Electric Power Generation, Transmission and Distribution (U.S.)

NAICS 2022 code 2211 — a rollup investor primer for public-market and private investors

NAICS = North American Industry Classification System, the U.S. government's standard for grouping businesses by activity. This is a rollup primer: NAICS 2211 is an industry group (4-digit) that sits one level above two 5-digit industries — 22111 Electric Power Generation (making the electricity) and 22112 Electric Power Transmission, Control and Distribution (moving and delivering it). This note synthesizes both child primers plus our ingested federal statistics for the combined 2211 level. Core business statistics (revenue, firms, establishments, employment, concentration) are our authoritative ingested U.S. Census figures; physical scale, ownership mix, capital spending, and market data come from the Energy Information Administration (EIA), Department of Energy (DOE), and industry sources as cited. Written for general investors, public-market and private alike.

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1. Overview

NAICS 2211 is the entire electricity supply chain in one code — from the moment a fuel becomes power to the moment that power reaches the plug. It contains two industries that together book about $563.3 billion of counted (private-sector) revenue across roughly 2,626 firms and 12,735 establishments, employing about 519,711 people [2][3]. That is a small headcount for the machine that runs the entire U.S. electricity supply — the signature of an extraordinarily capital-heavy business (over $1 million of revenue per worker, and an implied average pay near $133,000) [3].

The reason to look at this level rather than the whole utility sector is contrast between the two halves. They are not two versions of one business — they are two different businesses stapled together:

• Generation (22111) is a production business. Eight competing fuels and technologies convert energy into power; the layer carries fuel choice, the energy transition, commodity prices, and market risk. Part of it earns a regulated return; part of it sells into competitive wholesale markets. This is the variable, policy-driven, higher-upside half.
• Transmission and distribution (22112) is a toll-road business. The wires that carry and deliver the power are regulated monopolies that earn an approved return on the capital they sink into the network. They do not care which fuel wins; they are paid to move electrons. This is the bond-like, lower-variance half.

Put simply: the power plants are a commodity-and-competition business wrapped in some regulation; the wires are a regulated utility with no commodity bet. A top-down "utilities" summary averages those two profiles into a single number and hides the most useful decision an investor makes here — which half of the chain do you want to own, and why. This primer leads with that split, then covers the group.

Two ways in, common to both halves. Public-market investors buy the listed utilities, merchant generators, and renewable platforms — but there is no pure-play stock for either child; every listed owner is a mixed fleet or a diversified regulated utility. Private investors — infrastructure funds, private equity, direct developers, and public-power / municipal bodies — buy the plants, wires, portfolios, or project debt directly. Which route fits depends on which half you are buying.

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2. What's inside — the two children, and how they differ

The group contains exactly two child industries. They sit in sequence — make the power, then move and deliver it — but they are structured, regulated, owned, and invested in very differently.

Comparison table — the two children at a glance

IPP = independent power producer (a merchant generator that sells power into markets rather than to captive rate-payers). HHI = Herfindahl-Hirschman Index, a 0–10,000 concentration gauge; U.S. antitrust agencies treat anything below 1,500 as "unconcentrated." Share-of-group is of the group's counted Census revenue [2][4].

Four contrasts stand out.

• The size split is counterintuitive. Most people equate "power" with power plants, but by counted revenue the wires are nearly three-quarters of the group and generation only about a quarter. That is partly real (distribution collects the whole retail electricity bill) and partly an artifact of how revenue is booked — the retail bill embeds the cost of the energy that generation already sold at wholesale, so the two layers' receipts partly double-count the commodity (see §3). Either way, the wires are not a small appendage to generation; by dollars they are the larger business.

• Direction of travel differs in kind. Both halves are growing, but generation is a mix of winners and losers travelling in opposite directions (natural gas and nuclear re-rating up, solar/wind/storage growing fast, coal and biomass in structural decline), while the wires are a rising tide that lifts both children regardless of which fuel wins. If you want exposure to rising electricity demand without having to pick the winning fuel, the wires are the cleaner bet.

