2 Energy Stocks to Buy in April

Oil rose >75% in Q1 and the average S&P 500 energy stock jumped >35%, but the Iran war creates material price uncertainty. Energy Transfer: units +15% YTD (MLP +3% over 12 months), ~7% distribution yield, ~90% fee‑based earnings, and secured expansion projects supporting 3–5% annual distribution growth. Oneok: shares +20% YTD (‑~10% over 12 months), ~4.7% dividend yield, 85–90% fee‑based earnings in 2026, plus acquisitions and projects driving 3–4% annual dividend growth to mid‑2028; both are pitched as lower‑risk, fee‑based midstream plays resilient to crude price swings.

Analysis

Pipelines with fee-based contracts (ET, OKE) are behaving like quasi-utilities: they de-risk commodity-price volatility but remain levered to producer activity. That creates an asymmetric payoff this cycle — a short-term oil spike (weeks–months) lifts sentiment and may increase incremental throughput fees; a rapid peace-led price collapse would remove upside for E&Ps but only modestly reduce contracted fee income over 6–18 months, not immediately forcing distribution cuts.

Second-order beneficiaries include fractionators, storage and rail terminals that sit downstream of gas/NGL flows; rising NGL spreads can materially lift fractionation yields and incentive tariffs late in 2026 and into 2027 as new petrochemical demand recovers. Key fragility is financing and execution: legacy MLPs still face refinancing needs for secured growth projects 2026–2029, so rising rates or execution delays can compress distributable cash despite stable tolling economics.

Tail risks are fast and binary: a ceasefire within 30–90 days could knock Brent 20–35% and expose over-allocated thematic energy longs. Conversely, sustained regional escalation keeping Brent >$95 for multiple quarters would accelerate volumes and fee escalators, making 12–36 month growth guidance conservative. Watch covenant triggers and upcoming debt maturities (mid-2020s), and treat pipeline equity as a duration asset sensitive to discount-rate moves as much as volume changes.

Consensus underestimates optionality from secured, long-dated contracts and the timing mismatch between near-term oil-price moves and multi-year contraction/expansion capex cycles. That suggests a barbell: capture current yield and locked-in project IRR while hedging short-dated directional oil risk — the mispricing is in time-structure, not headline commodity exposure.

Key Decisions for Investors

• Go long Energy Transfer (ET) units — 2–4% portfolio weight, horizon 12–24 months. Target total return 15–25% (7% distribution + 8–18% price appreciation) if projects execute; set tactical stop-loss at -18% and reassess on any distribution coverage <1.1x or announcement of >6 month project delay.
• Pair trade: long ET / short XOP (or short a high-beta E&P such as PXD) — equal notional, horizon 3–9 months. Rationale: capture stability-of-fees vs commodity beta; expect pair to net 8–15% if oil mean-reverts down 15–30% while fee streams hold. Risk: sustained rally in oil and volumes; cap position sizing to 1–2% NAV.
• Income buy OKE — 1–3% portfolio weight, hold 18–36 months. Accept lower upside vs ET for cleaner equity (no K-1) and predictable 3–4% dividend growth. Risk-managed by monitoring debt maturities and initiating protective puts if OKE falls >12% or distributable cash trends downward two consecutive quarters.
• Short-dated oil downside hedge: buy 3-month Brent/WTI puts (or USO puts) equal to 1–2% portfolio cost if geopolitical headlines suggest de-escalation probability >30% in the next 60 days. This protects the income positions from a rapid price shock that would pressure sentiment and E&P activity, while leaving longer-dated growth optionality intact.