The United States power grid is facing a level of strain that has not been seen in decades. After years of flat or declining electricity demand, consumption is surging, driven by an unprecedented wave of data center construction, the electrification of transportation, and the rapid scaling of artificial intelligence workloads that consume enormous amounts of power. The North American Electric Reliability Corporation (NERC) has warned that large portions of the country face elevated risk of electricity shortfalls during peak demand periods, a situation that is expected to worsen before it improves.
For commercial property managers, this is not an abstract infrastructure story. Grid strain translates directly into higher electricity rates, capacity surcharges, reliability concerns, and potentially mandatory demand reduction requirements. Understanding the forces driving grid strain and preparing for their impact is becoming as essential to property management as understanding local real estate tax assessments or insurance markets.
The Data Center Demand Explosion
The scale of data center growth in the United States is staggering. Major hyperscale operators including Amazon Web Services, Microsoft Azure, and Google Cloud are building data centers at an unprecedented pace, each facility consuming between fifty and one hundred megawatts of power, equivalent to the electrical demand of a small city. In Northern Virginia alone, data center power demand exceeds four gigawatts and is projected to double within five years. Similar buildouts are occurring in markets across the country including Columbus, Phoenix, Atlanta, and the Dallas-Fort Worth metropolitan area.
The power requirements of these facilities are reshaping local electricity markets in ways that directly affect other commercial consumers. When a utility must add hundreds of megawatts of generation and transmission capacity to serve data centers, the cost of that infrastructure is spread across all ratepayers through the rate base. Commercial property managers in data center-heavy markets are already seeing accelerated rate increase filings by their local utilities, with the infrastructure costs of serving data centers as a primary driver.
In some markets, the pace of data center development has outstripped the grid's ability to deliver power. Dominion Energy in Virginia has reported interconnection queues measured in years, and new commercial customers in some areas face extended timelines for obtaining adequate electrical service. For property managers developing or repositioning assets in these markets, electrical capacity is becoming a critical site selection factor that can make or break a project's feasibility.
AI Compute: The Load Growth Accelerator
Artificial intelligence workloads are amplifying the data center demand story by an order of magnitude. Training a large language model consumes vastly more electricity than traditional computing tasks. A single AI training run can consume as much electricity as hundreds of U.S. households use in an entire year. As AI capabilities expand and more organizations deploy AI at scale, the power consumption of these workloads is growing exponentially.
The infrastructure implications extend beyond the data centers themselves. AI chip manufacturers are building fabrication plants (fabs) that consume enormous amounts of electricity and water. Supporting infrastructure including cooling systems, backup power facilities, and fiber optic networks all add to the electrical load. The entire AI supply chain, from chip manufacturing to model training to inference serving, is electricity-intensive at every stage.
For property managers, the AI-driven demand surge matters because it is consuming generation and transmission capacity that might otherwise be available to serve commercial buildings. When a utility must choose between connecting a data center that will consume fifty megawatts and a new office development that will consume five megawatts, the revenue calculus favors the data center. Commercial properties may find themselves waiting longer for service upgrades, paying higher rates to fund infrastructure expansion, and facing more frequent capacity constraints during peak demand periods.
NERC Warnings and Reliability Risks
NERC's annual reliability assessments have grown increasingly urgent in recent years. The organization has identified elevated risk areas covering much of the central and western United States, where generation retirements, transmission constraints, and demand growth create the potential for electricity shortfalls during extreme weather events. The retirement of coal-fired power plants, which provided reliable baseload generation for decades, is removing capacity from the grid faster than replacement resources are being built.
The reliability risks are not theoretical. Winter Storm Uri in 2021 demonstrated what happens when grid capacity is insufficient to meet demand. Millions of customers in Texas and surrounding states lost power for days, with devastating consequences for commercial properties including frozen pipes, equipment damage, and prolonged business interruptions. While the specific circumstances of Uri were unusual, the underlying vulnerability, insufficient reserve margins during extreme conditions, is becoming more common across the country.
NERC has identified that more than 300 gigawatts of generation capacity are at risk of retirement by 2035, while demand is projected to grow by at least 100 gigawatts over the same period. The resulting gap must be filled by new generation, storage, and demand management, or reliability will deteriorate further.
What This Means for Commercial Properties
Property managers should expect more frequent reliability events in the coming years, ranging from voluntary conservation alerts to mandatory curtailment orders. Buildings that can reduce their electrical demand quickly during grid emergencies will be better positioned than those that cannot. Demand response programs, which pay building operators to curtail load during grid stress events, are becoming more valuable and more widely available. Properties with building automation systems that can shed non-essential loads quickly can generate meaningful revenue from demand response participation while contributing to grid stability.
Capacity Surcharges and Rate Impacts
The financial impact of grid strain on commercial electricity customers is materializing through several mechanisms. Capacity charges, which recover the cost of maintaining enough generation to meet peak demand, are increasing dramatically in several wholesale electricity markets. The PJM Interconnection, which serves the Mid-Atlantic and Ohio Valley regions, recently cleared a capacity auction at prices nearly eight times higher than the prior year, an increase that will flow through to retail electricity bills starting in mid-2026.