• The economic engine is the sharpest divide. The wires run on one model — regulated rate base × allowed return, a capped but predictable toll. Generation runs on two — the same regulated model plus a competitive/merchant model where revenue swings with energy prices, capacity auctions, and power-purchase agreements. All of the group's commodity risk, and most of its policy-driven upside, sits in the generation half.

• Ownership undercounts the group on both sides, differently. Government, municipal, and cooperative owners are heavy throughout — federal and public power dominate hydro and hold a fifth of nuclear on the generation side, and municipal plus cooperative systems are a majority-by-count of distribution on the wires side. Federal business statistics largely exclude those owners, so the $563 billion understates the true footprint of the whole chain (see §3).

One thing the two share: at the level of any individual utility, both children are monopolies — a power plant competes, but a distribution grid or a transmission line in a given territory faces no direct rival. The group looks fragmented (thousands of firms) because the monopolies are geographic, not because there is head-to-head competition.

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3. Size — the rollup figures, and how to read them

Our authoritative Census figures for NAICS 2211 (the counted, private-sector industry group):

The rollup reconciles almost exactly against the two children. Revenue ($146.3 B generation + $417.0 B wires = $563.3 B), establishments (4,192 + 8,543 = 12,735), employment (134,570 + 385,141 = 519,711), and payroll ($18.18 B + $51.09 B = $69.27 B) are the clean sums of the child figures [2][3][4]. The one measure that does not simply add up is the firm count: 2,626 at the rollup versus 2,703 summed across the children — because a company that owns generating plants and distribution wires is counted once here but in both child industries. That gap of ~77 firms is a direct measure of how many owners are vertically integrated across the make-and-move divide, and it is why the listed "pure play" for either child barely exists.

The group looks less concentrated than either child — and that is a clue, not a paradox. The rollup HHI of 186 is below both generation (274) and the wires (207), and the top-four share (17.7%) is below both children's. Merging two industries whose largest firms only partly overlap dilutes every firm's share of the combined revenue, pushing the joint concentration below either part. The honest reading: the group is genuinely unconcentrated nationally, but that number hides pockets of real concentration inside it (nuclear generation, high-voltage transmission) and near-total local monopoly everywhere.

Two caveats before you take $563 billion as "the size of U.S. power."

1. The government undercount. Census business surveys generally exclude government-owned establishments [5]. That matters a lot here: federal and public power own ~73% of hydro and ~⅕ of nuclear generation, and municipal plus cooperative systems are a majority-by-count of distribution [7][8][9]. The true asset base and workforce are larger than the tables imply, and there is no official consolidated total that adds government generation and public-power wires back in — treat that combined figure as not available rather than estimating it.

2. The commodity double-count. The $563 billion is the correct arithmetic sum of receipts, but it is not the sector's value added. Distribution's receipts are largely retail electricity bills, which already include the cost of the power that the generation layer booked when it sold that energy at wholesale. So the commodity is counted once in generation and again inside distribution's revenue. The figure is right as reported; just don't read it as the industry's economic size — most of the value-added is smaller and sits in the network and the generating margin, not the pass-through cost of fuel.

Physical scale (the more reliable gauge of the real industry). On the make side, the U.S. fleet is about 1,230 gigawatts (GW; 1 GW = 1,000 megawatts) of capacity producing roughly 4,300 terawatt-hours (TWh; 1 TWh = 1 billion kilowatt-hours) a year [6]. On the move-and-deliver side, the network is roughly 600,000 miles of high-voltage transmission line plus more than 5.5 million line-miles of local distribution on the order of 180 million poles [23]. The end market — retail electricity sales — was worth about $514 billion in 2024 by EIA's count [6].

