The Clean Cloud Act amends the Clean Air Act to require owners of data centers and cryptomining facilities with more than 100 kW of IT nameplate power to report detailed electricity consumption and source information to EPA and the Energy Information Administration annually. EPA will calculate each covered facility’s greenhouse‑gas (GHG) intensity (tCO2e/kWh) and publish facility‑level summaries, while some granular consumption figures are treated as confidential business information.
If a facility’s grid‑sourced or behind‑the‑meter electricity GHG intensity exceeds a regionally set baseline, the bill imposes monetized fees tied to the excess emissions. Baselines are published for 2026, decline by 11% of the 2026 baseline annually through 2034, and drop to zero in 2035.
Fee proceeds fund program administration (3%), consumer energy cost relief (25%), and grants/loans for zero‑carbon firm generation and long‑duration storage (70%), with grant conditions and clawback authority.
At a Glance
What It Does
Requires annual reporting from covered facilities and utilities to EPA and EIA on location, ownership, total electricity use, behind‑the‑meter generation, and contractual procurement. EPA uses those data to compute facility GHG intensity and levies fees when intensity exceeds region baselines; fees are assessed on utilities for grid-supplied electricity and directly on owners for behind‑the‑meter generation.
Who It Affects
Applies to any U.S. data center or cryptomining facility with >100 kW of IT nameplate power, their owners and tenants, electric utilities that serve them, developers of on‑site generation, and firms that sell or claim energy attribute certificates or power purchase agreements tied to those facilities.
Why It Matters
This is a sector‑specific federal mechanism that translates electricity emission intensity into dollars, accelerating demand for zero‑carbon 'firm' power and long‑duration storage and reshaping how PPAs, EACs, and behind‑the‑meter generation are treated for compliance and public disclosure.
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What This Bill Actually Does
The bill creates a new Section 139 in the Clean Air Act that focuses on emissions tied to power consumption by data centers and cryptomining facilities. It defines covered facilities as those with more than 100 kilowatts of installed IT nameplate power and directs EPA, working with the Energy Information Administration (EIA), to collect annual, facility‑level data: location (including balancing authority), whether the site is a data center or cryptominer, ownership, the utility provider, total annual electricity use, generation behind the meter, the fuel mix for both grid and behind‑the‑meter supply (subject to verification rules), and contract terms such as PPAs.
Certain detailed consumption figures are treated as confidential business information unless otherwise required public.
EPA and EIA must convert reported power mixes into greenhouse‑gas intensities expressed in metric tons of CO2e per kWh. For methane the bill requires EPA to use the 20‑year GWP from the IPCC Sixth Assessment Report, which raises the relative weight of methane emissions in the intensity calculations.
EPA must publish regional baseline intensities (using the DOE’s 2023 National Transmission Needs Study regions) by December 31, 2025; that baseline becomes the 2026 benchmark and is reduced by an amount equal to 11 percent of the 2026 baseline each year from 2027 through 2034, reaching zero in 2035.The bill establishes a two‑track fee regime. For electricity drawn from the grid, EPA assesses a fee on the owner of the serving electric utility; for electricity produced behind the meter, EPA assesses the fee directly on the covered facility owner.
The statutory formula multiplies the facility’s relevant annual kWh by a per‑unit amount (initially $20) and by the gap between the facility’s GHG intensity and the regional baseline. The $20 per‑unit figure is indexed annually beginning in 2027 by inflation plus an additional $10.
EPA must notify affected utilities and facility owners of assessed fees by January 31 each year and collect payments by March 31 of the following year. Utilities may not pass fees through to non‑covered customers; EPA and EIA will monitor compliance and EPA can fine utilities equal to twice any improperly recovered amounts.The bill tightly constrains how owners can claim low‑carbon electricity for the purpose of avoiding fees.
Power purchase agreements, EAC retirements, or behind‑the‑meter claims count toward a facility’s low‑carbon share only if they satisfy a series of conditions: timing (new assets or upgrades within 36 months of starting facility operations, or grandfathered contracts finalized before enactment), temporal matching (same calendar year for generation before 2028; same hour or stored energy serving the facility after 2027), regional interconnection or demonstrable physical delivery, and exclusive retirement of EACs. These provisions are intended to prevent counting of older or displaced renewable generation as incremental decarbonization.Fee proceeds are appropriated annually with a fixed split: 3% for program administration, 25% for grants to states, tribes, municipalities and utilities to offset residential electricity cost impacts, and 70% for awards (grants, rebates, AMC, or low‑interest loans) to support zero‑carbon generation that can operate year‑round at >70% capacity factor or long‑duration storage that can discharge at rated power for at least 10 hours.
