Q1 2026 Earnings Season Preview: The $100 Test

April 10, 2026 — Houston

In any other year, a quarter in which the energy sector surged nearly 38% while the S&P 500 finished negative would be the dominant investment story. This year, it barely registered above the noise of Hormuz drone strikes, ceasefire announcements, and presidential press conferences. But the Q1 numbers matter — and earnings season, which kicks off in earnest over the next three weeks, will determine whether the extraordinary returns of January through March were justified fundamentals or geopolitical-panic froth.

This is CIR's in-depth preview of what to watch, who's positioned, and where the landmines are.

The Q1 Setup: A Quarter Unlike Any Other

According to OilPrice.com's analysis published April 7, 2026, energy was the clear standout of Q1, surging nearly 38% for the quarter. Tight global supply, strong refining margins, and persistent geopolitical risk kept crude prices elevated and cash flows strong across the sector. According to the same analysis, the rally was broad and fundamental: 38 of 40 upstream S&P 500 companies finished Q1 in positive territory, the big three refiners averaged 48.6% returns, and tanker stocks led midstream with gains above 45%.

The macro backdrop was straightforward: WTI averaged well above $100/bbl through most of the first quarter, driven by the Strait of Hormuz disruption that began in mid-February and progressively tightened global crude routing. Henry Hub natural gas also saw elevated realizations relative to Q4 2025 lows. For most upstream E&Ps, Q1 2026 will represent the highest revenue quarter they've reported in years.

CIR Analysis: The key question for earnings season isn't whether companies made money in Q1 — they almost certainly did, in scale. The question is what they do with it, and whether their forward guidance reflects a "higher for longer" price environment or a more cautious return to capital discipline. Investor patience with management teams that either overspend or disappoint on buybacks will be thin after a decade of watching producers destroy value at the top of cycles.

ExxonMobil: The Elephant in the Room

According to OilPrice.com, ExxonMobil (NYSE: XOM) has signaled that surging oil and gas prices triggered by the Iran conflict could increase its first-quarter upstream earnings by approximately $2.9 billion relative to Q4 2025 — a figure that would represent one of the largest quarter-over-quarter earnings acceleration events in the company's modern history.

This is not a surprise; it is confirmation of a structural reality. ExxonMobil's acquisition of Pioneer Natural Resources closed in mid-2024, nearly doubling its Permian Basin footprint. The combined entity now produces approximately 1.3 million barrels per day of oil equivalent from the Permian alone. At $100+ WTI, that production base generates cash at a rate that dwarfs anything Pioneer's management team imagined when they sold.

CIR Analysis: Exxon's Q1 report — expected in late April — will be the most watched print of the season. Beyond the headline earnings number, investors will be scrutinizing: (1) Permian production volumes vs. guidance; (2) realized price differentials given WTI Midland/Cushing dynamics; and (3) capital allocation — specifically whether the company accelerates buybacks or redirects cash toward announced CCS projects. The $2.9B upstream tailwind estimate was provided before the ceasefire-collapse-and-recovery cycle that occurred in early April. The actual Q1 number may differ, and management commentary will be closely watched for guidance on Q2 sensitivity to the current $95–$98 WTI range.

Shell: The Integrated Gas Headwind

Not every major will report uniformly strong results. According to Rigzone's April 8 reporting, Shell expects production in its Integrated Gas segment to fall to 880,000–920,000 barrels of oil equivalent per day in Q1 2026, down from 948,000 boepd in Q4 2025, due to "the impact of the Middle East conflict." The company separately signaled "significantly higher" adjusted earnings in oil trading, partially offsetting the production shortfall.

Shell's situation illustrates a critical asymmetry in this cycle: upstream producers with Middle East exposure or LNG operations subject to Hormuz routing are not the clear winners the headlines suggest. Producers with purely domestic, Permian-heavy portfolios — insulated from tanker risk and with direct access to Gulf Coast export infrastructure — are the beneficiaries. Shell's more diversified global exposure means its results will be a messier read.

CIR Analysis: Shell's Integrated Gas miss is a preview of what we'll hear from TotalEnergies, BP, and Equinor — all of which have material exposure to Middle East production or LNG volumes affected by Hormuz routing constraints. For U.S.-focused readers, this asymmetry is the structural argument for owning domestic E&Ps over integrated majors in a Hormuz-disrupted world.

The Permian: Printing Money

For Permian-focused operators — Diamondback Energy (FANG), Coterra Energy (CTRA), Pioneer/ExxonMobil, Chevron's Permian assets — Q1 2026 will be a showcase quarter. The variables are tight: WTI averaging above $100, Permian differentials narrowed by strong Gulf Coast export demand (itself driven by Asian buyers rerouting away from Middle East barrels), and production volumes running at or near plan given the rig count stability of Q4 2025 and Q1 2026.

There is one Permian-specific wildcard worth noting: NGL realizations. According to Reuters reporting cited in the CIR Friday morning brief, Asia's largest LPG importers — India and China — are paying record spot premiums to source cargoes from the Americas after Middle East supply disruption. Permian Basin NGL recoveries tied to Mont Belvieu are seeing widening realizations — a positive margin tailwind that's largely absent from consensus estimates heading into earnings season. Operators with significant NGL yield (particularly ethane-rich Delaware Basin production) may post upside surprises on realized pricing.

CIR Analysis: The NGL tailwind deserves more attention than it's getting. Diamondback's Delaware Basin assets, Coterra's Permian/Anadarko mix, and Civitas Resources' expanding Permian footprint all carry meaningful NGL exposure. If Mont Belvieu NGL pricing remained elevated through March — which CIR believes it did, given Asia sourcing disruption — we may see multiple companies beat on realizations even before anyone mentions crude price.