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4. The investable universe — where the group's value concentrates

Two facts govern the whole group. First, there is no pure-play public stock for either child, and none for the group — every listed name is either a mixed generating fleet or a diversified regulated utility that blends generation, transmission, distribution, and often gas. Second, a large share of the physical chain is not listed at all — it sits with federal agencies, public-power authorities, cooperatives, and private infrastructure funds.

Where public-market value concentrates. A recurring set of names splits into three profiles, which map onto the make/move divide:

• Merchant / independent power producers (the generation "torque") — valued on cash flow and capacity prices, low or no dividend. Constellation (CEG) (largest U.S. nuclear operator, ~55 GW after buying Calpine), Vistra (VST), NRG (NRG), Talen (TLN). These are pure generation-layer bets; they re-rated sharply in 2024–2026 on rising demand and record capacity prices [22].
• Renewable platforms and yieldcos (generation, contracted) — higher dividend, contracted cash flow. NextEra (NEE) (the world's largest wind and solar owner and the largest U.S. battery owner, wrapped around regulated Florida Power & Light), Brookfield Renewable (BEP/BEPC) (the most direct listed hydro exposure), Clearway (CWEN), AES (AES).
• Regulated utilities (both halves) — bond-proxy income, ~3–4% yields, earnings that grow with invested capital. Exelon (EXC) is the closest thing to a pure "wires" play (transmission-and-distribution only after spinning off its generation in 2022; ~10 million customers, ~$68 B rate base) [22]. Fortis (FTS) is the most concentrated transmission exposure through its 80.1% of ITC Holdings, the largest U.S. independent transmission company. Southern (SO), Duke (DUK), Dominion (D), American Electric Power (AEP), Ameren, Xcel (XEL), and Edison International (EIX) own generation and wires across both children at once.

There is no pure-play exchange-traded fund (ETF) for either child; the broad utility funds (XLU, VPU) hold the whole chain mixed together, and the grid-equipment fund GRID captures the build-out through equipment makers and contractors [22].

Where private, government, and public-power value concentrates (not buyable on an exchange):

• Federal and public power — the largest owners of the hydro fleet (Army Corps of Engineers, Bureau of Reclamation), a big nuclear/gas/hydro owner (the federal Tennessee Valley Authority, TVA), the Power Marketing Administrations (Bonneville, Western/Southwestern/Southeastern), and large municipal systems (LADWP, Salt River Project, CPS Energy, SMUD). On the wires side, ~830 distribution cooperatives own ~42% of U.S. distribution lines [9]. Investors reach all of these only through municipal and cooperative bonds, not equity [7][8][9].
• Private infrastructure and private equity — the natural owners of merchant generation and of whole regulated utilities: LS Power, ArcLight, Energy Capital Partners, Brookfield, KKR, EQT, Macquarie, Stonepeak, Invenergy (largest private renewables developer), and infrastructure funds that have bought entire investor-owned utilities (El Paso Electric, Puget, the 2026 Cleco deal) [22]. Private capital has been the buyer in the sector's biggest recent deals — Constellation/Calpine (~$26.6 B), NRG's ~13 GW gas purchase from LS Power (~$12 B), and Brookfield's 49.9% of FirstEnergy Transmission (~36× trailing earnings) [22].

The pattern across the whole group: the public-equity universe is essentially the investor-owned segment of each child, and even there it is diversified rather than pure. The government, municipal, and cooperative owners — a minority of generation and transmission, a majority-by-count of distribution — offer no common stock and are reached only through debt and the equipment-and-contractor supply chain (Quanta Services, MYR Group, MasTec, Eaton, Hubbell, GE Vernova), which captures the build spend regardless of who owns the asset.

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5. How the money works — one shared model, one extra engine

The shared engine (both children): rate base × allowed return. Wherever an asset — a generating plant, a transmission line, a distribution grid — sits inside a regulated utility, a regulator approves a revenue requirement:

(rate base × allowed return) + operating costs + depreciation + taxes.

