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Start by identifying the generator and the pollutant you need to reduce. Natural-gas engines and combustion turbines have different requirements, and lowering local air pollution such as NOx is not the same as cutting greenhouse-gas emissions. A practical plan combines an equipment-specific baseline, careful operating decisions, compatible emissions controls, useful heat recovery where the site can use it, and review of the current permit and rules.
First, separate local air pollution from greenhouse gases
“Generator emissions” can mean several different things. Natural-gas combustion releases carbon dioxide (CO₂), a greenhouse gas. It can also release local air pollutants, including nitrogen oxides (NOx), carbon monoxide (CO), and volatile organic compounds (VOCs). Reciprocating engines may also be subject to requirements addressing hazardous air pollutants (HAPs). The pollutants regulated and the controls that apply depend on the source category and site.
A measure can improve one outcome without producing an equivalent improvement in another. For example, a control aimed at NOx should not be described as a greenhouse-gas reduction unless the CO₂ or CO₂-equivalent effect has also been established. When comparing options, state whether the figure is for direct on-site emissions or for a broader comparison that includes displaced grid electricity and useful heat.
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Inventory units individually rather than treating a data center’s generators as one interchangeable fleet. The U.S. Environmental Protection Agency (EPA) distinguishes stationary spark-ignition engines from stationary combustion turbines and links each category to separate air rules. The unit’s role matters too: emergency backup, demand response, peak shaving, and continuous primary generation are not equivalent operating cases.
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Record equipment, duty, and controls
- Generator type, manufacturer, model, rated output, age, and installation or modification date.
- Fuel and any approved fuel blends; emergency, standby, peak-shaving, demand-response, or primary-power duty.
- Annual runtime, typical load, starts, testing, and any relevant startup, shutdown, or abnormal-operation assumptions.
- Existing combustion settings, emissions-control equipment, maintenance condition, and monitoring or reporting obligations.
- Applicable federal requirements, state and local permit conditions, and any operating limits.
Keep local pollutants and greenhouse gases in separate records, using the measurement methods and reporting boundaries required by the applicable permit and rules. For a greenhouse-gas comparison involving combined heat and power (CHP), specify whether you are counting direct combustion alone or comparing CHP with separate grid electricity and boiler heat. EPA’s April 2022 CHP analysis used 2019 marginal-grid emissions estimates; it cautions that results change with grid emissions and the amount of heat actually used.
Reduce avoidable fuel use without compromising readiness
Fuel burned generally means on-site combustion emissions, so dispatch and maintenance are worth examining. With reliability, engineering, and permit requirements in view, operators can avoid running units when their power is not needed, assess whether the fleet is appropriately sized for its actual loads, and identify degraded performance through maintenance. Measure the effect at the site; the EPA materials cited here do not establish a universal emissions-reduction percentage for these operational changes.
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Do not curtail required emergency readiness, skip required testing, or operate outside permit terms to reduce runtime. For emergency generators, distinguish permitted emergency and maintenance/testing use from non-emergency generation. EPA’s September 6, 1995 memorandum says 500 hours is an appropriate default assumption when estimating worst-case annual operating hours for potential-to-emit (PTE) calculations. It is guidance for that estimation purpose—not a general authorization to operate for 500 hours. The memorandum excludes peaking units and standby units operating while utility power is available, and allows case-specific estimates where justified. Check the current permit and applicable requirements for the site.
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Controls must match the unit, the pollutant limit, and the operating conditions. A technology suitable for one engine or turbine is not automatically suitable for another, and a control choice may affect operating requirements and maintenance.
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Stationary combustion turbines
EPA identifies NOx and sulfur dioxide (SO₂) as key pollutants for stationary combustion turbines. EPA’s turbine standards overview describes combustion controls and selective catalytic reduction (SCR) as technologies underlying proposed NOx limits. Those references make them options to evaluate, not a promise that a particular installation will achieve a specific reduction. Ask the equipment supplier and air-permit engineer to assess compatibility with the turbine, fuel, exhaust conditions, load range, applicable limits, and permit.
