The United States does not have a single electricity market. It has a patchwork of regulatory frameworks that vary by state, by utility service territory, and sometimes by customer class. For property managers operating portfolios across multiple states, understanding whether a property sits in a regulated or deregulated market is fundamental to managing energy costs. The market structure determines whether you can shop for a competitive electricity supply, what pricing options are available, how rates are set, and what risks you bear as a consumer.
This guide explains the two primary market structures, maps them across the country, and provides practical guidance for property managers who must navigate both systems simultaneously. Whether you manage ten buildings in a single state or hundreds of properties across fifteen states, the principles outlined here will help you make better procurement decisions, avoid common pitfalls, and capture savings opportunities that many property managers overlook.
Understanding Market Structures: Regulated vs. Deregulated
In a regulated electricity market, a single utility company provides both the generation (supply) and delivery of electricity to customers. The utility owns power plants, transmission lines, and distribution infrastructure. It charges rates that are approved by the state's public utility commission (PUC) through a formal rate-setting process. Customers in regulated markets do not have a choice of electricity supplier. They buy power from their local utility at the approved rate, period.
In a deregulated (or restructured) electricity market, the generation and delivery functions have been separated. The local utility still owns and operates the wires, poles, and transformers that deliver electricity to your building. But the electricity itself, the commodity flowing through those wires, can be purchased from a competitive supplier known as an Energy Service Company (ESCO) or retail electricity provider (REP). The delivery charge remains regulated and set by the PUC, but the supply charge is determined by market competition.
Key Differences at a Glance
- Supplier choice: Regulated markets offer none. Deregulated markets allow you to choose from multiple competing suppliers offering different products and pricing structures.
- Price volatility: Regulated rates change infrequently through formal rate case proceedings. Deregulated supply prices can be fixed for a contract term or float with wholesale market indices.
- Procurement complexity: Regulated markets are simple; you pay the posted rate. Deregulated markets require active management, contract negotiation, and an understanding of wholesale market dynamics.
- Savings potential: Regulated markets offer limited opportunities for supply cost reduction. Deregulated markets can offer savings of five to fifteen percent below the utility's default supply rate, but they also carry the risk of paying more if procured poorly.
- Risk allocation: In regulated markets, the utility bears commodity price risk. In deregulated markets, the customer or their chosen supplier bears this risk, depending on the contract structure.
The State-by-State Landscape
Electricity market restructuring swept through the United States in the late 1990s and early 2000s, driven by the premise that competition would reduce prices. Some states fully embraced restructuring, others partially implemented it, and many never restructured at all. The result is a complex map that every property manager should understand.
Fully Deregulated States (Electric Supply Choice)
States with active retail electricity competition include Texas, Pennsylvania, Ohio, Illinois, New York, New Jersey, Maryland, Delaware, Connecticut, Massachusetts, Rhode Island, New Hampshire, Maine, and the District of Columbia. In these jurisdictions, commercial customers can contract with competitive suppliers for their electricity supply, while continuing to receive delivery service from the local utility.
Texas stands apart as the most aggressively deregulated market. In most of the state served by ERCOT, there is no regulated default supply option. Customers must choose a retail electricity provider or be assigned one. This creates a highly competitive market with a wide range of products and pricing options, but also requires more active management than markets where a default utility supply rate provides a safety net.
Partially Deregulated or Transitional States
Several states have implemented limited forms of competition. Michigan, for example, allows retail choice but caps the percentage of a utility's load that can switch to competitive suppliers. Virginia has moved toward customer choice for some large commercial customers while maintaining regulated service for most consumers. California deregulated in the late 1990s, experienced the energy crisis of 2000-2001, and subsequently re-regulated much of the market, though community choice aggregation programs provide a form of supply choice in many areas.
Fully Regulated States
The majority of states in the Southeast, Mountain West, and Pacific Northwest maintain fully regulated electricity markets. Florida, Georgia, Alabama, the Carolinas, Tennessee, Kentucky, Indiana, Colorado, Utah, Nevada, Oregon, and Washington operate under traditional regulation where the local utility provides bundled generation and delivery service at PUC-approved rates. Property managers in these states focus on rate optimization, ensuring they are on the most favorable available tariff, rather than supplier procurement.
Procurement Options in Deregulated Markets
Property managers operating in deregulated markets have access to several procurement strategies, each with different risk profiles and potential returns. The right strategy depends on the portfolio's size, the property manager's risk tolerance, and the resources available for active energy management.
Fixed-Rate Contracts
The most common procurement approach is a fixed-rate supply contract, typically spanning one to three years. The ESCO provides electricity at a fixed price per kilowatt-hour for the contract term, giving the property manager budget certainty and protection against market price increases. Fixed-rate contracts are simple to understand and administer, making them the default choice for most commercial property managers.
The risk with fixed-rate contracts is opportunity cost. If market prices decline during the contract term, the property manager is locked into the higher fixed price. Additionally, fixed-rate contracts typically include a margin premium that compensates the ESCO for bearing commodity price risk. This premium means the expected cost of a fixed contract is slightly higher than the expected cost of buying at market prices over the same period.