Rate base is the utility's prudent invested capital (net of depreciation); the allowed return blends the cost of debt with an allowed return on equity (ROE) on the equity-funded slice. Because the owner earns a return on the asset base, the growth algorithm is identical across the whole chain: build more approved plant or wire → grow rate base → grow earnings. Owners are paid for prudent investment, not for throughput. Recent allowed ROEs cluster near 9.5–10% in both children — FERC transmission base ROEs around 9.5–10% plus incentive adders, and state-set distribution ROEs averaging ~9.7% in 2024 [20]. The shared catches are also identical: returns are capped, the utility must actually spend to grow, there is regulatory lag before rate relief arrives, and a commission can disallow imprudent costs (Plant Vogtle's nuclear build ballooned from ~$14 B to ~$35–37 B, and shareholders absorbed part of it) [22].

The extra engine (generation only): the competitive / merchant model. This is what the wires do not have. Uncontracted power plants sell into wholesale markets run by regional grid operators, earning a stack of revenue: energy ($/MWh), capacity payments (getting paid to be available), ancillary services, renewable energy credits, and long-term power-purchase agreements (PPAs) — increasingly signed directly with data-center operators. The single biggest recent development is the capacity-price surge: in PJM (the largest market), the capacity price jumped from $28.92 to $269.92 per megawatt-day for 2025/26 and hit the $325 cap for 2028/29 — worth the most to already-built, dispatchable capacity like gas and nuclear [17]. This is where the group's volatility and its sharpest recent upside both live. The wires have no equivalent — their only uncapped adjacency is generation owned by the same parent, or, in transmission, a small slice of merchant high-voltage lines that take market risk instead of a regulated return.

The shared cost signature: capital everywhere, fuel in one place. Both children are capital-is-the-business — you spend up front to build, then earn a return on the asset for decades. That makes the whole group interest-rate-sensitive: higher rates raise the cost of the capital that is the business and compress every valuation, in both children at once. The difference is fuel: most generation (all but fossil and biomass) and all of the wires have near-zero fuel cost, so the group's commodity exposure is concentrated in the fossil-generation slice.

The tax-credit lever flows to generation, not to the wires. The 2022 Inflation Reduction Act's technology-neutral clean-electricity credits — the Section 45Y production credit and Section 48E investment credit (up to 1.5¢/kWh or 30% of cost), plus the Section 45U nuclear credit — subsidize generation and storage, and are transferable for cash [18]. They do not flow to the poles-and-wires network; the wires benefit only indirectly, by making the remote renewables that need new lines financeable. And within generation the 2025 budget law (the One Big Beautiful Bill Act) split the fuels apart: wind and solar face a construction-start cliff around July 2026, while hydro, geothermal, nuclear, and storage keep full eligibility through ~2033 [18]. So the single sharpest policy fault line in the group runs inside the generation child — the wires are largely insulated from it.

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6. Demand drivers

The same historic tailwind lifts both halves of the chain: after roughly 15 years of flat U.S. electricity demand, load is inflecting up — the change that re-rated much of the group since 2024. The drivers are shared, but each half must respond differently.

• Data centers and artificial intelligence (AI) — the dominant new driver. Lawrence Berkeley National Laboratory estimates data centers used ~4.4% of U.S. electricity in 2023, rising toward 6.7–12% by 2028 [13]. Generation must add capacity and firm (around-the-clock) power to serve it; the wires must add transmission and distribution to connect and deliver it. The North American Electric Reliability Corporation (NERC) now forecasts summer peak demand rising ~224 GW (~24%) over ten years, ~90 GW of it data centers [14].
• Broad demand growth, electrification, and reshoring — electric vehicles, heat pumps, and new chip/battery factories add large concentrated loads; EIA projects generating capacity must grow substantially through 2050 to meet load and replace retirements.
• Connecting new supply. Interconnection queues held roughly 2,060 GW of proposed generation and storage at end-2025, much of it far from load — a demand driver specific to the wires, which must be built to reach it [15].
• Aging assets. More than 70% of transmission lines are over 25 years old, with parallel replacement cycles in distribution and in the generating fleet — a baseline of spending that continues even if load growth disappoints [23].

