Energy has always been a line item. But in 2026, it's become an unpredictable one — and that unpredictability is the problem.
Facility managers responsible for multi-site portfolios are navigating a market shaped by extreme weather events, regional grid constraints, rising electricity demand from data centers, and ongoing fuel supply uncertainty. The result: utility budgets that looked reasonable in Q4 are already under pressure. Understanding what's driving these shifts — and how to get ahead of them — is now a core part of the job.
What's Driving Energy Price Volatility Right Now
Natural gas is the foundation — and it's been shaky.
Natural gas is the dominant fuel source for U.S. electricity generation, which means its price movements ripple directly into your electric bills. After hitting record lows in 2024, gas prices rose sharply in 2025 — up roughly 56% from the prior year — and have remained elevated heading into 2026. This winter provided a sharp reminder of just how volatile the gas market can be: Winter Storm Fern in late January pushed Henry Hub spot prices to historic levels, briefly exceeding $30/MMBtu before retreating, sending electricity prices spiking across major grids in the Midwest and East.
Near-term forecasts from the U.S. Energy Information Administration (EIA) project Henry Hub natural gas prices averaging around $3.80/MMBtu for 2026 — but those figures represent averages. Daily and seasonal swings remain wide, and global factors (including disruptions to LNG flows from the Middle East) are adding new layers of uncertainty to a market that facility managers once treated as relatively stable.
Electricity demand is rising faster than supply in key regions.
Demand growth across U.S. power grids is accelerating, driven by data center expansion, cryptocurrency mining, and electrification trends. The EIA projects U.S. electricity generation will need to grow 1.2% in 2026 and 3.1% in 2027 — with some regional grids facing much steeper demand increases. The Electric Reliability Council of Texas (ERCOT) alone is forecast to see electricity demand rise nearly 10% in 2026. That kind of demand concentration creates summer price spikes that spill over into commercial utility rates in affected regions.
Regional grid congestion compounds the problem.
National averages don't protect your locations. Price volatility is highly regional — driven by local transmission constraints, capacity market rules, and weather exposure. Facilities in the Northeast, Mid-Atlantic (PJM), and Texas face different risk profiles than those in the Pacific Northwest or Mountain West. Forward power prices for the balance of 2026 have already moved significantly higher compared to projections made just a few months ago.
Capacity market pressures are adding a structural cost layer.
Beyond fuel costs, utilities are passing through higher capacity charges to recover the costs of maintaining grid reliability. As older generation retires and demand grows, these charges are increasing — particularly in restructured electricity markets. For small commercial customers, this often shows up as a gradual but persistent rise in the supply portion of electricity bills, even in years when fuel costs stabilize.
How Price Trends Affect 7,000–80,000 Sq Ft Sites
Most facility managers at this scale are managing HVAC-heavy buildings where energy cost is directly tied to comfort delivery. QSRs, c-stores, banking locations, and theatres share a common vulnerability: their core customer experience depends on thermal performance, and thermal performance costs money to maintain.
Seasonal load profiles amplify price exposure. A c-store running refrigeration around the clock or a QSR with heavy cooking loads during peak meal periods will see disproportionate energy costs during price spike events. During Winter Storm Fern, commercial sites in the Midwest and East that relied on gas-fired HVAC saw both direct gas cost increases and electricity cost increases simultaneously — a compounding effect most operating budgets aren't modeled to absorb.
Budget variance is the immediate operational consequence. When energy prices spike by 20–40% for even a few weeks, the annualized effect on a multi-site portfolio can be significant. A 10% increase in average electricity costs at a 15,000 sq ft retail or QSR location that spends $3,000–$5,000/month on electricity translates to $3,600–$6,000 in unplanned annual cost per site. Multiply that across 20, 50, or 100 locations, and you're managing a material budget problem — not a rounding error.
The problem isn't just cost — it's unpredictability. Facility managers can manage a known cost increase. What creates real operational stress is when the monthly utility bill can't be forecast accurately enough to protect the maintenance budget, staffing plan, or capital allocation timeline.
Budgeting Strategies That Reduce Risk
Given this environment, there are several proactive approaches that help facility managers reduce energy cost exposure without major capital investment.
Blended rate forecasting. Rather than budgeting to current rates, build in a volatility buffer — typically 10–15% above the 12-month trailing average — and model scenarios for both mild and severe weather years. This prevents mid-year budget revisions and gives you headroom to manage unexpected spikes without cutting other line items.
Weather normalization. Energy costs don't reflect operational performance in isolation — they reflect weather patterns too. Normalizing consumption data by heating and cooling degree days lets you separate true efficiency changes from weather-driven variance. This is especially useful for multi-site portfolios where location matters, and for tracking performance year over year.
Multi-site aggregation planning. Individual sites have limited procurement leverage. But when energy data is aggregated across a portfolio, facility managers gain the visibility needed to negotiate more favorable contract structures and identify which sites are outliers. Aggregation also creates opportunities to shift some procurement volume into fixed-rate contracts during favorable windows, reducing exposure to market rate swings.
Procurement timing awareness. Energy contracts don't need to be managed by the finance team alone. Facility managers who understand when natural gas futures are trending lower — typically in late summer or mild weather periods when storage is robust — can advocate for locking in rates before winter pricing pressure returns. The 2026 market is a good example: despite volatile Q1 conditions, forward pricing moderated in February as milder weather restocked inventories. That window matters.
Key KPIs to Track
Facility managers operating in this environment need metrics that connect energy performance to operational and budget outcomes — not just raw consumption numbers.
Cost per occupied hour captures energy spend relative to actual building use, removing distortion from hours of operation differences across sites. A location running 18 hours per day will naturally consume more than one running 12 — this KPI normalizes that.
Energy cost per transaction (retail/QSR) directly connects utility spend to business activity. If energy cost per transaction is rising while transaction volume holds steady, the building is becoming less energy-efficient — or pricing has increased. Either way, it requires action.
Energy per square foot is the standard cross-site benchmarking metric and the foundation for identifying underperforming locations. Sites running 20–30% above portfolio average in kWh/sq ft are typically candidates for operational review — runtime schedules, setpoint drift, equipment issues.
Energy cost as % of operating expense provides the CFO-level framing that elevates energy conversations from facilities to finance. When this ratio starts climbing, it becomes a same-store margin story — and that's when the conversation changes.
The Bottom Line
Energy volatility in 2026 is not a temporary disruption. It's the new operating environment. The combination of demand growth, weather extremes, regional grid constraints, and global fuel market uncertainty means that utility costs will remain harder to forecast — and more consequential to get wrong — than they were even three or four years ago.
Facility managers who build volatility into their budgeting frameworks, track the right performance metrics, and engage procurement strategy as an operational tool — not just a finance function — will be better positioned to protect their margins and keep their sites running consistently.
That's not facilities work. That's enterprise performance management.
