Bernstein favors integrated oils, FANG and DVN as elevated oil and refining conditions persist into autumn.

Overview

Bernstein assesses how to position in Americas oil equities into autumn amid elevated crude prices, unusually strong refining margins and geopolitical disruption. It expects eventual normalization but does not expect the next few months to deliver clarity, favoring integrated producers as a hedge and FANG and DVN among E&Ps.

Core views

Bernstein’s central premise is that oil prices tend over the long run toward marginal supply cost. Brent was above $90/bbl at publication, versus an estimated marginal cost of roughly $75/bbl, so the report expects eventual mean reversion rather than treating the prevailing price as a permanent mid-cycle level. However, commercial inventories have drained significantly during the year, and Bernstein argues that spot oil prices reflect commercial OECD inventories while largely ignoring strategic inventories. This inventory backdrop supports the current premium. US Strategic Petroleum Reserve releases have helped cap crude prices, according to the report, but the SPR is near record-low inventory levels. Bernstein therefore sees further releases as less likely and argues that low SPR levels could create a practical floor if prices fall modestly below marginal cost because refilling could then become relevant. The report distinguishes this crude-price effect from refined-product pricing: SPR releases may affect crude, but are less likely to resolve elevated product prices. Refining margins remain more elevated than crude prices. The 3-2-1 crack spread measures refined-product value relative to crude input cost, and Bernstein attributes record diesel cracks, more elevated than gasoline cracks, particularly to disruption involving Russia. Historical analysis places average crack spreads at 20% of oil prices before 2012 and 33% after 2012; the report says they have been roughly one-third of oil prices over the past decade. Current crack spreads are near records while crude has pulled back, producing a crack-implied oil price of about $120/bbl. Bernstein expects refining margins to normalize eventually as well, but regards the current disconnect as material. Geopolitical tension is the third source of support. Bernstein’s model combines macroeconomic variables with the Geopolitical Risk Index to explain real Brent prices over more than 90 quarters, from 1988 through April 2026. The model explains about 70% of the variation in real oil prices and, on current inputs, implies Brent near $98/bbl, above spot. The report argues that geopolitical events can create actual supply disruption or perceived supply risk over horizons ranging from quarters to years; Ukrainian drone attacks on Russian refining assets are cited as an important contributor to current conditions. For equities, Bernstein says its oil coverage generated a median 36% return in 2026, led by more leveraged KOS and APA, while lower-beta integrateds lagged. All covered names saw 2027 EBITDA estimates rise from the start of the year and from before the Hormuz conflict; excluding DVN’s merger-driven EBITDA increase, consensus expects group 2027 EBITDA to be 7% higher than at the start of the year. Median valuation multiples expanded 17%, or less than one turn. Bernstein sees consensus EBITDA as too low and therefore observed multiples as too high, while stating that future valuation upside is primarily dependent on EBITDA growth because multiple expansion appears limited. The report finds no meaningful group-wide re-rating or de-rating over the past five years. All covered names trade above their five-year valuation average, with DVN slightly flat, although EOG, DVN, KOS and APA appear below average on a longer-term valuation basis. Bernstein links higher multiples more to defensiveness and shareholder cash returns than to growth or EBITDA margin; capital intensity is negatively correlated with valuation. Integrateds are favored as the best hedge against the crude-product disconnect because they receive current earnings support from refining margins and retain upstream upside if crude catches up to product-market signals. Bernstein prefers XOM among integrateds and FANG and DVN among E&Ps, citing FANG and DVN’s asset quality and Henry Hub gas exposure. Bernstein does not recommend trimming before an obvious catalyst, but remains alert. Its conclusion is that geopolitical and oil-price normalization should ultimately occur, including an end to the US-Iran and Russia-Ukraine conflicts, yet it does not see a reason to expect clarity in the next few months.

Analysis framework

Bernstein first benchmarks crude against marginal supply cost and commercial inventories, then assesses the effect and limits of SPR releases. It tests the crude-product disconnect through historical crack-spread relationships, uses a macroeconomic and geopolitical-risk model for Brent, and evaluates equities through EBITDA revisions, valuation multiples, shareholder-return and capital-intensity comparisons.

Methodology notes

• Industry AnalysisSupply-demand framework

  Marginal-cost and inventory analysis for oil pricing

  The report treats long-run marginal supply cost as an anchor for oil prices and uses commercial inventory levels to explain why spot crude can trade above that anchor.

