What If Utilities Just Made Less Money?

California's Public Utilities Commission is considering requests from the state's four largest investor-owned utilities to raise allowed returns on equity (ROE) even as consumer advocates and analysts push for cuts amid record utility profits and an affordability crisis. Academic and industry analyses cited in the proceeding show utility ROE risk premia rose from roughly 3% to nearly 8% since the 1990s, and ex-utility economist Mark Ellis estimates excessive ROEs cost U.S. customers ~$50 billion/year (>$300/household) and proposes lowering average ROE from about 10% to 6% — a change he says could save California customers >$6 billion/year. Utilities warn lower ROEs would trigger credit downgrades, higher borrowing costs and reduced investment capacity; the commission issued a preliminary decision to reduce ROEs by 0.35% and a final ruling is expected in December.

Analysis

Market structure: A meaningful ROE compression in California (plausible band: -100 to -400 bps from ~10%) is a direct negative for investor‑owned utilities with high CA exposure (PG&E/PCG, Edison/EIX, Sempra/SRE) and for equipment vendors tied to utility capex. Winners: ratepayers, public/municipal utilities, independent power producers (merchant renewables) and software/grid‑optimization vendors if IOU capex slows and market solutions pick up slack. Cross‑asset: expect utility equity multiples to compress 5–20%, IG utility credit spreads to widen 50–200 bps (esp. wildfire‑exposed issuers), and options IV on CA utilities to spike into Dec CPUC decision; commodity impact is second order but slower interconnection can keep power prices elevated regionally.

Risk assessment: Tail risks include a sweeping ROE cut (>200 bps) triggering one‑to‑two notch downgrades, forced asset sales, or state takeover talk — each could cause >30% stock downside for the worst‑exposed names. Immediate (days): headline sensitivity to CPUC filings and testimony; short (weeks/months): December CPUC decision is the primary catalyst; long (quarters/years): sustained lower returns leading to 5–15% lower cumulated capex and delayed grid modernization. Hidden dependencies: rating agency reaction thresholds (e.g., S&P/Baa2 moves), interlink between ROE precedent across states, and utilities’ ability to retain earnings instead of issuing equity.

Trade implications: Direct short candidates: PCG and EIX — initiate 1–3% notional short positions staggered 1–3 weeks ahead of the Dec CPUC decision; scale to 3–6% if ROE cut >100 bps. Pair trade: long NextEra (NEE) or broader renewable IPPs (2–4% long) vs short EIX (2–3%) to capture regulatory dispersion and merchant upside. Options: buy 6–12 month puts (10–20% OTM) on PCG/EIX to asymmetrically hedge tail risk; consider buying straddles around the Dec decision if IV is <market shock implied (~25–35%). Reduce XLU overweight by 50% and reallocate to NEE and grid software/ESS suppliers (names with global, less regulatory‑tied revenue).

Contrarian angles: Consensus understates utility adaptability — IOUs can dramatically cut dividends/retain earnings to fund capex, muting equity issuance risk and limiting credit stress; that argues for selective, not blanket, shorts. The market may overprice systemic contagion: expect idiosyncratic dispersion — wildfire‑tainted PCG may underperform but diversified SRE could rerate slower or even outperform if management preserves cash. Historical precedent (UK regulatory resets) shows initial price falls then stabilization; watch CPUC final text and rating agency commentaries as the true re‑pricing triggers.

Key Decisions for Investors

• Establish a staggered short position in EIX and PCG totaling 2–4% portfolio notional: initiate 0.5–1% positions each week over the next 2–3 weeks, increase to 3–4% if CPUC issues ROE reduction >100 bps in December.
• Set up a long/short pair: long 2–3% NextEra Energy (NEE) or a renewable IPP ETF and short 2–3% Edison International (EIX) to capture regulatory dispersion; rebalance if relative spread moves >10%.
• Buy 6–12 month puts on PCG and EIX (10–20% OTM) sized to cover 50–75% of the short position notional to cap downside and profit from IV spikes around the Dec CPUC decision.
• Reduce XLU ETF exposure by 50% within 2 weeks and reallocate proceeds (1–3% portfolio) to grid software/ESS suppliers and NEE to hedge slower IOU capex and benefit from merchant price upside.
• Trigger monitoring rule: if S&P/Fitch places a California IOU on negative watch or if credit spreads widen >100 bps vs. IG utility index, increase shorts in that issuer by +50% within 48 hours.