Hess Midstream: The Issue Continues To Be The Bakken Upstream Business

Bakken production is confirmed flat at 200,000 BOED by HESM and Chevron, with the rig count down to three. Hess Midstream's core Bakken acreage is high-cost and unprofitable, constraining growth and limiting the company's outlook; recent dividend increases are likely a short-term distraction rather than evidence of improving fundamentals.

Analysis

The core issue is a persistent negative wedge between Bakken unit economics and corporate WACC that forces marginal barrels to be volume- and capital-constrained — this turns midstream receipts into an option on third-party capex decisions rather than on commodity prices alone. Expect realized midstream throughput and fee inflation to decouple from headline oil moves: a $10/bbl oil rally that improves E&P cashflow may still leave high-per-unit Bakken breakevens uncompetitive versus Permian returns, so volumes recover only slowly and unevenly over 6–24 months.

Second-order beneficiaries are assets and companies exposed to lower per-unit extraction costs or contracted fee-for-service structures (Permian midstream, takeaway-constrained pipelines that capture basis). Conversely, firms with high fixed-cost gathering networks in decline-prone basins will see leverage to utilization declines, inflation in per-unit O&M, and credit metric erosion; this compresses multiple expansion even if distributable cash flow is stabilized. Expect counterparties (E&P operators) to re-price long-term take-or-pay and acreage dedications, accelerating renegotiations within 3–9 months.

Key catalysts that would reverse the negative trajectory are structural: (1) sustained WTI > $85–90 for multiple quarters that makes Bakken returns competitive enough to restart rigs, (2) a meaningful reduction (15–25%) in well costs or improvement in EURs from completion innovation, or (3) sale/restructuring that converts fee exposure to fixed-fee contracts. Near-term downside is driven by further capital rotation away from high-cost basins and any credit-rating action that forces distribution cuts — both can occur inside a single earnings cycle (90–180 days).

Key Decisions for Investors

• Short HESM equity sized 2–4% of portfolio with a 6–12 month horizon — target 30% downside vs current levels with a stop-loss at +20% adverse move. Rationale: asymmetric exposure to utilization decline and re-contracting risk; add if quarterly guidance shows continued volume downgrades.
• Buy HESM 6–9 month put spread to define risk: pay premium for downside to capture 25–35% move, with max loss = premium and max gain equal to spread width less premium (target 3:1 reward-to-risk). Use this if you prefer defined option risk over outright short exposure; unwind if oil prices sustain above $85 for two consecutive months.
• Pair trade: short HESM / long EPD (or PAA) equal notional for 3–12 months — expect 20–30% relative underperformance as Permian throughput and fee structures re-rate higher. Risk: systemic shale recovery lifts both; cap pair exposure to 3% of NAV and hedge with a crude futures collar if oil > $80 triggers reversion.
• Event hedge: buy CVX (size 1–2% tactical) on any meaningful rotation into majors after HESM weakness, holding 3–9 months — low correlation to Bakken-specific execution risk and provides defensive upside if capital shifts back to integrated producers. Take profits if macro energy ETF flows reverse or CVX underperforms sector by >8%.