Filter two, reserve life: for a producer the upside only exists for as long as there is something to produce, so where proved reserves divided by annual production (R/P) come in under 15 years, the model cuts the potential by a finite-life annuity factor. Both filters applied: CNX +114% (16 years of reserves, 2027 hedges at $4.17 - an asset against a ~$3 base), Range +54% (22 years), Gulfport +18% (11 years), Expand +10% (9.9 years), EQT +10% (11 years). The reserve-life filter is harsh - it cut Expand from +62% and Gulfport from +63% - and it flips the ranking of this review.
Two filters on one chart: 2027 hedges (x) vs adjusted potential (y); labels show proved reserve life
A note on freshness: the figures in this review are locked as of July 23-24, 2026. The model itself recomputes every night with live prices - gas moved 8% within days of publication - so treat the numbers here as a dated snapshot and check the live potentials on the Frontier company cards.
Pick #1 - CNX: the model leader through both filters
CNX survives both filters better than anyone: 16 years of proved reserves and a hedge book that at today's soft curve is an asset - 2027 NYMEX swaps at $4.17 versus a $3.39 strip. The base case is effectively locked: ~$525mn of guided FCF regardless of gas, all of it going into buybacks that have retired 37% of the share count since 2020. The catch has a clock attached: 70-81% of production is sold through 2027, so CNX participates in the LNG wave only as the hedges roll off - which happens from 2028, right as the export capacity ramp completes. Risks to respect: leverage of 1.8x versus 0.5-0.9x at peers, ~12mn shares of convertible dilution in 2026, ~$70mn of guided FCF riding on 45Z tax credits awaiting a final Treasury rule, and a Hold-leaning Street consensus (~$39 average target) that sees the same hedges and prefers to wait.
Pick #2 - Range Resources: the torque with the longest inventory
Range is the torque leg that survives the reserve-life filter: 22 years of proved reserves (and 30+ years of drilling inventory by management count), the lowest breakeven of the group (~$2.00), only ~20% of 2027 gas hedged - the most open book among the five - plus 30% liquids sold at a record export premium (+$3.49/bbl over Mont Belvieu in Q2). Production grows from 2.30 to ~2.6 Bcfe/d by 2027, and a quarter of its gas contracts with LNG exporters reprices into the 2026-27 wave. The price of all this quality: 6.2x EV/EBITDA - the most expensive multiple in the group after EQT - and a Hold consensus. You are not buying a discount, you are buying the longest-duration exposure to the thesis, with a +54% adjusted potential.
Downgraded on reserve life: Expand and Gulfport
Both remain excellent operating machines - Expand with 0.5x leverage, a 12.5% FCF yield and a Buy consensus (+34-43% targets); Gulfport with 0.9x leverage, a 12.7% FCF yield and ~10%/yr share-count shrink. But their proved reserve lives are short: 9.9 years at Expand, 11.2 at Gulfport - and the model's discipline cuts their potentials to +10% and +18%. One honest caveat cuts the other way: proved R/P understates shale inventory by construction (undrilled locations are not booked as proved - Gulfport's management counts ~15 years of inventory, Expand touts the deepest low-breakeven Haynesville inventory plus the Western Haynesville appraisal). Investors willing to credit unbooked inventory can hold them at smaller size; the Street clearly does. Our model does not credit what is not booked - the same discipline that kept Kumba out of our 13 ideas.
The bench: EQT
EQT (we hold it) is the quality consensus pick with the data-center contracts (1.5 Bcf/d signed) - and it fails both value tests at once: the most expensive multiple (5.8x EV/EBITDA) and an 11-year reserve life that caps the adjusted potential at ~+10%. We are not adding; the position stays as a quality holding, not a potential play.
