The Enernova Insights

Following this weekend’s U.S. strike on Iranian targets, we've received a wave of questions from clients about what this could mean for energy markets.

The biggest driver of future electricity prices won’t be the weather it’ll be whether the system can deliver power at all. We’re seeing a growing mismatch between energy demand and the capacity of the grid, supply chain, and labor force to support it.

Most commercial electricity customers in ComEd are already exposed to market price risk—even when they’re on a fixed-price contract.

The power grid serving over 65 million people across the Midwest and East Coast (PJM) is entering a period of tighter operating margins.

Beginning June 2025, PJM capacity prices will reflect a nearly 900% increase — a dramatic market shift that will now be largely locked in through May 2028.

New England pays some of the highest electricity and natural gas prices in the U.S.—not because of its distance from supply, but because it’s effectively cut off from it.

The natural gas market is shifting due to rising demand, LNG exports, and producer discipline, impacting prices, electricity costs, and infrastructure. While policy may affect supply, market fundamentals drive pricing trends. This analysis examines the key forces shaping the future.

The "Natural Gas Demand Growth by 2030" chart outlines three potential growth scenarios—Low, Medium, and High—each driven by varying levels of LNG exports, power sector demand, and pipeline exports to Mexico.

At EnerNova, we empower businesses with smarter energy risk management. Watch our story to see how we help companies navigate the complexities of the energy market, optimize costs, and plan for a more sustainable future.