Recipients of clean‑firm awards must certify that utilities selling the asset’s power will offer customers a voluntary higher‑rate product sourced from the zero‑carbon asset and use the additional revenue exclusively to finance those assets; EPA can claw back awards if recipients breach those certifications. The statute also clarifies leased spaces: tenants are treated as facility owners for covered leased spaces and leased spaces are standalone covered facilities when they meet the threshold.
The Five Things You Need to Know
Coverage threshold: any data center or cryptomining facility with more than 100 kilowatts of installed IT nameplate power becomes a 'covered facility' subject to reporting and fees.
Baseline glidepath: EPA must publish regional baselines by Dec 31, 2025; for 2027–2034 each year’s baseline is the prior year’s baseline reduced by 11% of the 2026 baseline; baselines become 0 tCO2e/kWh in 2035.
Fee formula: for each covered facility the statute computes fees as (relevant annual kWh) × ($20, indexed annually after 2026) × (facility GHG intensity tCO2e/kWh above the regional baseline).
Temporal and delivery tests for claimed low‑carbon power: PPA/EAC claims count only if they meet timing (36‑month/new capacity or grandfathered contracts), same‑year (pre‑2028) or same‑hour (post‑2027) matching, regional interconnection or physical delivery, and exclusive EAC retirement.
Allocation of receipts: collected fees are split annually—3% for administration, 25% for consumer energy cost relief grants, and 70% for awards to deploy zero‑carbon firm generation (>70% capacity factor) and long‑duration (≥10‑hour) storage, with certification and clawback conditions.
Section-by-Section Breakdown
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Scope and definitions
This subsection defines the new regime’s vocabulary: 'covered facility' (>100 kW IT nameplate), 'cryptomining facility' (standalone or within structures with environmental controls), 'data center' (EISA definition), 'electric utility' (FPA definition), and 'region' (DOE National Transmission Needs Study regions). The practical effect is to target a broad set of commercial compute and mining operations while tying implementation to existing federal definitions and DOE regional mapping, which will matter for data mapping, regulatory jurisdiction, and how owners classify assets.
Annual facility and utility reporting to EPA and EIA
EPA, with EIA, must collect a specified dataset annually from facility owners and utilities: location, ownership, total and behind‑the‑meter electricity consumption, fuel‑mix percentages, and contractual procurement terms. The statute treats detailed kWh numbers and behind‑meter consumption as confidential business information except for items EPA must publish; EPA and EIA must reconcile utility and owner reports. This establishes a continuous, centralized transparency database that will underpin fee calculations, compliance monitoring, and public disclosure of published intensity metrics.
Verification rules for claimed low‑carbon supply and behind‑the‑meter generation
The bill imposes tight tests for counting PPAs, EACs, and on‑site generation as low‑carbon supply: assets must generally be new or recently uprated (36‑month window), avoid double‑claiming via exclusive EAC retirement, be physically deliverable or in the same balancing area, and—critically—match temporally (same calendar year before 2028; same hour or via storage after 2027). For behind‑the‑meter generation EPA also may exclude high‑intensity sources; these mechanics are intended to limit 'accounting tricks' and incentivize genuinely incremental clean capacity and hourly matching.
GHG intensity calculation and public reporting
Using reported fuel‑mix data and the 20‑year methane GWP from the IPCC AR6, EPA will compute each facility’s grid‑sourced and behind‑meter GHG intensity (tCO2e/kWh) and publish, annually, facility‑level summaries: identity, ownership, percent by source, and the intensity metric. Owners’ aggregate consumption is also published. Certain raw consumption figures remain confidential. The publication creates reputational and procurement pressure and supplies the inputs needed to determine fee liability.
Region baselines, fee assessment, indexing, and enforcement
EPA must publish per‑region baseline intensities by Dec 31, 2025; 2026 uses that baseline, which is then reduced annually by a fixed fraction and set to zero in 2035. Fees apply when a facility’s intensity exceeds the baseline: utilities are charged for grid‑sourced shortfalls and facility owners are charged for behind‑the‑meter shortfalls. The fee math multiplies kWh × a per‑unit dollar ($20 initially) × the emissions intensity gap; the $20 is increased annually by inflation plus $10 beginning in 2027. EPA notifies liable parties by Jan 31 and collects by March 31. Utilities may not pass fees through to non‑covered customers; EPA can fine twice the improperly recovered amount.
