Selling Into Energy and Utilities: Storm Season, Regulators and a Ten-Year Asset Plan

A rep I was talking to had been working a list of investor-owned utilities for two months. Good list. Good product — asset risk analytics, the kind of thing that reads transformer load data and tells you which units are about to fail. His open rate was fine. His meeting rate was close to nothing.

I asked him what his opener was. It was some version of we help utilities cut maintenance spend.

That is a perfectly reasonable sentence to say to a manufacturer, a logistics company, a hospital system. Say it to a Head of Asset Management at a distribution utility and you have just told them you don't understand how their money works. Not that you're wrong. That you're irrelevant.

Utilities are one of the strangest buying environments in enterprise software, and the strangeness is not cultural. It is structural. The way a regulated utility earns money, plans capital, and reports performance to a state commission changes what a buyer can say yes to. If you learn that structure, you will out-sell reps with better products and bigger logos. If you don't, you will spend a year sending ROI decks into a void.

Start with how the money actually works

Here is the piece most reps never learn, and it explains almost everything else.

A regulated utility does not simply charge what it wants. It goes to a state public utility commission and files a rate case. In that proceeding it lays out what it costs to serve customers and what rates it needs. Two categories of spend get treated very differently.

Capital spend — new substations, replacement transformers, reconductoring, grid hardening, in many cases software that gets capitalized — goes into the rate base. The utility earns an authorized rate of return on that rate base. Capital, put plainly, is how the business makes money.

Operating spend — labor, contract crews, most SaaS subscriptions, tree trimming — is an expense. It gets recovered, but it does not earn a return. Every dollar of O&M is a dollar the utility is trying to defend to a regulator and to its own finance organization.

So when you walk in and say we will reduce your maintenance costs, you are offering to shrink a category the utility is already squeezing, and you are asking to be paid out of the same squeezed category to do it. You have proposed a trade with no upside for the person across the table. Worse, if the savings are real and material, in a future rate case the commission may simply lower the allowed O&M and hand the benefit to ratepayers. That is the system working as designed. It is also why cost-savings pitches die quietly in utility land.

The things that survive are the things that reduce risk the utility cannot currently see, defend capital the utility already wants to spend, or improve a metric the utility is graded on in public.

What a Head of Asset Management actually owns

Titles vary — Director of Asset Management, VP Asset Strategy, Head of Distribution Engineering, sometimes Reliability. The scope is roughly the same, and it is not what most reps assume.

An aging fleet they cannot replace on any reasonable timeline. Distribution transformers, poles, breakers, underground cable that was put in decades ago and is now failing in ways nobody logs well. Everyone knows the fleet is old. Nobody has the money or the crews to swap it out wholesale. So the job is not replace old assets. The job is pick which old assets to replace this year, and be able to defend the pick. That second half is where you live.

A vegetation program. Trees are one of the largest causes of outages on overhead distribution, and vegetation management is a standing, enormous, cyclical line item. Trim cycles, contractor crews, right-of-way disputes with property owners. It is deeply unglamorous and it eats budget, and any rep who can talk about it without flinching gets taken more seriously.

Reliability metrics that go to a regulator. SAIDI is the average number of outage minutes a customer experiences over a year. SAIFI is how many times the average customer loses power. CAIDI is duration per interruption. These are not internal KPIs. In many jurisdictions they are reported, tracked against targets, and tied to penalties or performance incentives. When a Head of Asset Management wakes up at three in the morning, they are not thinking about maintenance cost per unit. They are thinking about outage minutes and whether the number is going the wrong way.

A capital plan set years ago. This is the one reps most consistently miss. The multi-year capital plan — grid modernization, hardening, substation rebuilds — was largely locked in before you ever dialed. It went through internal planning, then into a regulatory filing, then into a commission decision. You are not selling into a blank budget. You are selling into a plan with a shape, and your job is to attach to something already in it or to give someone ammunition to defend a piece of it that is under pressure.

Prudency exposure. If a major failure happens and the commission decides the utility should have seen it coming, the associated costs can be disallowed — meaning shareholders eat them, not ratepayers. Post-event, someone will ask: what did you know, when did you know it, and what did you do. "We had no visibility" is the worst possible answer. Being able to show a documented, data-driven basis for the decisions you made is worth real money, and it is not a line item on any ROI calculator.

Why "here's the failure you can't see coming" works

Once you understand the above, the reframe is obvious.

You are not selling savings. You are selling the ability to see a failure before it happens, to rank risk defensibly, and to prove to a regulator that the money was spent on the right assets for the right reasons.

The difference in the opener is stark. Compare:

"We help utilities reduce transformer maintenance costs."

against:

"Most of the distribution utilities I talk to can tell me the age of every transformer on the system and almost nothing about which ones are actually close to failing. If that's roughly true for you, that's the whole reason I called."

The second one is a hypothesis about their world, not a claim about your product. It invites a correction, and a correction is a conversation. I have written out the full thirty-second version of this in the energy and utilities cold call script, including how to handle the "we already have an asset management system" brush-off, which you will hear on almost every dial.

One more thing on language. Do not say predictive maintenance in your first sentence. It has been said to these people so many times by so many vendors that it now functions as a signal that you are the fourth call this week. Describe the outcome in their vocabulary — outage minutes, unplanned replacements, crew truck rolls, deferred capital — and let them apply the category label themselves.

The buying calendar is two calendars

Every utility runs at least two budget rhythms and you need to know which one you are in.

The O&M budget is annual, tight, and defended line by line. This is where a modest software subscription usually lands if nobody has done any work to position it otherwise. It has a hard planning window, it is the first thing cut when storm restoration blows a hole in the year, and it is the reason so many utility deals slip a quarter and then a year.

