Opinion | Data centers don’t have to drive up electricity bills for everyone else

33%: New Jersey declared a state of emergency after power prices rose ~33% since June 2023, freezing rate hikes and ordering faster interconnection of utility-scale solar and battery storage. Policymakers nationwide — including Illinois (Gov. Pritzker proposing a two-year moratorium on data center tax incentives after lifting an ~40-year nuclear moratorium), Sen. Sanders (nationwide pause), Florida (regulatory proposals), and local Minnesota moratoria — are moving to restrict data center approvals as AI and cloud demand drive a surge in electricity use that could require billions in new generation, transmission and substations.

Analysis

Localized grid strain from concentrated compute growth creates a multi-year arbitrage: near-term scarcity (12–36 months) of interconnection capacity and substations forces a premium on projects with ready transmission or behind-the-meter generation, while longer lead-times (3–7 years) for new high‑voltage lines reprice geography. That premium will show up as higher effective build cost per MW — think incremental connection and upgrade bills in the tens to low hundreds of thousands $/MW for many sites — shifting returns away from brownfield land plays toward vertically integrated suppliers of generation, storage and grid equipment.

Second-order winners are firms that monetize the “last mile” of capacity: battery integrators that can deliver services (frequency, capacity, black start) and fast-track connections via front-of-meter contracts, and equipment suppliers that sell substations, switchgear and microgrid stacks. Conversely, developers and colo landlords exposed to single-state pipelines face permit and rate backlash that can crystallize as months-long queue delays and meaningful IRR erosion; their options to self-build (PPAs + storage) raise capex and lower ROIC.

Policy is the key swing factor: a flurry of moratoria and state-level incentives can compress returns quickly, but federal or utility-level capacity programs (capacity markets, accelerated rate-base treatment) would reverse the pain within 6–24 months. A contrarian tail: rapid model-efficiency gains (model distillation, on-device inference) could cut marginal compute demand 10–30% over several years, capping the long-term upside for all infra players even as near-term grid scarcity persists.

Key Decisions for Investors

• Long AES (AES) — 12–24 month horizon. Initiate a 2–3% portfolio weight in shares or 2027 calls; thesis: storage & integrated solutions win most near-term interconnection auctions. Risk/Reward: +40% upside if storage adoption accelerates and utilities secure rate recovery; downside ~20% on project delays or negative power prices.
• Long Eaton (ETN) or ABB ADR (ABB) — 6–18 months. Buy ETN (preferred US exposure) to play substation and switchgear capex with expected multi-year procurement cycles. Risk/Reward: +25–35% if states accelerate upgrades; downside ~15% if utilities defer spending due to permitting freezes.
• Short / hedge regional colo exposure — Digital Realty (DLR) and Equinix (EQIX) selective puts for 6–12 months. Target markets with active moratoria; buy 3–6 month puts (2.5–5% OTM) or establish small short positions. Risk/Reward: asymmetric — small premium cost (~2–4% of notional) for >10–20% downside if permit pipelines stall; risk of rebound if providers pivot to self-supply with PPAs.
• Pair trade: long First Solar (FSLR) / short a regional developer land play — 12–24 months. Long utility-scale solar names capture PPA demand as projects become the cheapest route to on-site carbon-free power; short speculative development exposures where interconnection risk is binary. Risk/Reward: FSLR +25–40% if PPAs accelerate; short leg provides downside buffer of 10–20% if moratoria are temporary.