The Hedge Tax: Who's Capturing $95 WTI and Who's Leaving It on the Table

Source data: Q1 2026 10-Q filings (EOG Resources, EQT Corporation, Expand Energy, Diamondback Energy, SEC EDGAR). Current commodity prices: Yahoo Finance, June 4, 2026.

The Hedge Tax

WTI is sitting at $95.13 this morning. Henry Hub is at $3.254. If you're an E&P operator who locked in oil at $72 a barrel last fall and natural gas at $2.80, you're not celebrating. You're watching the market hand your unhedged peers a 30% premium you won't see.

That's the fundamental tension in upstream finance right now: hedging was designed to protect cash flow during downturns. In a $90+ WTI environment driven by geopolitical disruption, it functions instead as a tax on upside. The companies that understood this, or got lucky betting against it, are generating materially more cash per barrel than those that played it safe.

The Q1 2026 10-Q filings are out, and the divergence is stark.

EOG: The Discipline of Not Hedging Oil

EOG Resources (EOG) is the textbook case for what an unhedged oil strategy looks like when prices cooperate. The company's Q1 2026 income statement shows crude oil and condensate revenue of $3.577 billion, up from $3.293 billion in the prior year quarter. That $284 million increase was driven almost entirely by price, not volume.

EOG's Q1 2026 income statement line reads: "Gains on Mark-to-Market Financial Commodity and Other Derivative Contracts, Net: $113 million." But the cash flow statement tells a more interesting story: net cash payments for settlements of commodity derivative contracts were $53 million outflow. EOG does use financial instruments for natural gas and basis management, but its oil is sold essentially at spot. The company does not hedge crude oil as a matter of policy, a philosophy consistently restated across multiple annual reports and investor presentations. Per EOG's Q1 2026 10-Q (SEC accession 0000821189-26-000104), the company's derivative program covers natural gas positions, not oil.

At $95 WTI, that philosophy is generating results. Q1 2026 net income: $1.98 billion. Diluted EPS: $3.70. Operating cash flow: $2.97 billion. EOG returned $545 million in dividends and repurchased $402 million in stock in a single quarter.

CIR Analysis: EOG's cost structure, roughly $38-40/boe all-in, gives it the balance sheet durability to sustain a no-oil-hedge philosophy through down cycles. The bet paid off dramatically in Q1 2026. Every dollar above the company's full-cycle breakeven went straight to shareholders.

Diamondback: Minimal Hedging, Maximum Capture

Diamondback Energy (FANG) took a $1.4 billion non-cash ceiling test impairment in Q1 2026, which dominated the headline P&L. Strip out the accounting noise and the cash story is different: the company received $133 million in net cash from settlement of derivative instruments in Q1. That is not a hedge tax; it is a hedge benefit. FANG's derivative positions, as disclosed in Note 12 of its Q1 2026 10-Q (SEC accession 0001539838-26-000077), were structured at levels that captured upside when WTI ran.

Q1 2026 oil revenues: $3.445 billion. Gain on derivative instruments: $117 million. Net cash from operations: $1.828 billion.

Diamondback has been explicit with investors about its hedging philosophy: the company targets minimal oil hedging to preserve upside exposure. In the current environment, that approach, paired with Permian Basin cost efficiency, is rewarding shareholders. The February 2026 secondary offering of Viper Energy shares generated $589 million in proceeds, used for debt reduction. Diamondback ended Q1 with $174 million cash and long-term debt of $13.15 billion against a $70 billion asset base.

The Gas Hedge Tax: EQT and Expand Energy

If oil hedging is a muted story in Q1 2026, the natural gas hedge picture is louder, and more painful for the hedged operators. Henry Hub averaged roughly $4.50-$5.00/MMBtu through the January 2026 winter storm period before settling into the $3.00-$3.25 range. Companies that hedged heavily at $2.80-$3.00 left significant money on the table during the spike, and continue to surrender upside as the $3.25 floor reasserts itself.