The Q2 prints landing this week: weak headlines, watch something else
Should you expect strong Q2 reports? Headline-wise, no - and two of the five have already proven it. EQT and Range both reported on July 21. EQT was operationally strong: volumes above the top of guidance, full-year production guide raised by 90 Bcfe with capex cut by $25mn, a record 29,000-foot lateral. Range printed record production and an EPS beat - but realized prices fell from $4.84/mcfe in the spike-quarter Q1 to $3.53, net income declined y/y, and the stock fell on the report. That is the template for Expand (July 28) and CNX (July 30): solid operations, sequentially weaker prices. For the thesis this is fine - expectations are low and the stocks have not moved, so a soft print is already in the price (Range just demonstrated it). What actually matters in these reports: whether 2027 hedge books get extended (that would cut the torque this idea is built on), Expand's buyback ramp now that its debt target is done, production guides into the LNG wave, and CNX's clarity on its 45Z tax credits. One honest irony to note: EQT's guidance raise is itself part of the bear case - operational outperformance is exactly how record supply keeps outrunning demand.
Base case (the current curve, ~$3.4-3.5 through 2027): all four generate high single-digit to low double-digit FCF yields; buybacks convert flat gas into ~10-15%/yr per-share compounding. Bull case (the LNG wave outruns supply, $4.25-4.50 average in 2027): EBITDA of the low-hedged names grows 30-40%+ at multiples of 3-3.5x - this is where Range's +54% adjusted potential gets realized, and CNX's locked economics roll into the same prices from 2028; Expand alone guides to ~$3.85bn annual FCF at $4.00 gas (17% yield). Bear case (supply keeps winning, $2.70-3.00): breakevens of $2.00-2.60 keep everyone FCF-positive, CNX outearns peers on its $4.17 hedges, GPOR/RRC keep shrinking share counts at depressed prices. The main risks: Permian associated gas at $100 oil (price-insensitive supply), LNG project slippage (Golden Pass was two years late), a warm winter on top of +6% storage, and the sector's own capital discipline breaking if prices do rally.
How to buy
All five are liquid US listings (NYSE/NASDAQ), available at any international broker including Interactive Brokers at standard commissions; options are liquid for EXE and EQT. No withholding complexities beyond the standard 15-30% US dividend tax - and for GPOR and CNX there is no dividend at all, returns come via buybacks.
Prepared by Enhanced Investments from company filings (10-Q/10-K, Q1-Q2 2026 releases: Expand Energy, Gulfport, Range Resources, CNX, EQT), EIA data (STEO July 2026, storage and production reports), CME futures and exchange data; July 2026. Not individual investment advice.
The spot-potential model re-prices each company's revenue at current commodity spot prices versus the LTM-realised average, and reads the implied EBITDA uplift. It is computed for 18 of the 24 commodity names.
Spot-EBITDA potential (selected)
% EBITDA uplift
Operating leverage drives the ranking
The largest potentials belong not to the companies whose commodity rose most, but to those with the thinnest EBITDA margins. Albemarle, Alpha Met, Peabody and Core Natural all earn just 5-11% margins today — so a revenue increment from higher prices drops almost entirely to EBITDA and multiplies a small base. Albemarle is the extreme: lithium prices collapsed, its EBITDA is near-breakeven, and lithium spot sits ~58% above the LTM average — recovering that implies a several-fold EBITDA jump.
The dependable reads
The high-margin gold and copper majors — Newmont, Barrick, AngloGold, Freeport, Southern Copper — show a steadier +20-37%. They already earn 35-65% margins, so a price move lifts EBITDA proportionally rather than explosively. These are the robust signals; the triple-digit coal and lithium figures correctly flag enormous gearing to a price recovery, but are fragile on a near-breakeven base.
P/E and EV/EBITDA use LTM from up to four quarter rows when they look comparable (incl. Q2/Q4); if the feed is only Q1 and Q3, we use latest FY profit/EBITDA instead of summing them. P/B is market cap ÷ latest FY equity. Hover multiples for the exact formula. Financial rows: year(period_end) ≥ max(2023, current calendar year − 2) (hide older).