Index or Variable-Rate Contracts
Index-rate contracts price electricity based on wholesale market indices, typically with a fixed adder for the ESCO's margin. The per-kilowatt-hour rate changes monthly or even hourly based on market conditions. These contracts offer the lowest expected cost but the highest budget uncertainty. A mild winter followed by a cool summer might produce significantly lower costs than a fixed contract, while extreme weather or supply disruptions can create month-over-month cost spikes.
Block and Index (Layered) Procurement
Sophisticated property managers and energy advisors use block and index strategies that fix the price for a portion of expected consumption while leaving the remainder exposed to market prices. This approach, commonly called "layering" or "slice and dice," balances budget certainty with market exposure. A typical approach might fix seventy percent of expected load on a forward basis and leave thirty percent indexed, capturing market upside while limiting downside exposure.
Aggregated Purchasing
Property managers with large portfolios can aggregate load across multiple properties and meters to negotiate volume discounts from ESCOs. Aggregated purchasing leverages the combined load profile of the portfolio, which is typically more attractive to suppliers than individual accounts because load diversity reduces the supplier's risk. Savings from aggregation can range from two to ten percent compared to individual account procurement, depending on portfolio size and load characteristics.
Optimizing Costs in Regulated Markets
While regulated markets do not offer supplier choice, property managers still have meaningful opportunities to optimize electricity costs. These opportunities are frequently overlooked because the assumption is that regulated rates are fixed and non-negotiable. While the rates themselves are indeed set by the PUC, how those rates are applied to your property is often within your control.
Rate Schedule Optimization
Most utilities offer multiple rate schedules for commercial customers, differentiated by demand level, usage pattern, voltage level, and sometimes industry type. A property on a general service commercial rate might qualify for a large power rate that carries a lower per-kilowatt-hour charge if it meets certain demand thresholds. A building that operates primarily during off-peak hours might benefit from a time-of-use rate. A property that can take service at primary voltage rather than secondary voltage can avoid the transformation charge included in secondary rates.
Rate schedule optimization requires a careful analysis of the property's load profile, a thorough understanding of the utility's tariff book, and sometimes engineering modifications to qualify for preferred rates. The analysis is property-specific and should be repeated whenever the utility modifies its rate schedules, the property's usage pattern changes significantly, or the property undergoes a major renovation.
Demand Management
In regulated markets where the energy rate is fixed, the demand charge often represents the most controllable cost component. Demand charges are based on the highest fifteen-minute or thirty-minute average demand during the billing period. Reducing peak demand through load scheduling, pre-cooling, and equipment sequencing can produce meaningful cost savings without reducing total energy consumption. A building that reduces its peak demand by ten percent might reduce its total electricity bill by three to five percent, depending on the demand-to-energy cost ratio.
Managing Multi-State Portfolios Across Both Market Types
The greatest challenge for national property managers is operating across both regulated and deregulated markets simultaneously. Each market type requires different competencies, processes, and vendor relationships. A portfolio with properties in Texas, Florida, Pennsylvania, and California spans four distinctly different regulatory environments, each requiring tailored energy management approaches.
Building an Integrated Energy Management Framework
Successful multi-state property managers build energy management frameworks that accommodate both market types within a unified structure. The framework typically includes centralized utility data management that normalizes costs across different rate structures and market types, standardized procurement policies that specify which strategies are authorized for each market type, and market-specific execution supported by internal expertise or third-party energy advisors with jurisdiction-specific knowledge.
The procurement calendar is a critical tool for multi-state portfolios. In deregulated markets, supply contracts have defined terms and expiration dates. Missing a renewal window can result in reverting to the utility's default supply rate, which is typically the most expensive option. A centralized procurement calendar that tracks contract expirations across all properties ensures that renewal negotiations begin early enough to evaluate market conditions and secure competitive pricing.
Natural Gas: A Parallel Market to Understand
While this guide has focused primarily on electricity, many of the same principles apply to natural gas markets. Several states that deregulated electricity also deregulated natural gas supply, allowing commercial customers to purchase gas from competitive marketers while receiving delivery service from the local distribution company. Property managers should evaluate their natural gas procurement strategy using the same framework applied to electricity: understand the market structure, evaluate available products, and align procurement decisions with risk tolerance and budget requirements.
In regulated gas markets, the same optimization opportunities exist. Rate schedule analysis, load factor improvement, and demand management can produce savings that do not require changing suppliers. Gas utility tariffs often contain multiple rate options for commercial customers based on annual consumption, peak demand, and interruptible service willingness, and many property managers are on suboptimal rate schedules simply because no one has reviewed the alternatives.
Whether your portfolio spans two states or twenty, the key to effective energy management across different market structures is a combination of market knowledge, data discipline, and systematic execution. The property managers who master this combination will consistently outperform those who treat energy as an uncontrollable expense, capturing savings that flow directly to the bottom line and demonstrating the operational excellence that owners, investors, and tenants increasingly demand.