$8T+ Oil & Gas market. Goldman sees $115 crude. When prices rise, cash flow explodes across the energy stack. Here’s who wins 👇

Oil demand >104M bpd. Gas >4.2T m³. Supply stays tight while LNG demand grows. Goldman’s near-term price targets show how sensitive the system is to disruption.

Higher prices don’t just lift revenues → they expand margins, cash flow, and shareholder returns fast.

$XOM Exxon Produces ~4.7M boe/d, highest in decades, with advantaged barrels from Guyana and Permian. Breakevens sit far below global benchmarks. Every $10 move in Brent flows directly into incremental upstream cash. Downstream + chemicals smooth cycles, but upside is driven by volume growth from low-cost assets. Massive buyback capacity stays intact even at mid-cycle prices, meaning higher oil accelerates capital returns without requiring more capex.

$CVX Chevron Permian + deepwater Gulf anchor the portfolio. Production growth offsets weaker pricing, showing strong operating leverage. Capital program already built for mid-cycle oil. When crude rises, incremental cash isn’t reinvested aggressively — it flows to dividends and buybacks. Integration of recent assets adds scale without bloating costs. High-margin barrels + disciplined spending create a clean pathway for price upside to convert into shareholder returns.

$SHEL Shell Global LNG + trading engine layered on upstream. Cash flow stays strong even in weaker price environments due to portfolio flexibility. LNG exposure captures regional gas premiums, while trading desks monetize volatility across oil and products. Higher oil and gas prices amplify an already efficient system. Instead of chasing megaprojects, capital gets redirected to buybacks and dividends, making price upside directly visible in per-share returns.

$BP BP Portfolio still heavily tied to upstream projects, with refining and energy transition investments layered in. Impairments masked underlying strength, but operating cash flow remains solid. Higher oil improves project economics and reduces funding pressure for transition spending. Strategy reset increases oil sensitivity versus peers. Rising crude prices compress valuation discount as free cash flow expands and balance sheet improves.

$TTE TotalEnergies Blends upstream growth with LNG and refining strength. Production rose ~3.9%, while refining margins surged >30% in late 2025. Multiple earnings engines activate when prices rise: liquids, gas, and downstream spreads. LNG portfolio adds global optionality. Higher oil doesn’t just lift earnings — it multiplies cash flow across segments, supporting aggressive buybacks while funding expansion into power markets.

$EQNR Equinor European gas exposure drives the story. Realized gas prices ~10.6/mmbtu highlight premium positioning. Pipeline + LNG flows into Europe capture structural scarcity. Liquids add secondary upside, but gas dominates margins. Higher global energy prices reinforce already elevated European benchmarks. Strong pricing environment translates into high returns on capital and sustained shareholder payouts.

$CNQ Canadian Natural ~1.45M boe/d anchored by oil sands mining, thermal, and heavy oil with utilization near 100%. Operating costs sit around $23/bbl, among the lowest for oil sands globally. Decline rates are minimal. Infrastructure already built. Incremental barrels carry very high margins once facilities are online. Higher Brent doesn’t require more drilling — it expands margins on existing production. Free cash flow scales fast, supporting dividends, buybacks, and steady output without capex growth.

$CVE Cenovus ~725k bpd oil sands production paired with ~465k bpd refining throughput running at ~98% utilization. Integrated structure captures both upstream and downstream economics. Higher crude widens upstream margins while refining benefits from stronger product pricing and improved crack spreads. Oil sands growth continues alongside better downstream performance. Export capacity expansion reduces bottlenecks. Cash flow grows from both production and refining leverage when global oil prices rise.

$COP ConocoPhillips ~19.9B operating cash flow with exposure across Permian, Eagle Ford, Bakken, Alaska, and LNG-linked assets. Portfolio built around low-cost supply with flexible capital allocation. About 45% of operating cash returned to shareholders. Cost discipline remains central. Higher oil prices don’t trigger aggressive production growth. Incremental dollars flow directly into free cash flow. Large inventory of advantaged barrels magnifies price sensitivity, creating strong upside in sustained higher price environments.