EQT Corporation (EQT) reported a "Loss on derivatives" line of $238.3 million for Q1 2026. For context, the same line showed a $678.9 million derivative loss in the prior year quarter, when gas prices were lower and EQT's hedged positions generated settlement outflows. The hedge dynamic has shifted: with Henry Hub moving higher, EQT is now paying cash to settle positions rather than receiving it. Per EQT's Q1 2026 10-Q (SEC accession 0000033213-26-000030), net cash settlements paid on derivatives were $303.7 million outflow in Q1. That is actual cash out the door to hedge counterparties in a quarter where Henry Hub averaged above $3.00/MMBtu. Despite that drag, EQT posted Q1 net income attributable to EQT of $1.487 billion on revenues of $3.44 billion. The underlying gas business is generating enough to absorb the hedge cost, but the cost is real.

Expand Energy (EXE), the largest U.S. natural gas producer by daily output, has the most extensive hedge book in the sector. As of March 31, 2026, per EXE's Q1 2026 10-Q (SEC accession 0000895126-26-000028, Note 11), EXE's derivative exposure includes:

Natural gas notional positions (Bcf):
Fixed-price instruments: 869 Bcf  |  Two-way collars: 858 Bcf  |  Three-way collars: 680 Bcf  |  Call options (sold): 55 Bcf  |  Basis protection: 261 Bcf
Total natural gas notional: 2,723 Bcf

The net fair value of EXE's derivative portfolio was a $556 million asset as of March 31, 2026, up from $307 million at year-end 2025. Cash paid on derivative settlements in Q1 2026 was $386 million outflow. EXE recorded $129 million in "losses on derivatives" for the quarter. This compares to a $1.014 billion derivative loss in the prior year quarter, when lower gas prices made EXE's hedged positions more favorable to settle.

CIR Analysis: EXE's hedge book is a structural feature of the business, not a speculative position. As the largest U.S. gas producer with long-duration transportation commitments and LNG offtake contracts under development (including the 20-year Delfin FLNG SPA signed in Q1 2026 for 1.15 MTPA from 2031), EXE runs a portfolio business that requires cash flow predictability. The hedge cost is a reasonable price for the optionality their LNG infrastructure buildout requires. But at $3.25 Henry Hub, they are paying a visible premium to be hedged.

The Hamm Philosophy: No Public Filings, But a Living Legacy

Note: Continental Resources completed a going-private transaction in November 2022 and no longer files public financial statements with the SEC. All references below reflect Harold Hamm's publicly documented views from prior to that date.

No executive in US upstream was more vocal about the futility of oil hedging than Harold Hamm. During Continental Resources' years as a publicly traded company, the operator regularly ran one of the lightest hedge books in the Bakken. Hamm's argument was simple: you drill because you believe in long-term commodity value. Hedging is an admission that you don't. When oil ran to $100+ in 2022, Continental's minimal hedge position allowed full market participation. The Hamm philosophy, expressed repeatedly in earnings calls and investor materials before the company went private, lives on in the operating culture of several US independents.

The Math at $90 vs $85 vs $95

Here is what the arithmetic looks like for an oil-weighted operator producing 100,000 bbl/d with a $60/boe breakeven:

At WTI $85: Unhedged operator captures $25/boe margin = $2.5M/day.
If hedged at $72: locked at $12/boe margin = $1.2M/day (negative $1.3M/day vs. unhedged).
Hedge cost per year: approx. $475M.

At WTI $90: Unhedged captures $30/boe = $3.0M/day.
Hedged at $72: $12/boe = $1.2M/day (negative $1.8M/day).
Hedge cost per year: approx. $657M.

At WTI $95: Unhedged captures $35/boe = $3.5M/day.
Hedged at $72: $12/boe = $1.2M/day (negative $2.3M/day).
Hedge cost per year: approx. $840M.

These are illustrative figures using round numbers. For a major Permian operator producing 300,000 to 500,000 bbl/d, the math scales accordingly, and the divergence between hedged and unhedged operators is measured in billions, not millions.

CIR Analysis: The operators who hedged 40-60% of 2026 oil production at $70-75/bbl in the fall of 2025, when the futures strip was pricing WTI well below current spot, are now realizing those positions cost them significant free cash flow per quarter. At $95 WTI, the insurance premium is punishing. The operators who stayed light had to absorb more volatility, but at this price level, the bet was right.

