Industrial facilities face a record wave of rate increases in 2025. Utilities requested nearly $31 billion in new revenue through official filings, more than double the amount asked for the previous year. Industrial customers bear the steepest price hikes, with retail electricity prices climbing 6.0% from 2024 to 2025, the largest jump of any customer class, according to research from Berkeley Lab and the Brattle Group. This surge pushes industrial electricity costs up 27% since 2019, despite the fact that identical equipment operating in Louisiana pays 5.61 cents per kWh, while similar facilities in Massachusetts face charges of 18.19 cents per kWh.
The Negotiation Trap
Regulators rarely reject these requests outright. Instead, they trim them, and lately they trim less. State commissions approved 66% of the dollar value of revenue increase requests in 2025, compared to a 52% average over the prior two decades. Only 2 of 83 requests were rejected. That means most of the financial burden falls on the few parties who show up to contest the filing. While a customer class cannot stop a rate case, it can influence the final outcome through negotiation. This margin used to be nearly half of the approved increase, but it is shrinking as the total asks grow larger.
Minnesota offered a clear example of this dynamic this spring. Xcel Energy sought an 8.2% residential gas increase and a 10.65% return on equity. A settlement filed in May cut the increase to 4.1% and the return to 9.55%. The agreement included refunds and interest for customers who had already paid an interim increase. The successful outcome relied on organized participants at the table, including the state Department of Commerce and the Citizens Utility Board, demonstrating how coalitions can slice utility rate hikes in half.
After a commission establishes a utility’s total revenue requirement, a class cost-of-service study determines how it is divided among residential, commercial, and industrial users. The cost causer should be the cost payer, but equity factors also play a role. This allocation process is effectively a zero-sum game, balancing the interests of different customer groups. Because residential customers are politically influential and three out of four Americans report a lack of control over utility charges, the political pressure to shift costs toward industrial users is intense.
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Rate design determines the structure of your bill, typically combining a base customer charge, a kilowatt-hour energy charge, and a demand charge tied to peak usage. For facilities with fluctuating load profiles, demand charges often represent the largest cost component. Because rate schedules are assigned based on operating parameters that may be outdated, reviewing these assignments can reveal significant cost-saving opportunities. A facility locked into a tariff schedule designed for a different production profile may be overpaying simply because no one reviewed the paperwork.
How to Start the Process
Industrial customers have standing to intervene in these proceedings. At the federal level, FERC’s Rule 214 grants standing to anyone with an interest that may be directly affected by the outcome. State commissions run parallel tests, asking if a proceeding will bind or affect a specific interest different from the public. For a manufacturing plant dealing with a restructured demand charge, both criteria are easily satisfied. Being a party provides access to discovery, the right to file testimony, cross-examination at hearings, a seat in settlement talks, and appeal rights.
Two key considerations apply. Commissions require parties to intervene promptly on the reasonably foreseeable issues raised in a rate filing, and submitting a late petition demands showing good cause. Food manufacturers are not expected to maintain dedicated regulatory affairs teams, but established industrial customer groups often intervene as a collective bloc to distribute legal fees across members. This enables individual plants to secure legal representation that would otherwise be cost-prohibitive. To identify these groups, consult your utility account representative or review the service list on your commission’s recent case dockets.
The Four Metrics to Analyze
Before a facility takes any formal action, it must gather specific data points to understand its position. The first metric is the rate schedule itself. Every industrial customer should locate the tariff number printed on their utility bill and review the complete rate schedule posted on the utility’s website. This document outlines the exact charges and eligibility requirements. Many facilities remain locked into outdated schedules for years, even if their operational load has changed significantly. Verifying that current operations still meet the eligibility requirements is a critical first step.
The second metric involves the demand charge as a share of the total bill. A facility should analyze a full year of utility statements, separating energy use from demand fees. When demand charges account for at least one-third of the overall bill, it indicates that high peak usage, rather than baseline consumption, is driving costs. Identifying this ratio helps determine if the current rate design accurately reflects the facility’s operational reality or if an alternative schedule might be more appropriate.
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Third, a company needs 12 months of interval data. Most utilities provide this data for a fee or it can be requested through the meter. Analyzing this data generates a load profile, which pinpoints the exact operational shifts, production lines, or startup routines that establish the billing peak. Most facilities have not analyzed this metric, yet it directly determines the pricing set by their rate schedule. Understanding these peaks allows a facility to propose a schedule that aligns with its actual usage patterns rather than a generic profile.
The fourth metric is the commission’s open dockets. A facility must search its state commission’s website for its specific utility. If a general rate case is currently open, there is a procedural schedule available to the public. This schedule will list an intervention deadline. Reviewing these dockets ensures that a company is aware of the specific timeline and procedural rules that govern the rate case.
Why This Matters for Operations
Intervening in utility proceedings presents a rare opportunity to capture recurring margin without driving additional sales volume. For a facility spending $2 million annually on power, utility rate cases routinely adjust electricity costs by single-digit percentages every few years. Securing even a one percentage point reduction, or transitioning to a rate schedule aligned with actual load profile, delivers ongoing margin. This financial gain can directly support capital projects, such as production line upgrades, without requiring customer-facing price hikes.
Conversely, inaction carries a tangible expense. When a customer class fails to advocate for its position, the regulatory burden and cost allocations naturally shift toward the unrepresented parties. By reviewing the tariff schedule and monitoring the commission’s docket, a facility can take control of a major variable in its budget. If a proceeding is active, the intervention timelines are already underway.