Where the emphasis differs: generation's incremental demand is about which fuel fills the gap (favoring firm, dispatchable sources — gas, nuclear, geothermal, hydro, storage — for 24/7 loads); the wires' incremental demand is about building the network to move and deliver it, largely fuel-agnostic. The shared counter-force: some data-center load may be delayed or double-counted (one analysis flags possible ~40% over-statement), so both halves face the risk of building ahead of demand that never arrives.

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7. Regulation

Regulation is the business model, and the group's defining regulatory fact is a clean split between a federal layer and a state layer — with fuel-specific regulators bolted onto the generation half.

• The Federal Energy Regulatory Commission (FERC) governs the wholesale and interstate layer: wholesale power markets, the capacity auctions that now drive merchant generation economics, interstate transmission rates and returns, and grid interconnection — the binding constraint on connecting new generation. Its recent transmission actions (Order No. 1920 on long-term planning, Order No. 2023 on interconnection reform) shape the wires' build-out; a FERC move on transmission ROE moves the whole transmission sector at once [16].
• State public utility commissions (PUCs) govern the retail layer: they set rate base, allowed ROE, and cost recovery for regulated distribution and for regulated generation, and they control transmission siting — the routing, rights-of-way, and permits that make transmission's dominant risk a timeline risk (major lines average ~10 years to build) [20].
• Fuel-specific regulators attach only to the generation child: the Nuclear Regulatory Commission (NRC) licenses reactors (the moat and the main cost center for nuclear); the Environmental Protection Agency (EPA) is the swing regulator for fossil generation; the Treasury/IRS administers the clean-electricity tax credits that reshape which fuels get built [18][19]. None of these touch the wires.

The through-line: the wires answer mainly to FERC (transmission) and state PUCs (distribution) on rate-and-return terms; generation answers to that same rate-and-return machinery plus a wholesale-market regulator plus a stack of fuel-specific agencies. The generation half is simply the more heavily and variably regulated of the two.

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8. Consolidation

The group is fragmented at the rollup (HHI 186) but consolidating within its most valuable segments [2], and the pattern differs by child.

• In generation, the wave is merchant scale-up in gas and nuclear. Constellation bought Calpine (~55 GW combined), NRG bought ~13 GW of gas from LS Power, and Talen and others are racing to own existing, interconnected, dispatchable capacity ahead of data-center load and record capacity prices — because new turbines and reactors face multi-year backlogs, and hydro's best sites were dammed decades ago [22]. Competition here is a race to own and extend scarce existing assets.
• In the wires, consolidation is quieter and structured around regulation. Transmission consolidates through minority stakes and joint ventures (Fortis/ITC with Singapore's GIC, Brookfield's 49.9% of FirstEnergy Transmission) that draw lighter merger review; distribution consolidates through holding-company mergers and whole-utility buyouts by infrastructure funds (El Paso Electric, Puget, Cleco), each needing state-PUC approval [22]. The countertrend is structural separation — Exelon spun off its generation to become a pure-wires company, reflecting investor demand for the lower-risk toll-road profile.

Across both children, a handful of engineering-and-construction and equipment specialists (Quanta, MYR, MasTec, Eaton, Hubbell, GE Vernova) capture much of the build spend regardless of who owns the asset — the one place the two halves' consolidation waves converge.

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9. Risks

Shared across the whole chain:

1. Demand-forecast / stranded-asset risk — the biggest two-sided factor. The re-rating of the entire group rests on data-center load landing near consensus. If AI demand disappoints, is delayed, or was double-counted, merchant generation valuations unwind and utilities that built wires ahead of load face disallowances.
2. Interest rates. Both children are capital-is-the-business, so higher rates directly compress valuations and acquisition values across the group. Judge growth per share, not just aggregate capital spending.
3. Affordability backlash. Record capital spending on both plants and wires pushes bills up, inviting rate freezes and adverse rate cases — and political pushback on the very capacity-price surge that is boosting merchant generation.
4. Supply chain and cyber. Large power transformers carry 36-month-plus lead times and are largely imported; substations and control centers are high-consequence security targets [24].