• Industry AnalysisVolume-price decomposition

  Crude price and crack-spread decomposition

  Bernstein separates crude pricing from refining margins, using the 3-2-1 crack spread and product prices to assess the implied crude-price signal.

• Macroeconomics

  Macroeconomic variables plus the Geopolitical Risk Index model

  The model relates real Brent prices to macro factors and geopolitical risk; Bernstein uses its current inputs to estimate Brent near $98/bbl.

• Valuation methodsEV/EBITDA valuation

  Forward EV/EBITDA valuation comparisons

  The report compares covered companies’ forward EV/EBITDA with the S&P 500, their own history and peers, alongside EBITDA estimate changes.

Asset mapping & comparison

Structured mapping from thesis to named assets (strengths, weaknesses, peers, risks).

• XOM (Exxon Mobil)

  Preferred integrated oil company.

  Strengths

  Elevated refining margins support current earnings; higher crude prices would add upstream upside.

  Comparison

  Bernstein prefers XOM among integrateds.

  Risks

  Eventual normalization of refining margins and oil prices.

• FANG (Diamondback)

  Preferred E&P.

  Strengths

  High-quality asset base and Henry Hub gas exposure.

  Weaknesses

  Double Eagle acquisition negatively affects free cash flow.

  Comparison

  Preferred with DVN among E&Ps.

  Risks

  Oil-price normalization and limited multiple expansion.

• DVN (Devon Energy)

  Preferred E&P.

  Strengths

  High-quality asset base and Henry Hub gas exposure.

  Weaknesses

  2027 EBITDA increase is heavily affected by the CTRA merger, making it an outlier.

  Comparison

  Preferred with FANG among E&Ps.

  Risks

  Oil-price normalization and merger-related comparability.

• CVX (Chevron)

  Covered integrated oil company.

  Strengths

  Strong refining business and sustainable business model support valuation relative to much of the group.

  Comparison

  Identified with XOM as an exception benefiting from refining.

  Risks

  Eventual normalization of refining margins and oil prices.

• COP (ConocoPhillips)

  Covered E&P.

  Comparison

  Included in sector valuation and oil-beta analysis.

  Risks

  Oil-price normalization and limited multiple expansion.

• EOG (EOG Resources)

  Covered E&P.

  Strengths

  Appears below average on a longer-term valuation basis.

  Comparison

  Included in sector valuation and oil-beta analysis.

  Risks

  Oil-price normalization and limited multiple expansion.

• APA (APA)

  Covered E&P.

  Strengths

  More leveraged oil exposure contributed to leading 2026 performance.

  Weaknesses

  Smaller-cap oil-weighted E&Ps underperformed integrateds historically.

  Comparison

  Led sector performance with KOS.

  Risks

  Oil-price normalization and higher leverage to oil conditions.

• KOS (Kosmos Energy)

  Covered E&P.

  Strengths

  More leveraged oil exposure contributed to leading 2026 performance.

  Weaknesses

  Smaller-cap oil-weighted E&Ps underperformed integrateds historically.

  Comparison

  Led sector performance with APA.

  Risks

  Oil-price normalization and higher leverage to oil conditions.

Key data

• Brent price> $90/bblAbove Bernstein’s estimated marginal cost of roughly $75/bbl.
• Marginal supply cost~$75/bblBernstein’s long-run anchor for mid-cycle oil pricing.
• Crack-implied oil price~$120/bblDerived from currently elevated gasoline and diesel crack spreads.
• Geopolitical-risk model Brent estimate~$98/bblBased on current inputs; above spot price.
• Model explanatory power~70%Share of real oil-price variation explained across more than 90 quarters.
• Coverage median return in 202636%KOS and APA led; integrateds generally lagged.
• 2027 group EBITDA revision7% higherVersus start-of-year consensus, excluding DVN’s merger impact.
• Median multiple expansion17%Less than one turn on 2027 estimates.
• Historical crack-spread ratio20% pre-2012; 33% post-2012Bernstein’s historical comparison of crack spreads as a share of oil price.

Impact & implications

Bernstein sees integrated oils as the clearest hedge while refined-product margins remain elevated and crude may rise toward the product-market signal. It expects limited scope for sector-wide multiple expansion, making EBITDA delivery, capital intensity, defensiveness and shareholder cash returns more important valuation drivers.

What to watch

• Commercial OECD inventory trends and any change in US SPR release policy.
• The persistence of diesel-led crack spreads and disruption to Russian refining assets.
• Developments in the US-Iran and Russia-Ukraine conflicts.
• Whether 2027 EBITDA estimates continue to rise and whether shareholder cash returns support valuations.