Utility Tariff Optimization

Commercial energy buyers spend their attention on the competitive half of the bill — the supply rate, where there is a market and a negotiation. The regulated half, the delivery charges set by the utility's filed tariff, is treated as a fixed cost of doing business.

It is not fixed. It is fixed per schedule, and which schedule you are on is a choice. Utilities publish a menu of rate schedules with different eligibility rules and radically different cost structures, and your account sits on whichever one fit your load on the day the meter was energised. If your business has changed since then — and it has — nobody re-ran the comparison, because nobody at the utility is paid to.

How You Ended Up on the Wrong Schedule

Rate assignment happens once, at connection, based on expected load. After that it persists. Meanwhile the facility does things:

• Adds or drops a shift, changing load factor substantially.
• Retrofits lighting or HVAC, cutting consumption while leaving peak demand largely intact — which pushes the account into a worse position on any schedule weighted toward demand charges.
• Installs refrigeration, process equipment or EV charging, raising peak demand disproportionately.
• Expands and takes service at a higher voltage, sometimes acquiring its own transformer without the billing ever reflecting it.
• Installs solar or storage, which changes the net load shape entirely and frequently makes a different schedule optimal.
• Simply crosses a threshold — a demand level or annual consumption figure — that makes a different schedule available.

Each of these is a reason to re-run the analysis. Almost none of them triggers one.

The Schedule Families

Exact names vary by utility, but the structures are consistent across the country:

• Small general service. Energy-only or minimal demand component. Simple, and usually the right answer below a low demand threshold.
• General service, demand-metered. The workhorse commercial schedule. A per-kW demand charge plus per-kWh energy. Load factor is what determines whether this is good or bad for you.
• Large general service / primary. Lower per-unit rates for larger loads, often with a customer-owned transformer requirement and higher fixed charges.
• Time-of-use. Energy and sometimes demand priced by period. Can be mandatory above a threshold in some jurisdictions, optional below it.
• Interruptible or curtailable. A discount in exchange for a contractual obligation to reduce load on request, with penalties for non-performance.
• Standby / supplemental. For sites with on-site generation. Frequently mispriced against sites that added solar without reviewing their schedule.

Six Signals You Are Misclassified

• Your load changed and nobody re-checked. The single strongest predictor.
• Your load factor is atypical for your class. Load factor is average demand divided by peak demand. Very high load factor sites are usually better off on demand-weighted schedules; very low load factor sites are usually punished by them. If yours is above 70% or below 30%, check.
• Demand charges are a large share of your delivery cost. If demand-related charges exceed roughly a third of the delivery side, the schedule is worth challenging — and so is peak load management, which attacks the same number from the operational side.
• You are near a threshold. Accounts sitting just above or just below an eligibility boundary are the most likely to be on the wrong side of it, and sometimes a small operational change moves you into a materially better schedule.
• You take primary voltage but are billed secondary. Check who owns the transformer. This one is binary, verifiable, and occasionally worth a great deal.
• You have never claimed a rider you qualify for. Manufacturing exemptions, economic development riders, agricultural provisions, interruptible options and standby schedules all require you to ask.

Time-of-Use: The Analysis That Must Not Be Guessed

Time-of-use is where the largest gains and the largest self-inflicted losses both live. The rate structure rewards concentrating consumption outside the on-peak window and punishes the opposite, sometimes severely, and whether your facility benefits is a question about the shape of your load rather than about your industry.

Facilities that usually gain: overnight or continuous operations, cold storage with thermal mass that can be pre-cooled, water and wastewater pumping, any site with battery storage, and process operations that can move a batch by a few hours.

Facilities that usually lose: standard-hours offices, retail with fixed trading hours, schools, and anything whose entire operating day sits inside the on-peak definition.

The determination is arithmetic. Take twelve months of interval data, apply each candidate schedule to it, and compare the totals. Anyone offering a view on time-of-use without having done that is guessing, and the minimum-stay provision means guessing wrong is expensive for a year.

Running the Analysis

The method, in order:

• Pull twelve months of interval data for the account — the utility holds it and will release it to you or an advisor with a Letter of Authorization.
• Obtain the current tariff book, including riders and the effective dates for each period covered.
• Confirm eligibility for every schedule, not just the obvious neighbors. Eligibility rules are specific and sometimes surprising.
• Recalculate the full twelve months under each eligible schedule. A full year matters because seasonal schedules and ratchets produce results that a single month cannot reveal.
• Model the change, not just the steady state. Include any metering or service costs and the minimum-stay obligation.
• Check the interaction with supply. Changing rate class can change how your supply contract prices you and, in some markets, how your capacity obligation is calculated.
• File the request in writing and confirm the effective date on the first bill after the change.

That last step is not a formality. Requested rate changes that were never actually implemented are a recurring finding in bill audits — which is why this exercise pairs naturally with a utility bill audit, and why running them together tends to find more than running either alone.

What It Is Worth

Tariff optimization has an unusual economic profile: no capital, no operational disruption, no negotiation with a counterparty who can say no on commercial grounds — the schedule is published, the eligibility rules are objective, and if you qualify you are entitled to it. The cost is the analysis. The benefit recurs every month indefinitely, and it stacks with supply procurement rather than competing with it, because the two address different halves of the bill.

The reason it goes undone is not that it is hard. It is that it requires reading a tariff book, which is nobody's favorite afternoon, and that the savings are invisible until somebody looks.