Concentrated in generation (the make half):

5. Commodity and merchant volatility — energy prices, capacity-price swings, and fuel spreads inject earnings swings the wires are shielded from.
6. Tax-credit and policy contingency — the 2026–27 wind/solar cliff, EPA's fossil-rule whiplash, and 45U's 2032 expiry are all live inside this child.
7. Fuel-specific tails — nuclear new-build overruns and outages, coal stranding, hydrology/drought, interconnection queues, and battery-safety risk.

Concentrated in the wires (the move-and-deliver half):

8. Wildfire and catastrophic liability — the group's defining tail risk, unique to distribution. Under doctrines such as California's inverse condemnation, a utility can be liable for fire damage even without negligence. PG&E filed for Chapter 11 in 2019 and settled wildfire claims for $25.5 billion, and Southern California Edison carries material exposure from the January 2025 Eaton Fire [21]. A single event can impair a company overnight — a risk generation does not carry to the same degree.
9. Siting and permitting — the dominant transmission risk. Major lines average ~10 years to permit and build; one contested county can stall a multi-state project. This is a timeline risk, not a demand risk .

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10. How to invest & outlook

Read the group as a barbell across the make/move divide, not as one "utilities" bloc.

• The wires (22112) are the lower-variance way to own rising electricity demand. They are regulated toll roads — bond-like, inflation-linked, monopoly cash flows with a built-in growth kicker, and largely indifferent to which fuel wins. They carry the group's one company-ending tail risk (wildfire liability in distribution, to be underwritten name by name) and a timeline constraint (siting in transmission), but not commodity risk. This is the "picks-and-shovels" exposure to the whole load wave.
• Generation (22111) is the higher-variance way — torque, commodity, and policy in one. It offers the sharpest upside (merchant gas and nuclear riding record capacity prices; solar, wind, and storage riding the transition) and the sharpest risks (commodity volatility, the 2026–27 tax-credit cliff, fuel-specific tails). Within it, the durable thesis is the scarcity and rising value of firm, already-built, dispatchable capacity meeting suddenly-rising load.

Which parts are attractive vs. at risk (analytical judgment, grounded in the sourced facts):

• Attractive now: the wires as a whole, riding a decade-plus capital supercycle with transmission the fastest-growing, lower-risk rate base (Exelon for near-pure distribution, Fortis/ITC and AEP for transmission); and within generation, owners of existing, dispatchable capacity — merchant gas and nuclear (Constellation, Vistra, Talen, NRG) plus firm-clean hydro, geothermal, and storage whose tax credits are preserved to ~2033.
• At risk / two-sided: wind and solar carry the strongest demand tailwind but the sharpest policy cliff (underwrite the construction-start date); coal and biomass are managed runoff; and any utility on either side that builds too far ahead of data-center load that never materializes faces disallowance.

How to get in. Public-market investors choose a profile, not a code: near-pure wires (EXC) or transmission (FTS, AEP) for bond-proxy income with a grid-growth kicker; merchant IPPs (CEG, VST, TLN, NRG) for torque to load growth and capacity prices; renewable platforms (NEE, BEP/BEPC, CWEN) for contracted income with transition upside; broad utility ETFs (XLU) for the whole chain mixed; and the contractors and equipment makers (Quanta, MYR, Eaton, GE Vernova) for the build spend without the regulated-return ceiling. Private investors buy the assets the way the industry is actually owned: whole regulated utilities and minority transco stakes (bond-like, premium multiples), operating and development project equity in generation, tax-equity and transferable-credit purchases, merchant lines and merchant plants (highest upside, most binary), and public-power municipal and cooperative bonds for the government-owned hydro, nuclear, and distribution fleets.