Use of proceeds, grant conditions, and leased spaces
Collected funds are divided: 3% to administer the program, 25% for grants to lower residential electricity costs, and 70% for awards supporting zero‑carbon firm generation (year‑round at >70% capacity factor) or long‑duration storage (≥10 hours). Grant recipients offering financed assets must certify that utilities will offer a voluntary premium rate product to support finance and that premium revenue will be used for those assets; EPA can claw back awards if certifications fail. The statute treats leased covered spaces as standalone facilities with tenants as owners, shifting reporting and fee responsibility onto tenants where applicable.
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Explore Environment in Codify Search →Who Benefits and Who Bears the Cost
Every bill creates winners and losers. Here's who stands to gain and who bears the cost.
Who Benefits
- Residential electricity consumers — stand to receive grants and rebates (via the 25% allocation) intended to offset higher retail costs resulting from increased large-scale electricity consumption by covered facilities.
- Developers of zero‑carbon 'clean firm' generation and long‑duration storage — will gain access to 70% of fee proceeds through grants, loans, or advanced market commitments tied to specific capacity and performance requirements.
- States, Indian Tribes, and municipalities — become grant recipients and partners for consumer relief and grid resilience projects, receiving targeted funding to cushion local impacts and finance clean capacity.
- Transparency and ESG purchasers — corporate buyers, investors, and procurement teams will benefit from standardized, federally published facility‑level intensity metrics to assess counterparty emissions and contractual claims.
Who Bears the Cost
- Owners of data centers and cryptomining facilities with on‑site fossil generation or high‑intensity grid footprints — face direct fees on behind‑the‑meter generation and indirect fees via utilities for grid consumption that exceeds regional baselines.
- Electric utilities serving covered facilities — must calculate and remit fees tied to served facilities’ grid emissions, monitor for improper pass‑through, and potentially face fines and administrative burdens; they also bear compliance costs tied to reporting.
- Operators and owners of behind‑the‑meter fossil plants and older PPAs — may lose the ability to count older generation toward decarbonization, faced with fee exposure unless they retrofit, retire, or reconfigure contracts to meet the bill’s temporal and delivery tests.
- Grant recipients and project developers — must meet strict certification and deployment conditions (capacity factors, discharge duration, and customer‑facing voluntary rates), and face clawbacks for noncompliance, shifting commercial risk onto applicants.
Key Issues
The Core Tension
The bill aims to force rapid decarbonization of compute‑intensive facilities by turning emission intensity into a recurring financial liability, but it balances two legitimate goals that pull in opposite directions: maximizing near‑term emissions reductions by forbidding accounting shortcuts and requiring hour‑level matching, versus preserving economically viable procurement options (older PPAs, EACs, and partially firm renewables) and minimizing electricity cost impacts on residential consumers and grid stability. The statute leans heavily toward strict attribution and aggressive baselines, creating very strong decarbonization pressure while leaving open difficult choices about enforcement, market adaptation, and fairness to existing contractual arrangements.
Implementation hinges on complex measurement and attribution rules that will determine whether contractual claims and behind‑meter generation truly represent incremental decarbonization. The bill’s 36‑month and hourly matching windows attempt to stop double‑counting and 'surplus' claims, but they will require EPA/EIA to adjudicate who owns the incremental emissions reductions in messy real‑world procurement markets.
The temporal matching requirement after 2027 (same‑hour for claimed deliveries) pushes purchasers toward storage‑paired or co‑located resources, but it also raises the administrative burden of hour‑level verification and may disadvantage smaller buyers unable to secure such products.
The fee design translates an emissions intensity gap into dollars via a somewhat unusual multiplication (kWh × dollar × tCO2e/kWh), which yields a dollar per ton equivalent. While administrable, it makes revenues highly sensitive to small changes in reported intensities and to the choice of methane GWP (the bill prescribes the 20‑year value).
The glidepath to zero by 2035 is aggressive: it effectively forces covered facilities to be supplied by zero‑carbon firm power or to pay increasingly large fees. That creates a strong market signal but also risks relocation of high‑intensity operations, accelerated hiring of marginal behind‑the‑meter fossil capacity, or legal and regulatory friction with state ratemaking and utility procurement frameworks.
Monitoring and enforcing the pass‑through prohibition will be technically and politically fraught; proving a utility 'recouped' a fee from non‑covered customers will require granular rate and revenue analyses.
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