The Scale of Connecticut’s Rate Increases
Connecticut commercial electricity customers have been hit with some of the steepest rate increases in the country over the past 18 months. United Illuminating, which serves approximately 340,000 customers in the greater Bridgeport and New Haven areas, received approval from the Public Utilities Regulatory Authority for rate increases totaling approximately 23% across its delivery and generation service charges. Eversource, the state's larger utility serving roughly 1.3 million customers across the rest of the state, implemented increases of approximately 11% during the same period.
These are not one-time adjustments. Both utilities have filed or signaled additional rate case proceedings that could layer further increases on top of the current rates. For commercial property operators managing multi-site portfolios across Connecticut, the cumulative impact is staggering. A 50,000-square-foot office building that was paying $120,000 annually in electricity costs in 2024 may now face bills approaching $145,000 to $150,000 — with no change in consumption or operations.
Making matters worse, both utilities have introduced mid-year surcharges and rate adjustments that fall outside the standard rate case cycle. These surcharges, often tied to storm recovery costs, infrastructure hardening programs, or renewable energy procurement mandates, appear as additional line items on commercial bills and can add 5–8% to the total cost beyond the base rate increases. The unpredictability of these charges makes budget forecasting extremely difficult for commercial operators.
Why Connecticut Rates Are the Highest in the Continental US
Connecticut's position at the top of national electricity rate rankings is not accidental — it is the result of structural factors that have compounded over decades. Understanding these drivers is essential for commercial operators trying to make strategic energy decisions, because many of these cost pressures are unlikely to abate in the near or medium term.
Grid Congestion and Transmission Constraints
Connecticut sits at a critical bottleneck in the New England power grid. The state imports a significant portion of its electricity from generation sources in northern New England and New York, but transmission capacity into the state has not kept pace with demand. This congestion drives up the locational marginal price of electricity in Connecticut load zones, meaning that commercial customers in Bridgeport or Hartford often pay substantially more per megawatt-hour than customers in Vermont or Maine, even when the underlying generation cost is similar.
Infrastructure Age and Modernization Costs
Both United Illuminating and Eversource operate distribution infrastructure that, in many areas, dates back to the mid-20th century. The cost of replacing aging transformers, underground cables, and overhead distribution lines is enormous, and state regulators have approved accelerated modernization programs that allow the utilities to recover these costs through rates. While these investments improve reliability, they add billions of dollars to the rate base that customers must fund.
Renewable Energy Credit Procurement
Connecticut's Renewable Portfolio Standard requires utilities to procure an increasing percentage of their power from qualified renewable sources. The cost of Renewable Energy Credits, particularly Class I RECs from sources like offshore wind and solar, is passed through to ratepayers as a separate line item on utility bills. As the RPS targets increase, so does the REC procurement cost. For commercial customers, this can add $0.01 to $0.03 per kilowatt-hour to the effective rate, depending on the compliance year and the market price of RECs.
Limited In-State Generation
Connecticut has retired or decommissioned several major generation facilities over the past two decades without replacing them with equivalent in-state capacity. The closure of coal and oil-fired plants, combined with the planned retirement of aging natural gas peaker units, has made the state increasingly dependent on imported power. This import dependency, filtered through congested transmission corridors, structurally inflates prices relative to states with more balanced generation portfolios.
PURA Rate Case Proceedings: What’s Coming Next
The Public Utilities Regulatory Authority is the state agency responsible for setting utility rates in Connecticut. PURA conducts formal rate case proceedings in which utilities submit detailed cost analyses and revenue requirement calculations, and intervening parties — including commercial ratepayer advocates, environmental groups, and the state Office of Consumer Counsel — present their own analyses and objections.
As of early 2026, several significant rate proceedings are either underway or anticipated:
- Eversource distribution rate case: Eversource has filed a new distribution rate case requesting additional revenue of approximately $180 million annually. If approved in full, this would add roughly 6–8% to the delivery portion of commercial bills. The proceeding is expected to conclude by late 2026.
- United Illuminating grid modernization docket: UI has proposed a multi-year grid modernization plan with capital expenditures exceeding $400 million. The rate recovery mechanism for this plan is under review, and commercial ratepayers will bear a proportional share of the approved costs.
- Standard Service generation rates: Both utilities adjust their Standard Service generation rates semi-annually based on wholesale market procurement costs. The January 2026 adjustment for Eversource increased Standard Service rates by approximately 9%, and the July 2026 adjustment is expected to reflect continued volatility in the ISO New England forward capacity market.
- Public benefits surcharges: Several dockets are considering increases to the public benefits surcharges that fund energy efficiency programs, low-income assistance, and the Connecticut Green Bank. While these programs provide societal benefits, the associated costs are borne by all ratepayers, including commercial customers.