Outlook. After a lost decade of flat demand, U.S. electric power as a whole has moved from managed maturity to a demand-led expansion — and for the first time in a generation, both halves of the chain need a wave of new capital. Investor-owned utilities plan more than $1.1 trillion of capital spending across 2025–2029, with distribution the largest single bucket and transmission the fastest-growing [11]. The single variable that matters most for the whole group is whether data-center demand lands near consensus. Given that uncertainty, the cleanest framing is the make/move split itself: the wires are how you own the rising tide with the least variance; generation is how you own it with the most torque — and the most policy and commodity risk.

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Sources

1. U.S. Census Bureau, 2022 NAICS — Sector 22 (Utilities), Industry Group 2211 (Electric Power Generation, Transmission and Distribution) and its two 5-digit industries 22111 and 22112. https://www.census.gov/naics/?input=2211&year=2022
2. U.S. Census Bureau, 2022 Economic Census — Summary Statistics and Concentration Ratios, NAICS 2211 (receipts $563,323,475 thousand; 2,626 firms; CR4 17.7% / CR8 29.6% / CR20 54.2% / CR50 74.4%; HHI 186). Histometrics ingested ground-truth statistics. https://data.census.gov/table/ECNBASIC2022.EC2200BASIC
3. U.S. Census Bureau, 2023 County Business Patterns, NAICS 2211 (12,735 establishments; 519,711 employees; annual payroll $69,270,756 thousand; first-quarter payroll $21,309,294 thousand). Histometrics ingested ground-truth statistics. https://www.census.gov/programs-surveys/cbp.html
4. U.S. Census Bureau, 2022 Economic Census and 2023 County Business Patterns, child industries NAICS 22111 and 22112 — generation receipts $146.3 B / 134,570 employees / 1,228 firms / HHI 274.4; transmission-and-distribution receipts $417.0 B / 385,141 employees / 1,475 firms / HHI 206.6. Histometrics ingested ground-truth statistics; children reconcile to the 2211 rollup [2][3].
5. U.S. Census Bureau, Understanding NAICS and Economic Census Coverage (government-owned establishments generally excluded from business statistics), 2022. https://www.census.gov/programs-surveys/economic-census/year/2022/guidance/understanding-naics.html
6. U.S. Energy Information Administration (EIA), Electric Power Annual 2024 (U.S. capacity ~1,230 GW; generation ~4,300 TWh; retail electricity market ~$514 B in 2024). https://www.eia.gov/electricity/annual/
7. U.S. Department of Energy (DOE) / Oak Ridge National Laboratory, U.S. Hydropower Market Report and U.S. Nuclear Plant Ownership (hydro ~73% federal + public; ~⅕ of nuclear public/federal, led by TVA). https://www.energy.gov/eere/water/hydropower-market-report
8. American Public Power Association, Public Power Statistical Report and EIA-860 ownership data (investor-owned utilities serve ~72% of distribution customers but are ~5% of utilities; municipal ~15% of customers). https://www.publicpower.org/public-power/stats-and-facts
9. National Rural Electric Cooperative Association, Electric Cooperative Facts & Figures (~830 distribution cooperatives; ~42% of U.S. distribution lines; 56% of U.S. land area). https://www.electric.coop/electric-cooperative-fact-sheet
10. DOE, Quadrennial Energy Review, Appendix C: Electricity — transmission ownership ~66% investor-owned, 2015. https://www.energy.gov/documents/qerappendixcelectricitypdf
11. Edison Electric Institute (EEI), Industry Capital Expenditures and 2024 Financial Review — transmission ~$32.6 B and distribution ~$60.2 B (2024); record $204.1 B total IOU capex; >$1.1 trillion planned 2025–2029. https://www.eei.org/resources-and-media/industry-data
12. DOE, National Transmission Needs Study — roughly double within-region and >5× interregional transfer capacity by 2035, 2023. https://www.energy.gov/gdo/national-transmission-needs-study
