Ask who sells you electricity and the answer depends on your ZIP code. In roughly half the United States, a monopoly utility generates (or buys) your power and sells it to you at rates set by state regulators. In the other half, you can choose among competing retail suppliers while a regulated utility still delivers the power over its wires. These two models — regulated and deregulated (or restructured) — are the deepest structural divide in American electricity, shaping investment, prices, and innovation.
The regulated model: the compact
The traditional model is the vertically integrated utility: one company owns the power plants, the transmission lines, and the distribution wires, and holds an exclusive franchise to serve customers in its territory. In exchange for the monopoly, it accepts comprehensive state regulation.
The regulatory instrument is the rate case. The utility proposes its costs — operating expenses, fuel, and a return on capital investments — and the public utility commission sets rates designed to recover prudently incurred costs plus a regulated return on equity, typically in the high single digits to around 10 percent. This is cost-of-service regulation: the utility is, in essence, guaranteed cost recovery on approved investments, with profit earned as a return on the capital it deploys (the “rate base”).
The model’s logic is straightforward. Electricity infrastructure requires enormous, long-lived capital investment; the regulatory compact gives utilities the revenue certainty to finance it cheaply. The model’s well-known distortion is equally straightforward: because profit scales with capital deployed, utilities are incentivized to build — the Averch-Johnson effect, sometimes called “gold-plating.” Regulators counter with prudence reviews, disallowing costs deemed imprudent, but the information asymmetry (the utility always knows more about its costs than the regulator) makes this an endless contest.
States in the Southeast, Northwest, and much of the Mountain West retain this model. It has delivered some of the lowest retail rates in the country — though whether that’s the model or the underlying resources (cheap hydro, coal, gas) is a perennial debate.
The restructuring wave: unbundling the monopoly
Beginning in the late 1990s, a wave of states — concentrated in the Northeast, Mid-Atlantic, Texas, and California — restructured their electricity industries. The core move was unbundling: separating the potentially competitive functions (generation, retailing) from the natural monopoly functions (transmission and distribution wires).
Under restructuring, utilities typically sold or spun off their power plants. Generation would henceforth be built and operated by independent companies competing in wholesale markets. The wires remained regulated monopolies — it makes no sense to build competing sets of poles and lines — with the utility earning its regulated return on distribution (and where it still owns it, transmission) infrastructure. And in most restructured states, retail choice was introduced: end users could buy their energy from competing retail suppliers, with the utility remaining as the default provider and the deliverer of last resort.
The intellectual case was that competition would discipline generation costs better than regulation could, while innovation in retail products — green power options, time-varying rates, smart-home bundles — would flourish. The results have been mixed enough to sustain decades of argument, which is itself informative: the honest answer is that restructuring’s record depends heavily on the state, the timeframe, and what you measure.
Retail choice in practice
Where retail choice exists, the market structure has three layers. Generators sell into wholesale markets. Retail electric providers buy wholesale (hedged forward, as described earlier in this series), add a margin, and sell to end users — competing on price, contract terms, and product features. The distribution utility delivers the power, maintains the wires, reads meters, and bills (in some states the retailer bills; arrangements vary).
The retailer’s business is fundamentally about risk management and customer acquisition, not electrons. Margins per customer are thin — often just a few percent — and the business scales on volume. Successful retailers are sophisticated hedgers; failed ones are typically those caught short during price spikes, as discussed in our volatility piece. The product differentiation is real but bounded: electricity is a homogeneous good, so retailers compete on price, fixed-vs.-variable terms, renewable content, and service.
Texas is the purest implementation — nearly all customers choose among dozens of providers — while states like Illinois, Ohio, and Pennsylvania have substantial but less universal retail competition. California restructured wholesale markets but suspended direct retail access for most customers, leaving a hybrid.
Hybrids and the messy middle
The binary framing obscures a large middle. Many “regulated” states have competitive wholesale procurement — utilities buying from independent generators through all-source solicitations rather than building everything themselves. Many “deregulated” states retain strong regulatory hands on the wires and default service. And several states partially restructured then stopped, leaving unique hybrids.
The trend in recent years has actually run in both directions: some traditionally regulated states have introduced competitive procurement to discipline utility building, while some restructured states have layered increasing policy intervention (clean energy mandates, reliability requirements) over their markets — intervention that critics say re-regulates through the back door. The FERC-state tensions described in our capacity markets piece are one manifestation of this blurring.
Comparing outcomes: prices, investment, innovation
The empirical debate is fierce and unresolved, but several patterns are reasonably well established:
Prices. Comparing average retail rates across models is confounded by resource endowments — restructured states in the Northeast have high rates partly because they lack cheap local fuel, not because of market structure. Careful studies find modest effects in either direction depending on methodology. What restructuring clearly did was expose customers to wholesale price volatility more directly — for better (capturing low-price periods) and worse (spike exposure for the unhedged).