Commercial operators should monitor these proceedings closely, as the outcomes will directly affect operating budgets for the next three to five years. Participating in rate case proceedings through industry associations or directly through legal counsel can provide early visibility into pending cost changes and create opportunities to advocate for rate structures that are more equitable for commercial ratepayers.
Competitive Supply: Opportunities and Risks
Connecticut is a deregulated electricity market, which means commercial customers have the option to purchase their generation supply from competitive suppliers rather than through the utility's Standard Service rate. In theory, competitive supply should offer commercial operators the ability to lock in fixed prices, access wholesale market savings, and negotiate contract terms tailored to their consumption profiles.
In practice, the competitive supply market in Connecticut has been mixed for commercial customers. During periods of wholesale price stability, fixed-rate competitive supply contracts can deliver meaningful savings relative to the utility's variable Standard Service rate. However, during periods of price volatility — such as the winter spikes driven by natural gas constraints in New England — competitive suppliers may offer fixed rates that are significantly higher than the utility rate, locking customers into above-market prices for the duration of their contract.
Key considerations for commercial operators evaluating competitive supply include:
- Contract term and structure: Shorter contracts (12–18 months) provide flexibility but may carry higher per-kWh rates. Longer contracts (24–36 months) can lock in savings but expose the customer to opportunity cost if wholesale prices drop.
- Load factor requirements: Some competitive suppliers require minimum consumption thresholds or charge penalties if actual usage deviates significantly from the contracted volume, which can be problematic for buildings with seasonal load variation.
- Renewable energy options: Several competitive suppliers offer green tariffs or bundled REC products that can help commercial operators meet sustainability commitments while potentially managing overall energy costs more effectively than separate REC procurement.
- Exit clauses and early termination fees: Always review the penalty structure for early contract termination, as some suppliers impose liquidated damages that can negate any savings achieved during the contract period.
Budget Planning Strategies for CT Commercial Operators
Given the current rate environment and the likelihood of continued increases, commercial property operators in Connecticut need to adopt more sophisticated approaches to utility budget planning. The days of simply escalating last year's utility costs by 3% and calling it a budget are over. Effective strategies include:
Granular Rate Component Tracking
Rather than tracking total utility costs as a single line item, operators should break their bills down into delivery charges, generation charges, transmission charges, and surcharges. Each of these components is driven by different factors and changes on different timelines. Delivery charges are set through PURA rate cases and change infrequently but significantly. Generation charges can change semi-annually for Standard Service customers or are fixed by contract for competitive supply customers. Transmission charges are set by ISO New England and FERC, and they can change with little advance notice.
Scenario-Based Budgeting
Building budgets around a single rate assumption is increasingly inadequate. Operators should model at least three scenarios: a base case reflecting current rates with modest inflation, a downside case incorporating pending rate case outcomes and potential surcharges, and an upside case reflecting potential savings from competitive supply procurement or efficiency investments. This approach provides a range of expected outcomes rather than a single point estimate that is almost certainly wrong.
Demand Response and Peak Shaving
Connecticut's commercial rates include significant demand charges based on the customer's peak kilowatt demand during each billing period. For many commercial buildings, demand charges can represent 30–40% of the total electricity bill. Investing in building automation systems, battery storage, or demand response program enrollment can reduce peak demand and generate meaningful savings even in a rising rate environment.
Centralized Utility Data Management
For operators managing multiple properties across Connecticut, the ability to aggregate, normalize, and analyze utility data across the portfolio is essential. Without centralized data management, operators are unable to identify billing errors, detect consumption anomalies, or benchmark performance across properties. Given that billing errors and estimated reads can inflate costs by 2–5% on average, automated utility data platforms pay for themselves quickly in a high-rate environment like Connecticut.
Looking Ahead: Preparing for Continued Volatility
The structural factors driving Connecticut's high commercial electricity rates are not going away. Transmission congestion will persist until major infrastructure projects like the planned HVDC corridors from Canada and offshore wind interconnections are completed — which is unlikely before 2030 at the earliest. Infrastructure modernization costs will continue to flow through rates for the next decade. Renewable energy procurement requirements will only increase, adding to the compliance costs embedded in commercial bills.
In this environment, commercial operators who treat utility costs as a strategic planning challenge rather than an uncontrollable expense will gain a significant competitive advantage. The key levers — competitive supply procurement, demand management, operational efficiency, and centralized data visibility — are all within reach for operators willing to invest in the systems and processes needed to manage them effectively.
Connecticut's commercial rate crisis is not a temporary blip. It is a structural reality that will define operating budgets for years to come. The operators who build utility cost intelligence into their planning processes now will be the ones best positioned to protect margins as rates continue to climb.
For property operators managing portfolios across Connecticut and the broader New England region, the case for automated utility data collection and analysis has never been stronger. The complexity of the rate environment, the frequency of mid-cycle adjustments, and the potential for billing errors all point to the need for systems that provide continuous, granular visibility into every dollar spent on energy.