Energy: A Multi-million-dollar Blind Spot on the Corporate Balance Sheet

The same energy procurement strategies that produced a $15 million cost variation in two nearly identical contracts four years ago continue to be implemented for most corporate portfolios today.

Three fundamental shifts are shaping today's corporate energy purchasing decisions in the U.S.:

1. U.S. power and gas markets have structurally repriced: AI data center construction, new liquefied natural gas (LNG) export terminals, manufacturing reshoring, and electrification are all driving sustained demand growth, while power plant delays, equipment shortages, and pipeline constraints limit the system's ability to absorb it.
2. Traditional procurement strategies now leave both dollars and controls exposed: Auto-renewing at contract expiration or locking in during a rally were defensible decisions in a stable market. In a market where volatility cycles run twice as often and last half as long as cycles before 2022, a standard energy hedging approach creates multi-year balance-sheet exposure that most organizations have not quantified yet.
3. A shift from passive procurement to active market positioning: The discipline finance teams apply to FX, interest rate, and commodity exposure is the same discipline that energy procurement now requires. Continuous monitoring, scenario-based sizing, regional pattern identification, and building a market view independent of the renewal calendar are essential tools to adapt to today's volatile power and gas markets.

Energy Markets Enter a New Era of Demand Growth and Volatility

Traditional energy procurement approaches, such as auto-renewal and fixed-price hedges worked when U.S. electricity demand grew predictably, natural gas production was booming and regions had similar consumption patterns and fuel mix. With stable market conditions, forward power and gas prices barely drifted between contract signing and delivery. A 12-to-36-month hedge locked automatically at contract renewal rarely meant overpaying, while also covering budgets against weather and most other unforeseen risks.

That assumption no longer holds. A multi-year hedge signed during a market rally can quickly be the most expensive mistake in corporate energy procurement in today's volatile environment. This kind of exposure warrants a higher level of internal controls and financial oversight in light of the structural forces reshaping prices. Demand growth, infrastructure constraints, weather patterns and fuel mix also vary widely by U.S. region, placing greater importance on managing the financial risk.

Three recent energy market drivers demonstrate the need for a new procurement approach:

1. Regional demand growth for power and gas from the AI data center boom, new LNG terminals, manufacturing facilities, and electrification puts sustained upward pressure on energy prices.
2. Infrastructure bottlenecks due to long connection timelines for power plants, critical equipment shortages, and gas pipeline and power line constraints leave limited capacity for the system to absorb new demand. The price paid by consumers for capacity charges—the portion of the bill grids charge to keep generation on standby— has risen by more than 800% in some major regions as a result of these bottlenecks.
3. Geopolitical supply shocks drive fear-led rallies in global energy markets. Buyers often contract at or near the peak because they tend to price the worst-case supply loss in full but underestimate how fast markets can re-balance.

Figure 1: Historical and Forecasted Annual U.S. Electricity Demand Growth

Companies Must Treat Power and Gas the Way Finance Treats FX

An energy procurement strategy that ignores regional differences will misprice the risk across the entire portfolio. The approach that protects a buyer in California or Texas can leave the same company exposed in New England. Still, most companies pursue two procurement strategies designed for stable and uniform market conditions:

1. Set-it-and-forget-it strategy: auto-renew at contract expiration, take the fixed price, declare the budget protected. The renewal calendar sets the signing date, and during rallies, that can mean locking in peak market prices the market is about to correct.
2. Panic-driven procurement: lock in prices at the first sign of market turmoil, often when an advisor's incentive is to close the contract, not to manage the long-dated exposure. Many rallies that prompt a panic-signed contract unwind by the time the contract is a few months old.

Both approaches leave the signing decision to the calendar or the market. A better approach replaces the calendar with a market view that is built on continuous indicator tracking. This strategy requires the same discipline that Finance teams apply to FX, interest rates and other market exposures:

1. Run a continuous cost-at-risk view on power and gas by tracking forwards against fundamentals and historical bands, following a similar logic that finance teams apply to FX or commodity exposure.
2. Distinguish structural drivers in procurement decisions, such as weather trends, realized demand growth, or natural gas inventory flows, from headline noise such as new data center announcements.
3. Maintain operational flexibility to act on corrections, and the discipline to hold through price rallies when the market is still pricing on incomplete information.