Investment. Regulated utilities demonstrably build — the rate-base incentive works, sometimes too well. Merchant generators in restructured markets build only when forward prices justify it, which disciplines overbuilding but can produce boom-bust investment cycles and adequacy anxiety. Neither model has a monopoly on getting investment timing right.
Innovation. Retail choice has produced genuine product innovation — renewable energy plans, free-night plans, smart thermostat bundles — that monopoly utilities were slow to offer. On the grid edge, however, some of the most aggressive distributed-energy programs have come from regulated utilities in the Southeast and West, complicating the narrative that only markets innovate.
What restructuring changed for the utilities themselves
It’s worth noting what happened to the incumbent utilities in restructured states, because their transformation illustrates the model’s logic. Stripped of generation, they became wires companies: their earnings now come from distribution (and sometimes transmission) rate base rather than power plants. This changed their incentives profoundly — they no longer profit from selling more electricity (especially where decoupled) and instead profit from capital deployed in grid modernization: smart meters, distribution automation, resilience hardening.
Some utilities adapted brilliantly, becoming leaders in grid-edge investment. Others struggled with the loss of the generation earnings engine and sought growth through mergers or unregulated affiliates. And in a twist, several restructured states are now watching their utilities propose to build generation again — for data center load, for reliability — raising the question of whether the unbundling of the 1990s will partially reverse. The industry’s structure, it turns out, is not a settled matter but a pendulum.
What the model means for the energy transition
The divide matters enormously for decarbonization strategy. In regulated states, the transition runs through the utility’s integrated resource plan and the commission’s approval — a political-regulatory process where clean energy competes against the utility’s incentive to build rate base. In restructured states, it runs through wholesale market prices and state mandates layered atop them — where clean energy compettes on cost but faces market-design headwinds (missing money, accreditation fights).
Corporate clean-energy buying — the power purchase agreements that have funded much of the recent renewable build — works differently in each: straightforward in restructured markets with liquid wholesale trading, more negotiated and utility-mediated in regulated ones. Data center developers siting massive new loads must navigate both models, and their location decisions increasingly hinge on which structure delivers power faster and cheaper.
Inside the rate case: how regulated prices are actually set
The rate case deserves a closer look, because it’s where regulated-model economics really happen. The utility files a detailed cost-of-service study: operating expenses, depreciation, taxes, fuel costs, and — crucially — its rate base (the depreciated value of approved capital investments) multiplied by the allowed rate of return. Intervenors — consumer advocates, industrial customer groups, environmental organizations — challenge the filing. Administrative law judges hear testimony. The commission issues an order setting new rates, typically years after the costs were incurred.
Three features shape behavior. Regulatory lag — the delay between spending and recovery — means utilities finance investments at their own risk in the interim, which disciplines spending but also means rates perpetually trail costs. Test years (historical or forecasted) determine which costs count, creating endless litigation over what’s representative. And decoupling mechanisms in many states break the link between sales volume and revenue, so utilities don’t profit from selling more electricity — a prerequisite for serious energy-efficiency programs, since otherwise every negawatt-hour saved is profit lost.
The rate case is slow, adversarial, and expensive — and it is also the venue where the energy transition gets negotiated in regulated states: whether a utility may build its own solar farm (adding to rate base) or must buy from independents, how grid-modernization investments are treated, and how the costs of coal-plant retirements are recovered.
The third model: munis and co-ops
Beyond the regulated/deregulated binary sits a large third sector: municipal utilities and rural electric cooperatives, which serve roughly one in seven Americans. Munis are owned by cities; co-ops are owned by their member-customers. Both are nonprofit, both are generally exempt from state rate regulation (governed instead by elected boards), and both tend to have lower rates — partly from nonprofit status, partly from access to tax-exempt financing and federal hydropower.
Co-ops in particular face distinctive challenges: they serve the most rural, lowest-density territories, where the per-customer cost of poles and wires is highest, and many carry legacy debt from coal plants built decades ago. Their governance — democratic in form — can be captured by management in practice, a recurring subject of reform efforts. But as a model, they demonstrate that neither investor-owned monopoly nor full market restructuring exhausts the institutional possibilities.
Which model “wins”?
Neither — and that’s the honest answer a fundamentals series should give. The regulated model offers investment certainty and has delivered reliable, often cheap power; its weakness is the build-bias and sluggish innovation. The restructured model offers cost discipline and product choice; its weakness is investment cyclicality and the complexity of getting market design right. Both are being stress-tested by the same forces: load growth from data centers and electrification, the renewable transition, and extreme weather. The states navigating those forces best will be the ones whose model — whichever it is — adapts its rules to the physics of the new grid rather than defending the ideology of the old one.