Stationary spark-ignition engines
EPA identifies NOx, CO, and VOC as key pollutants for stationary spark-ignition engines. The relevant new source performance standards are in 40 CFR Part 60, Subpart JJJJ. Reciprocating internal combustion engine hazardous-air-pollutant requirements are in 40 CFR Part 63, Subpart ZZZZ. The applicable rule and control train depend on the source and its circumstances; the cited EPA materials do not establish one retrofit or reduction rate for every natural-gas engine.
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Verify the current rule and permit
EPA’s Clean Air Act resources for data centers explain that applicable standards can cover stationary engines and turbines used for primary or backup power, while state and local agencies issue most air permits. As of October 9, 2026, EPA’s turbine standards page listed a January 15, 2026 final rule for Subpart KKKKa and a July 16, 2026 correction. EPA’s spark-ignition engine and RICE overview pages listed the August 30, 2024 final rule and were marked updated March 30, 2026. These page histories are not a substitute for checking current rule text, notices, state or local implementation, and the site’s permit. Applicability depends on equipment facts and jurisdiction.
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Use CHP only when the site can use the recovered heat
CHP generates electricity with an engine or turbine and captures heat that would otherwise be wasted, typically for useful hot water or steam. At a data center, assess whether there is a dependable thermal load that coincides with generation, or a practical application such as absorption cooling. If recovered heat has no useful destination, the expected efficiency and emissions benefit can shrink.
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EPA’s CHP overview gives typical total system efficiency of 65–80%; its April 2022 analysis describes typical CHP systems as achieving 60–80% when they capture and use otherwise-wasted heat. These are EPA-wide typical ranges, not a guaranteed efficiency for a data-center installation. EPA’s overview also illustrates a conventional 1 MW CHP comparison with about half the annual CO₂ of separate heat and grid power—4,200 versus 8,300 tons. That illustration depends on its assumptions and boundary; it should not be applied to a site without checking actual heat use and displaced electricity.
The April 2022 EPA analysis assessed a 100 kW engine, a 200 kW microturbine, a 1 MW engine, and a 7.5 MW gas turbine, comparing CHP with separate heat and power using 2019 marginal-grid emissions estimates. The analyzed 100 kW and 1 MW engine cases reduced CO₂ versus the separate-production comparison in all scenarios studied. The microturbine and larger turbine results were more conditional in some low-load or low-heat-use cases. The analysis assumed avoided boiler emissions and notes that customers whose electricity is attributable to renewable generation would not reduce emissions through CHP in that comparison. These modeled results are not predictions for an individual data center.
Assess alternative fuels as site-specific projects
EPA describes renewable natural gas (RNG) as biogas captured and treated to have the same composition as natural gas, and discusses RNG and green hydrogen as potential CHP fuel pathways. EPA also says near-term CHP use of RNG and green hydrogen is expected to be limited and that applicability varies by technology. Before relying on either, verify supply and fuel composition, equipment compatibility, safety requirements, and permit implications. Do not assume an existing generator can use a fuel blend without modifications or review.
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When evaluating dispatch changes, controls, CHP, or fuel alternatives, require each proposal to state the same operating scenario and emissions boundary. A useful comparison separates pollutant results from implementation and compliance questions:
| Comparison area | What to establish |
|---|---|
| Pollutants | Separate expected NOx, CO, VOC, HAP, and CO₂ or CO₂e outcomes. Identify the measurement boundary and method. |
| Equipment fit | Engine or turbine type, model, age, fuel, load range, exhaust conditions, and control compatibility. |
| Duty and reliability | Emergency versus primary use, runtime and testing needs, redundancy, and permit limits. |
| Energy and fuel boundary | Direct on-site emissions versus grid displacement; verified fuel supply; and the quantity and timing of useful heat. |
| Compliance | Applicable federal standards, state and local permit conditions, construction or modification date, and monitoring or reporting requirements. |
| Project evidence | Installed and operating costs, maintenance, expected utilization, and carbon-accounting assumptions for the actual site. The EPA materials cited here do not provide project-specific cost estimates. |
Make the decision from site evidence
There is no single control, retrofit, operating-hours target, or emissions-reduction percentage that applies to every natural-gas data-center generator. Select measures only after establishing the unit’s category, duty, pollutant target, and permit conditions. Have qualified equipment and permitting specialists verify proposed controls and operating changes, and evaluate CHP or alternative fuels against the site’s real loads, supply, and emissions accounting.
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