Supermajors and Diversified Companies: Structural Hedges

ExxonMobil (XOM) and Chevron (CVX) do not disclose traditional crude oil hedge books the way an independent E&P would. Their protection is structural: diversified downstream, refining margins that expand with crude price changes, integrated chemical businesses. When WTI rises, their refining crack spreads narrow on the product side, a natural hedge that limits downside but also costs upside.

ConocoPhillips (COP) maintains a modest financial derivative book relative to production. COP's Q1 2026 results showed Alaskan production and LNG portfolio benefits. The company's low-cost inventory thesis, with sub-$35/boe supply costs on average, means that at $95 WTI, hedging is less critical to balance sheet protection than it would be for a higher-cost operator.

BP operates as a trading house as much as an E&P. Its commodity risk management function is a profit center in its own right, meaning "hedging" for BP blends speculation, inventory management, and price protection. Direct comparison to US independents on hedge economics is apples-to-oranges.

Who Is Capturing the Full Geopolitical Premium

The operators benefiting most from the current $90+ WTI environment are, broadly:

Unhedged or lightly hedged oil producers: EOG Resources, Diamondback Energy, Permian Resources (PR), APA Corp (APA). These companies are selling oil at or near $95 spot with no futures positions capping their realizations.

Partially hedged, well-positioned: ConocoPhillips, Devon Energy (DVN). Some hedged volumes but light enough that the majority of production benefits from spot market exposure.

Gas-heavy with large hedge books: EQT Corporation and Expand Energy are capturing less upside on every Mcf than their unhedged counterparts. Their hedge infrastructure, built to support LNG development timelines and investor return commitments, has a visible cost at current prices.

The Bakken angle: Chord Energy (CHRD) has been more aggressive about monetizing upside and running a lighter hedge book relative to its Williston Basin production base.

What H2 2026 Tells Us About Operator Confidence

The hedging decisions operators are making right now for H2 2026 are revealing. Companies entering the second half with minimal new hedge positions are implicitly signaling they believe $90+ WTI is sustainable, that the geopolitical premium is structural, not a spike.

EXE and EQT are building out incremental hedge positions at current gas strip prices because their business models require cash flow predictability for LNG infrastructure commitments. That is rational. But for oil operators with lower-cost Permian and Bakken inventory, the calculus favors staying open.

CIR Analysis: The operators who will look smartest in Q3 and Q4 2026 earnings calls are those who hedged minimally at $90+, locking in enough to satisfy bank covenants and dividend coverage, but leaving the majority of production exposed to spot. If the Iran situation stabilizes and WTI corrects toward $82-85, those operators will have been lucky. If the geopolitical premium holds, they will be geniuses. In the current environment, unhedged looks more like conviction than recklessness.

What To Watch

• Q2 2026 hedge disclosures: Operators updating hedge books in July earnings calls will signal whether confidence in $90+ is hardening or softening.
• EQT and EXE cash settlements: Both will report Q2 hedge settlement payments; if Henry Hub stays at $3.25+, those outflows will be substantial again.
• EOG natural gas hedge roll: EOG's Q2 filing will show whether they are adding any commodity protection as nat gas prices firm.
• FANG derivative structure updates: Diamondback's derivative note in Q2 will show whether they have extended the minimal hedging approach or added protection as they work through debt reduction.
• WTI vs. Brent spread: US Gulf Coast export window remains wide; domestic unhedged operators are realizing Argus WTI Houston prices well above WTI Cushing.

Disclosure: The author/publisher holds positions in EQT Corporation (EQT) and Expand Energy Corporation (EXE) as of the publication date. This does not constitute investment advice.

Crude Intelligence Report is an independent upstream oil and gas intelligence publication. The content in this article is for informational purposes only and does not constitute investment advice, financial advice, or a recommendation to buy or sell any security. Always conduct your own due diligence before making investment decisions. CIR and its contributors may hold positions in companies mentioned; any such positions will be disclosed when known. © 2026 Crude Intelligence Report. All rights reserved.

This article contains forward-looking statements and analytical opinions. Actual results may differ materially.