Gas Producers: A Tale of Two Stories

The natural gas picture entering Q1 earnings is more complicated. Henry Hub averaged approximately $2.60–2.70/MMBtu through Q1 2026 — below the $3+ needed for most Appalachian and Haynesville operators to generate compelling returns on new wells. However, the Hormuz disruption has created a secondary effect: LNG feedgas demand has remained elevated as export terminals ran at high utilization to meet Atlantic Basin demand from Europe and the Mediterranean.

For Haynesville-focused operators — Expand Energy (formerly Chesapeake), Comstock Resources — this LNG export demand premium has partially offset weak spot Henry Hub pricing. Their realized prices include a meaningful Gulf Coast basis that tracks Sabine Pass and Cameron LNG netbacks more closely than Henry Hub spot.

Appalachian producers face a different math. EQT, Range Resources, and Coterra's Appalachian assets sell into regional markets where winter heating demand has long since passed. Their Q1 realizations will reflect pure Appalachian basis, which has not benefited from the LNG tailwind the same way east Texas/Louisiana production has.

CIR Analysis: Watch EQT's Q1 hedging disclosure carefully. In prior quarters, EQT has been more aggressive than peers with forward hedges — a strategy that limits upside but protects against the Henry Hub weakness we've seen. If they're significantly hedged below $3 for Q1, their reported realizations will look worse than operators who ran unhedged into a slightly firmer price environment. This is a nuance that consensus models often miss.

The Energy-Chemical Derivative Story

One underreported dimension of Q1 earnings season extends beyond upstream E&Ps into the petrochemical complex. According to OilPrice.com, U.S. chemical companies have suddenly turned bullish on their prospects after years of bleak margins, benefiting from cheap domestic feedstocks (primarily ethane from the Permian and Appalachia) while their Asian and European competitors face supply shortages and high input costs.

According to the same analysis, shares in Dow (NYSE: DOW) have soared more than 70% year to date, while LyondellBasell (NYSE: LYB) has jumped over 80%, both vastly outperforming the S&P 500. This chemical-sector divergence is directly upstream-linked: low-cost Permian ethane is the feedstock that makes these margins possible. For CIR readers managing or investing in upstream businesses, this is a real-world validation of the U.S. shale competitive advantage — and it's showing up in chemical company stock prices before it appears in upstream operators' realizations (which it will, through NGL pricing).

CIR Analysis: The chemical-petrochemical tailwind is a lagging indicator that validates the current upstream pricing environment. It also sets up an interesting downstream demand read: if U.S. chemicals producers are running at full capacity, their ethane and NGLs demand will remain strong through H2 2026 regardless of what happens with crude prices. That's a partial hedge on Permian NGL economics that most upstream models don't adequately capture.

What Investors Will Be Watching

Beyond headline earnings, the four questions that will define this earnings season:

1. Capital allocation signals: With cash flows at multi-year highs, will operators accelerate buybacks, raise dividends, or add capital? Investor preference for shareholder returns over production growth remains strong after years of conditioning. Any management team that signals material capex increases — even justified by the price environment — risks a negative market reaction.

2. Hedge book exposure: Operators heavily hedged at sub-$90 WTI heading into Q1 will report materially lower realizations than strip prices suggest. Hedge books are the great equalizer in high-price environments — and the great disappointment. The most hedged names may report technically strong cash flows but miss revenue expectations.

3. Q2 and full-year guidance: The bigger story than Q1 is what management teams say about Q2. WTI is currently trading near $97–98 — well below Q1 averages in the $100–$115 range. If companies guide conservatively to $85–90 WTI strip for Q2 and full-year, that guidance will be the headline, not the Q1 beat.

4. Hormuz sensitivity language: Every earnings call will feature questions about Middle East exposure, geopolitical risk premiums, and what scenario planning looks like for a complete Hormuz reopening. Management teams that answer these questions with specificity and credibility — showing they've modeled the downside — will earn more trust than those who paper over the uncertainty with optimistic platitudes.

The CIR Watch List

The five names CIR will be tracking most closely through earnings season:

• ExxonMobil (XOM) — Scale of Permian/Pioneer integration gains, NGL realizations, CCS capital allocation
• Diamondback Energy (FANG) — Operational efficiency data, Delaware Basin NGL yield, buyback pace
• EQT Corporation (EQT) — Appalachian hedging disclosure, Henry Hub basis, Mountain Valley Pipeline contribution
• Expand Energy (EXE) — LNG feedgas premium capture, Haynesville completion activity
• Coterra Energy (CTRA) — Multi-basin read (Permian + Marcellus + Anadarko), capital allocation balance

CIR Analysis: This earnings season is simultaneously the most straightforward in years (high prices = high cash flows) and the most analytically complex (hedging, Hormuz exposure, guidance uncertainty). The operators that emerge with upgraded consensus estimates and credible Q2 guidance will likely see further multiple expansion in their shares. Those that disappoint on hedging overhangs or guide conservatively — even prudently — may give back some of Q1's extraordinary gains.

The $100 test for this industry isn't just about whether operators made money. It's about whether they learned anything from the last time oil prices spiked and capital discipline evaporated. The evidence so far suggests a more measured sector — but earnings season will be the first real stress test of that discipline claim.

Editor's Note: This article contains forward-looking statements and analytical opinions based on publicly available information. Actual earnings results may differ materially from estimates referenced above. All company projections (e.g., Exxon's $2.9B earnings bump signal) are based on publicly disclosed pre-earnings guidance; final results have not yet been reported as of publication.

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. This article contains forward-looking statements and analytical opinions. Actual results may differ materially. © 2026 Crude Intelligence Report. All rights reserved.