$DVN Devon ~851k boe/d anchored in Delaware and Anadarko. Capital program calibrated for flat-to-low growth, keeping reinvestment needs contained. Q4 operating cash flow reached ~$1.5B while volumes held steady. Variable dividend model sits on top of base payout. Higher oil prices don’t trigger aggressive drilling. Incremental price moves flow directly into free cash flow. Liquids-heavy mix increases sensitivity to WTI. Cash returns scale quickly as price rises.

$OXY Occidental ~1.44M boe/d with strong Permian weighting and improving cost structure. Domestic operating expenses reached the lowest level since 2021 while capex came in ~$300M below plan. Production exceeded guidance, reinforcing efficiency gains. Chemicals and international assets add stability, but core torque sits in Permian oil. Higher crude prices accelerate free cash flow expansion. Debt reduction speeds up, unlocking additional buyback capacity.

$EOG EOG ~5.5B boe reserves across Delaware, Eagle Ford, and Powder River. Cost reductions of ~7% combined with disciplined drilling enhance margins. ~13% production growth paired with ~19% ROCE highlights efficiency. Capital allocation prioritizes full cash return to shareholders. Higher oil prices immediately expand free cash flow without requiring higher spend. Premium acreage and execution convert price upside directly into returns.

$FANG Diamondback ~513k bpd oil output and ~969k boe/d total production concentrated in the Permian. Generated ~$2.3B operating cash flow with sub-$1B capex, even at ~$58 realized oil. Long laterals and low-cost inventory drive strong well economics. Higher oil prices significantly increase free cash flow per share. Variable dividends scale quickly. Capital discipline keeps reinvestment low, maximizing price leverage.

$PR Permian Resources Delaware Basin-focused mid-cap with strong operational execution. Q4 EPS of ~$0.37 beat expectations despite weaker pricing, driven by higher-than-planned volumes. Drilling program emphasizes efficiency and steady growth. Operating leverage is high. Earnings expand faster than production when oil rises. Capital returns remain balanced with growth. Strong sensitivity to price upside in a sustained higher oil environment.

$EXE Expand Energy Largest independent US gas producer with assets tied to LNG export corridors. ~$4.6B operating cash flow reflects scale post-merger integration. Drilling activity calibrated for stability rather than aggressive growth. Balance sheet repair is a priority. Rising Henry Hub prices toward ~$5/mmbtu expand free cash flow quickly. LNG demand strengthens pricing backdrop. Incremental gains flow into debt reduction and shareholder returns.

$CTRA Coterra ~750–810k boe/d combining Marcellus gas with Permian oil exposure. Delaware Basin integration improved cost structure and midstream terms. Portfolio balances gas and liquids. Higher oil prices lift Permian returns, while stronger gas prices boost Appalachia cash flow. Dual exposure increases resilience. Free cash flow expands from both commodities without requiring major capex increases.

$EQT EQT Leading Appalachian gas producer with one of the lowest cost structures in US dry gas. Production tied into major takeaway infrastructure including Mountain Valley Pipeline. Capex remains below budget while output continues to outperform. Pipeline stakes provide steady cash flow streams. Rising gas prices drive significant free cash flow expansion. Margin strength improves as pricing moves above hedge levels.

$LNG Cheniere Exported ~670 cargoes totaling over 46M tons in 2025. Operates at the center of US LNG flows, linking domestic gas to global pricing. Stage 3 expansion increases capacity and flexibility. Mix of long-term contracts and spot cargoes captures volatility. Higher global gas prices widen spreads versus Henry Hub. Margins expand as international demand strengthens.

$AR Antero Appalachian producer with strong exposure to NGLs like propane and butane. LPG export capacity expanded through 2028, removing key constraints. Storage shifted from surplus to deficit entering 2026, tightening balances. Liquids pricing benefits from higher oil benchmarks. Gas exposure adds additional upside as Henry Hub strengthens. Dual commodity leverage drives strong cash flow expansion.