13. Lawrence Berkeley National Laboratory, United States Data Center Energy Usage Report (4.4% of U.S. electricity in 2023; 6.7–12% by 2028), 2024. https://emp.lbl.gov/publications/united-states-data-center-energy
14. North American Electric Reliability Corporation (NERC), 2025 Long-Term Reliability Assessment (peak demand +224 GW / ~24% over 10 years; ~90 GW data centers). https://www.nerc.com/
15. Lawrence Berkeley National Laboratory, Queued Up (end-2025 interconnection queue ~2,060 GW). https://emp.lbl.gov/queues
16. Federal Energy Regulatory Commission (FERC), Order No. 1920 (transmission planning, 2024), Order No. 2023 (interconnection, 2023), Order No. 1000 (2011), formula rates and capacity markets. https://www.ferc.gov/electric-power-markets
17. PJM Interconnection, Reliability Pricing Model / Capacity Auction Results (2024/25 $28.92 → 2025/26 $269.92 → 2028/29 $325.00/MW-day cap). https://www.pjm.com/markets-and-operations/rpm
18. Internal Revenue Service, Clean Electricity Production Credit (§45Y), Investment Credit (§48E), Zero-Emission Nuclear Credit (§45U), and transferability/elective pay; and U.S. Public Law 119-21 (One Big Beautiful Bill Act, 2025) wind/solar construction-start cliff. https://www.irs.gov/credits-deductions/clean-electricity-production-credit
19. U.S. Nuclear Regulatory Commission (NRC), reactor licensing and oversight. https://www.nrc.gov/
20. S&P Global Market Intelligence / Regulatory Research Associates and RTO Insider — average authorized electric distribution ROE ~9.7% (2024), ~58% of requested increases approved; FERC transmission base ROEs ~9.5–10% plus incentive adders. https://www.spglobal.com/market-intelligence/
21. PG&E Corporation Chapter 11 (2019, $25.5 B wildfire resolution); Edison International / Southern California Edison, Eaton Fire exposure (SEC filings). https://www.sec.gov/
22. Company disclosures and transactions underlying the child primers — Constellation/Calpine (~$26.6 B), NRG/LS Power (~$12 B), Exelon generation spin-off (2022), Fortis/ITC, Brookfield/FirstEnergy Transmission (~36× earnings), NextEra, Brookfield Renewable, Vistra, Talen (SEC filings; corporate newsrooms), 2022–2026. https://www.sec.gov/
23. Congressional Research Service, Introduction to Electricity Transmission (IF12253) — ~600,000 miles of transmission line, 70%+ over 25 years old; ~5.5 million distribution line-miles; ~180 million poles. https://www.congress.gov/crs-product/IF12253
24. DOE, Large Power Transformer Resilience Report (36+ month lead times; 80%+ imported) and supply-chain analysis, 2024. https://www.energy.gov/

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Prepared July 2026. Core NAICS 2211 business statistics (receipts, firms, establishments, employment, payroll, concentration) are Histometrics-ingested U.S. Census figures and take precedence over third-party estimates; the two child industries (22111 generation, 22112 transmission-and-distribution) reconcile to this rollup on revenue, establishments, employment, and payroll, with the firm count slightly lower than the children summed because vertically integrated owners are counted once. Physical scale, ownership mix, capital-spending, tax, and market figures are drawn from EIA, DOE, EEI, LBNL, NERC, FERC, IRS, and company filings via the two child primers, with reference years noted. Where government / municipal / cooperative ownership dominates (hydro and part of nuclear in generation; municipal and cooperative distribution in the wires), federal business statistics undercount the true industry; and because distribution receipts embed the retail value of energy that generation also books at wholesale, the $563 billion total is receipts as reported, not the sector's value added. Both points are stated rather than estimated around. Forward-looking statements in §10 are analytical judgments, not guarantees.