Trump’s Push for More AI Data Centers Faces Backlash From His Own Voters

Talen Energy is seeking to rezone roughly 1,300 acres in Montour County, Pennsylvania to build a 12–15 building data center on about 350 acres adjacent to its 1,528 MW gas-fired plant, provoking bipartisan local opposition and a 6-1 county planning commission recommendation against rezoning. The clash highlights growing political and regulatory risk for AI-related data center buildouts—Data Center Watch says roughly $64 billion of projects have been blocked or delayed—and comes as PJM projects sharp electricity demand increases and Pennsylvania saw retail electricity prices rise about 15% year-over-year. Investors should weigh increased permitting and political risk to hyperscale data-center developers and potential upward pressure on utilities’ rates and capacity costs that could affect utility earnings and regional infrastructure investment timelines.

Analysis

Market structure: Local rezoning fights create a bifurcation: regulated generators and grid owners (e.g., CEG) gain pricing power from constrained supply while land-constrained developers (TLN) and regional service contractors face execution risk. Expect upward pressure on PJM capacity and retail electricity (+15% Y/Y seen) to persist near-term; a 10–30% re-rating in regional utility EBITDA is plausible if data-center demand materializes and rate cases pass over 12–24 months.

Risk assessment: Tail risks include federal preemption being struck down by courts or local zoning moratoria cascading across states, which could cancel $10s of billions in projects and slam developer equity; conversely, a federal fast-track could rapidly accelerate builds and capex cycles. Key horizons: near-term county decisions (mid-Dec) and 30–90 day permitting filings; medium-term grid interconnection queues (6–18 months); long-term structural demand for AI capacity (2–5 years).

Trade implications: Tactical: favor regulated utility exposure (CEG) and grid services; avoid or hedge regional developers (TLN). Use options to express asymmetric views: buy 6–12 month CEG call spreads and 3-month TLN puts ahead of the mid-Dec vote. Rotate 3–6% of cyclical/real-estate exposure into power-equipment and transmission names to capture capex and scarcity rents.

Contrarian angles: The market underestimates hyperscalers’ relocation optionality — AMZN/GOOGL/MSFT can reallocate capex, so long-term core tech is not structurally impaired; short-term pain is concentrated in small regional names. Historical precedents (pipeline/NIMBY fights) show delays raise execution risk but rarely stop secular growth; prefer hedged, event-driven shorts over blanket bets.

Key Decisions for Investors

• Establish a 2–3% long position in CEG (Constellation Energy) with a 6–12 month horizon; consider target +20–35% if PJM capacity prices rise further or if utility rate cases allow cost recovery. Trim on a 15–20% rally.
• Initiate a 1–2% short (or buy 3-month puts 10–20% OTM) on TLN ahead of the mid-December county vote; unwind within 2 weeks of the ruling or if rezoning advances. Size small due to binary local outcomes.
• Construct a pair trade: long CEG (+2%) vs short TLN (-1%) to capture regulatory/regional execution dispersion over 3–12 months; hedge with sector ETF put if broader risk-off emerges.
• Buy a 6–12 month CEG call spread (bullish, limited cost) and fund with selling 1–3 month covered calls on regional real-estate/developer names; reassess after Q1 2026 capacity auction results.
• Reduce direct exposure to small-cap data-center developers by 50% in portfolios overweight to rural buildouts; redeploy proceeds into regulated utilities and transmission equipment suppliers, adding on any >5% pullback.