The capital plan operates on a much longer horizon and is tied to regulatory filings. Getting into that plan is slow — you are talking about planning cycles that start well before the spend year — but once you are in, the money is far more durable, and the internal politics flip in your favor because capital is the side of the ledger the business wants to grow.

What this means practically: ask, early and directly, which pocket the buyer thinks this comes out of. It is not a rude question. It is the question a serious vendor asks. "When something like this gets funded here, does it typically land in O&M or does it get attached to a capital program?" The answer tells you your timeline, your approver, and your ceiling in a single sentence.

It also tells you whether you should be pursuing this deal at all this year. If they tell you the current plan is locked and the next planning window opens in eight months, you have not lost. You have just been handed the actual close date, which is more than most reps in your patch have. Work the relationship, get in front of the planning cycle, and be the incumbent idea when the window opens.

The person who evaluates you cannot buy you

This is the trap that kills good utility deals.

Your first real champion will usually be an engineer. A distribution planning engineer, a reliability engineer, an asset analyst. Smart, curious, genuinely interested in the data. They will ask excellent technical questions. They will want to test the model. They will engage.

They also, almost without exception, cannot sign anything. And here is the part that stings: their enthusiasm is not a buying signal. It is an accurate reading of a good product by someone with no budget authority.

The signer is typically a director or VP, sometimes the COO on larger programs, with procurement and often legal and cybersecurity review in the path. In a regulated utility, vendor security review is not a formality — anything touching operational systems gets serious scrutiny, and if your product goes anywhere near grid operations, add time.

So run your discovery to find the path, not just the pain. Who has to agree? Who has been burned by a vendor before? Whose budget line does this come out of, and have they been told? What happened the last time this group tried to buy something like this, and why did it stall? I have laid out the full twenty-five-minute structure for this — including the questions that surface the capital-versus-O&M answer without sounding like you are qualifying them — in the energy and utilities discovery playbook.

One concrete move: ask your engineer champion what their director cares about this year. Not what the company cares about. What their specific director is being measured on. Engineers usually know, and they are usually happy to tell you, and it is the single best piece of intel you will get in the whole cycle.

Pilot on one feeder

Utilities do not buy enterprise-wide. Not first, anyway. The pattern that works, over and over, is small and specific.

One feeder. One substation. One circuit that has been a chronic problem — the one the reliability team already talks about in meetings, the one with the bad SAIDI contribution that everyone is tired of hearing about. You go in there, you run against their data, and you produce something they can look at and argue with.

This works for three reasons. It fits inside a spend threshold that a director can approve without a formal procurement circus. It gives your champion something to show internally that is not a slide. And it produces the artifact that gets you into the capital conversation — a ranked list of assets on a real circuit, with a defensible basis, that someone can carry into a planning meeting.

When you scope it, pick the circuit with them and pick a bad one. Reps instinctively want the clean dataset. Resist that. The messy chronic-problem feeder is where your value is visible, and where their skepticism lives. Beat the skepticism where it lives.

And when you demo, demo against that feeder, not against your sandbox. The product demo script for selling asset risk analytics walks through how to structure that session — leading with the ranked risk list rather than the data ingestion architecture, and how to handle the engineer who wants to interrogate your model in front of their boss. Which they will. Let them. An engineer stress-testing your methodology in front of a director is doing your selling for you, as long as you can take the questions calmly.

Storm season cuts both ways

Here is the timing thing nobody tells new reps in this vertical.

When a major storm hits the service territory, your entire buying committee disappears. Asset management, reliability, engineering, operations leadership — they are in a storm room. Mutual aid crews are arriving from three states away. Nobody is reading your follow-up. Nobody is taking your call. Calling into an active restoration is the fastest way to be remembered badly, and utility people talk to each other across companies more than most industries.

So during storm season in an affected territory, stop dialing. Genuinely stop. Reallocate those hours to territories that are quiet.

But the two or three weeks after restoration are the best window you will get all year. Because right then, someone is running the post-event review. Someone is assembling the numbers for the commission. Someone is being asked why that circuit went down again. The failures are fresh, the gaps in visibility are documented, and the political will to fix something is at its annual peak.

That is when you reach out, and you do it without a whiff of opportunism. Something like: "I held off while you were in restoration. Now that things have settled, I imagine you're deep in the post-event review — that's usually when the visibility gaps show up most clearly. Worth a short conversation?"

No pitch. No condolences theater. Just an acknowledgment that you understand their calendar, which is more than the rest of their inbox managed.

The same logic applies to regulatory milestones. When a rate case is filed, when a commission issues a decision on a grid modernization program, when a performance-based ratemaking framework changes — these are public events, they are searchable, and they move budgets. A rep who tracks their accounts' commission dockets knows more about their buyers' next twelve months than the buyers' own vendors typically do.

What I would do this week

Pick your five biggest utility accounts. For each one, find the most recent rate case or grid modernization filing on the state commission's website. They are public. Read the summary. Write down what the utility told the regulator it intends to spend money on and why. Then write one opener per account that references that intent in their language.

That is maybe three hours of work and it will change your call quality more than any script rewrite.

Then practice the calls. Not on your prospects — on something that will push back. Utility buyers are polite, busy, and quick to brush off anything that sounds generic, and you get one shot at the first fifteen seconds. If I were ramping into this patch, I would run the cold call opener and the first five minutes of discovery through DrillCall against a Head of Asset Management persona until the vocabulary is automatic — SAIDI, feeder, prudency, capital plan — because the moment you hesitate on one of those words, they know exactly how much homework you did.

The product will not carry you here. The homework will.