U.S. power and gas markets have grown more volatile since 2022, changing how to plan and time procurement decisions. Shorter volatility cycles, occurring twice as often since 2022, call for close market monitoring. Patience and procurement flexibility have become more critical in a market environment where corrections now tend to come within weeks rather than months before 2022.

Figure 2: Number of Yearly Volatility Cycles in Power, Gas and Crude Oil Markets, 2018-2021 vs 2022-2026

Case Study: Geopolitical Price Rallies Undermine Demand Elasticity to Create Million-Dollar Exposures

An energy buyer in the U.S. Northeast locking in 100,000 MWh on a 12-month forward in late 2022 paid roughly $20 million. The same contract cleared at $5 million a few months later.

Russia's invasion of Ukraine in early 2022 cut the bulk of Russian gas supply to Europe heading into the 2022/23 winter season. Gas and power markets rallied, fearing a severe global gas shortage. In Boston and New York City, 12-month forward power prices climbed past $200/MWh as a result, up from just $30/MWh during the same period a year earlier. Forwards exceeded $130/MWh even in PJM West, the zone with the largest U.S. grid adjacent to a major natural gas hub.

Within a few months, U.S. LNG export growth, new energy efficiency measures in Europe that reduced demand for power and gas, and a mild European winter pulled forwards back to $40-50/MWh, where they stayed through the next winter even as Europe continued cutting Russian gas.

Figure 3: Front-year Rolling Power Forward Prices for the Boston Area

A similar supply shock is active today. Ongoing conflict in the Middle East has taken roughly 20% of global LNG supply off the market, but U.S. forwards have not reacted yet. Spring demand has been mild and Europe has not started refilling their gas inventories ahead of the winter.

Buyers tracking the right fundamentals, such as global LNG export volumes, weather patterns, European gas storage levels, and demand destruction in importing nations, will likely be in a better position to spot pricing risk before a sustained rally.

Case Study: Near-term Relief Can Cause Markets to Underprice Structural Signals

ERCOT near-term forwards carried a reliability premium entering 2026, priced on the assumption that data center load growth would soon push the grid past its reliability margin. Winter Storm Fern arrived in late January 2026, and the grid held without major outages. The system had strengthened since widespread outages from 2021 during Winter Storm Uri.

Following the grid's performance during Fern, August 2026 and 2027 forwards fell 20–30% in the following weeks. The market has since held the lower price levels, including for longer-dated contracts. Prices have held even after ERCOT, the grid operator, reported more than 400 GW of data center capacity in the interconnection queue, nearly five times the current system peak.

Discounting the full data center pipeline is likely reasonable because most of those requests are speculative. But the market also risks underpricing the roughly 50 GW of data center load that is nearly contracted to come online, enough to raise system peak demand by over 50% in the next few years. Front-year summer forwards in Texas currently trade at about a third of the 2019-2023 highs, when the market was still pricing weather risk rather than demand growth. Buyers that locked in summer Texas power above $130/MWh in late 2025 are now sitting above market with no way to participate in any further softening.

Three CFO Questions That Separate a Strategy from a Renewal

The instinct to lock in a fixed price during a rally can be very expensive in today's market, where full volatility cycles now resolve in roughly 30 days. The contract signed at the height of the cycle is rarely one that a company would sign two months later with the same information.

The alternative is not perfect timing. Rather, it is a continuous process of monitoring cost-at-risk, layering entry positions across the price curve, and securing pre-agreed procurement flexibility to act on corrections rather than being forced to react to rallies. Three questions finance and energy teams should answer to determine whether that process exists today:

• What is our cost-at-risk on power and gas over the next 24 months, in dollars?
• When did we last re-evaluate our hedge ratio against current forwards?
• If forwards correct 20% in the next 60 days, do we have the authority to act, or does our renewal calendar?

The risk in this market is not under-hedging. It is locking in prices that look like a mistake in just a few months.

CBRE Energy advises Fortune 500 finance and energy teams, managing billions in annual power and gas spend on their behalf.

Appendix: Energy Market Volatility Drivers: Rallies & Correction Forces