Transmission and distribution infrastructure investment is another major cost driver. Utilities across the country are filing rate cases seeking double-digit percentage increases to fund grid modernization, transmission expansion, and distribution system upgrades. These rate increases are not one-time events. They reflect a sustained period of infrastructure investment that will continue for a decade or more as the grid is rebuilt to accommodate new demand patterns.
Cost Impact by Market
The magnitude of cost increases varies significantly by market. Properties in restructured (deregulated) electricity markets face direct exposure to wholesale price volatility, including the capacity auction increases described above. Properties in regulated markets are somewhat insulated from wholesale price swings but face rate case increases that tend to be larger and less frequent.
- Mid-Atlantic (PJM territory): Capacity costs projected to add two to four cents per kilowatt-hour to commercial rates beginning in 2026, representing a fifteen to twenty-five percent increase in total electricity costs for many buildings.
- Texas (ERCOT): Continued wholesale price volatility driven by summer peak demand, renewable intermittency, and limited interconnection with neighboring grids. Demand charges for commercial customers are increasing as the grid operator implements new reliability mechanisms.
- California (CAISO): Among the highest commercial electricity rates in the nation, with continued upward pressure from wildfire mitigation costs, renewable integration expenses, and transmission investment. Time-of-use rate differentials are widening, creating both cost challenges and opportunities for buildings that can shift load.
- Northeast (ISO-NE, NYISO): Natural gas pipeline constraints drive winter price spikes, while summer cooling demand strains capacity. Capacity costs are elevated and increasing, and offshore wind integration will require significant transmission investment over the coming decade.
Backup Power Planning: No Longer Optional
The increasing frequency and severity of grid stress events is changing the calculus of backup power investment for commercial properties. Emergency generators that were sized to keep essential systems running during brief outages may be inadequate for extended events. Property managers are evaluating their backup power capabilities with fresh urgency, and many are finding gaps between their current equipment and the duration and scope of backup they actually need.
The traditional diesel generator remains the workhorse of commercial backup power, but several factors are complicating its continued dominance. Emissions regulations in many jurisdictions limit the number of hours per year that diesel generators can operate, reducing their utility for demand response and extended outage scenarios. Fuel supply disruptions during widespread events, as seen during Hurricane Sandy and Winter Storm Uri, can leave generators idle when they are needed most. Maintenance costs for aging generator fleets are increasing, and replacement units face extended lead times.
Emerging Alternatives
Battery energy storage systems (BESS) are emerging as a complement to or replacement for diesel generators in some applications. A properly sized battery system can provide several hours of backup power for essential systems, bridge the gap between a grid outage and generator startup, and participate in demand response programs during normal operations. The economics of battery storage have improved dramatically, with installed costs declining by more than sixty percent over the past five years.
Natural gas generators offer another alternative, particularly for buildings with existing natural gas service. Gas generators produce fewer emissions than diesel units and are not subject to the same operating hour restrictions in most jurisdictions. However, they are vulnerable to gas supply disruptions during extreme cold weather events, exactly when backup power is most needed.
Strategic Planning for a Strained Grid
Property managers who approach grid strain proactively will be better positioned than those who react to each cost increase and reliability event as it occurs. A strategic approach to grid-related risk includes several key elements.
First, understand your portfolio's exposure. Identify which properties are in markets facing the most acute grid strain, highest rate increase projections, and greatest reliability risk. Prioritize proactive measures at these properties rather than spreading limited resources evenly across the portfolio.
Second, invest in energy efficiency as a hedge against rate increases. Every kilowatt-hour of consumption eliminated is a kilowatt-hour that will not be subject to future rate increases. The most cost-effective efficiency measures, LED lighting, HVAC optimization, and building automation system upgrades, typically pay for themselves within two to three years at current rates and faster as rates increase.
Third, evaluate on-site generation and storage. Solar panels, battery storage, and combined heat and power systems can reduce grid dependence, lower peak demand charges, and provide backup power during outages. The financial analysis for these investments has improved significantly as grid electricity costs have increased, and federal incentives including the Investment Tax Credit make many projects economically attractive even without considering resilience benefits.
Fourth, build utility cost monitoring into your standard operating procedures. Monthly review of utility bills across the portfolio, tracking of rate changes and regulatory proceedings, and benchmarking of consumption patterns enable early identification of cost anomalies and emerging trends. This intelligence is essential for budget forecasting, lease negotiations, and capital planning decisions. The grid strain challenge will not resolve quickly. New generation takes years to build, transmission projects face extended permitting timelines, and demand growth shows no sign of abating. Property managers who understand these dynamics and plan accordingly will navigate the transition successfully. Those who do not will face a steady erosion of operating margins and property values as energy costs consume an ever-larger share of building economics.