The Big Picture
Utilities investors woke to a mixed set of developments on Jan. 15: major project deals and new capacity are pushing the sector forward, but rising construction input costs and a near-term slowdown in wind additions temper the outlook.
Large financings, a 50-MW battery going online at a former coal site, and a 1,425-MW combined-cycle EPC award underscore ongoing capital deployment for reliability and electrification. At the same time, tariff-driven input-price inflation and a Wood Mackenzie forecast for a 6% decline in global wind additions in 2026 highlight tangible near-term risks for build costs and renewable supply chains.
Market Highlights
- Grid outlook: PJM trimmed near-term peak-demand projections in its 2026 Long-Term Load Forecast but reaffirmed steep long-term growth driven by data centers and electrification.
- Storage online: Duke Energy ($DUK) commissioned a 50-MW battery at the former Allen coal plant, a roughly $100 million project serving NC and SC customers.
- Major financing: Apex Clean Energy closed $2.79 billion to finance three utility-scale renewable projects across Texas, Ohio and Illinois.
- Big gas build: Oglethorpe Power selected Kiewit as EPC for a 1,425-MW combined-cycle plant, a roughly $2 billion project targeting operation by 2029.
- Input costs: PPI shows switchgear and controls up 11.1% year/year, copper wire and cable up 11.7%, while unprocessed energy materials were down 4.9%, signaling higher construction costs for some equipment categories.
- Wind outlook: Wood Mackenzie forecasts a 6% decline in global wind additions in 2026, driven by a slowdown in China and US policy headwinds.
Key Developments
PJM load forecast: Near-term trim, long-term growth intact
PJM’s updated 20-year load forecast lowered near-term peak-demand expectations after tighter vetting of large-load adjustments and revised EV and economic assumptions. Crucially, PJM still projects significant long-term demand growth tied to data centers and electrification, reinforcing the need for grid capacity and firming resources over the next decade.
Implication: Investors should view PJM’s adjustment as a timing shift rather than a structural slowdown, it supports demand for transmission upgrades, storage and dispatchable capacity, but could compress near-term project timelines and revenue ramp assumptions for some developers.
Storage, renewables and financing show execution continues
$DUK brought a 50-MW, ~$100M battery online at the Allen coal site, demonstrating utilities' push to redeploy legacy fossil sites for storage. Apex Clean Energy’s $2.79 billion financing for three projects across Texas, Ohio and Illinois signals strong capital availability for utility-scale renewables.
Implication: Project finance and brownfield repowering are active, which favors developers and utilities able to secure capital and interconnection. Retail investors should watch which public utilities or developer partners win offtake or tax-equity roles on these financed projects.
Large-scale thermal and AI-driven demand reshape resource mixes
Oglethorpe Power’s selection of Kiewit for a 1,425-MW, $2 billion combined-cycle build (target 2029) and the planned conversion of a California biomass plant into a 41-MW carbon-negative AI factory show divergent responses to rising demand: big gas for firming and niche carbon-negative assets for AI workloads.
Implication: The market for “AI-grade” megawatts is prompting hybrid portfolios, gas for firmness, renewables for cost/optics, storage for stability, which will favor integrated players that can offer bundled capacity, energy and flexibility services.
What to Watch
Policy and tariffs: Monitor any new tariff actions or trade rulings that could push equipment costs higher or extend delivery lead times for turbines, transformers and cabling.
PJM and ISO signals: Track follow-up filings and market reform discussions from PJM and other ISOs about capacity construct, interconnection reform and incentives for firm low-carbon resources, these will shape project economics and developer returns.
Project timelines and off-take: Watch financial close and offtake announcements tied to Apex’s financed projects and developer announcements at POWERGEN for clues on where capital is flowing and which utilities or corporates are signing long-term contracts.
Construction and commodity costs: Keep an eye on PPI updates and vendor lead-time notices for switchgear, copper and controls; sustained price pressure could erode project margins or delay builds.
Bottom Line
- Long-term structural demand (data centers, EVs, electrification) remains a tailwind, but timing has shifted in some ISOs.
- Capital is available: large financings and brownfield storage builds show continued investor appetite for utility-scale projects.
- Cost risks are real: tariffs and input-price inflation (switchgear +11.1%, copper +11.7%) could squeeze margins and slow deployment.
- Hybrid resource strategies (gas + renewables + storage) are emerging as the likely winner for AI and reliability-driven demand.
- Action for investors: favor companies with diversified portfolios, secured offtakes/financing, and explicit plans to manage supply-chain cost pressure.
FAQ Section
Q: How does PJM’s trimmed near-term forecast affect utilities? A: It mainly shifts timing for some capacity needs; utilities should still plan for long-term electrification-driven load growth but may face slower near-term demand ramp.
Q: Are input-cost increases likely to derail renewable builds? A: They raise project costs and could delay timelines, but large financings and continued developer activity indicate many projects remain viable if sponsors secure supply and financing.
Q: Should investors prefer gas or renewables given current headlines? A: A selective approach is best, gas provides near-term firmness and capacity returns, while renewables plus storage offer long-term growth; look for firms that can integrate both and control build costs.