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Set the boundary before calculating
First define the reporting entity, facilities, reporting period and organizational boundary. State whether the inventory uses an operational-control, financial-control or equity-share approach, and identify which emissions scopes it covers. The U.S. EPA’s Scopes 1 and 2 inventory guidance and emissions-source screening guidance provide a framework for identifying sources.
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- Scope 1: Direct emissions from sources the organization owns or controls, including fuel burned on site in generators, boilers or other equipment.
- Scope 2: Emissions associated with purchased electricity, steam, heat and cooling. Calculate these separately from on-site combustion.
- Scope 3: Other value-chain emissions, potentially including production, processing, transport and distribution of fuel. Include relevant categories according to the inventory’s purpose and available data.
Do not classify a fuel as Scope 1 merely because it is called renewable, or treat purchased electricity as part of the on-site combustion total. The boundary and the source of each activity determine where it is accounted for.
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For every fuel used during the reporting period, record the fuel type, quantity and units, the equipment that consumed it, the supplier or source, and any known blend or biogenic share. Reconcile fuel meters and invoices against generator, boiler or other equipment logs. Record purchased electricity and other purchased energy separately, along with the supplier or contractual attributes relevant to the chosen accounting method.
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EPA’s inventory guidance covers facility data collection, emissions-factor selection and calculation. If a fuel’s origin or blend is unknown, document that limitation rather than assuming its renewable share. Keep the records and unit conversions traceable so another reviewer can follow the estimate from source data to reported total.
Choose factors that match the fuel and site
Use current, fuel-specific factors that match the activity data, combustion technology, geography and reporting year. For each fuel and source, calculate CO2, CH4 and N2O separately, then convert the gases to CO2e using one stated global warming potential (GWP) basis. The Greenhouse Gas Protocol’s Stationary Combustion Guidance explains the relevant combustion gases and the role of activity data and emissions factors.
If a factor is expressed per unit of energy but the fuel was measured by volume or mass, convert using documented fuel properties or supplier data. Record the factor source and version, unit conversions, GWP basis and data quality. A generic “renewable fuel” factor is not adequate when the pathway and inventory treatment are unknown.
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Calculate on-site combustion emissions
Apply the calculation separately to each fuel, equipment source and reporting period:
Emissions of each gas (kg) = fuel consumed (activity units) × matching gas-specific emissions factor (kg gas per activity unit)
Combustion emissions (kg CO2e) = sum of [each gas in kg × the selected GWP for that gas]
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Keep fossil and biogenic fractions distinguishable when the fuel is blended or its origin is known. Aggregate the calculated sources only after applying the same stated GWP basis. This method produces an estimate tied to the site’s records and selected factors; it does not establish one universal emissions factor for renewable fuels.
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Under the cited GHG Protocol corporate inventory guidance, CO2 from biomass combustion is reported separately from the scopes as a memo item, while combustion CH4 and N2O are counted in Scope 1 for owned or controlled combustion. The Protocol states: “Unlike CO2 emissions, the combustion of biomass does in all cases result in net additions of CH4 and N2O to the atmosphere, and therefore emissions of these two greenhouse gases as a result of biomass combustion should be accounted for in emission inventories under Scope 1.” See the GHG Protocol Calculation Tools FAQ.
That accounting presentation does not mean the physical combustion releases no CO2. Biomass and biogas combustion release biogenic CO2 as well as CH4 and N2O; keep the biogenic CO2 visible and explain how it is treated instead of silently setting total fuel emissions to zero. Assess upstream fuel production, processing, transport and distribution separately under relevant Scope 3 categories when those categories are in the inventory and suitable data are available.
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Biomethane certificates introduce additional contractual accounting questions; do not assume a certificate by itself resolves how the fuel should be represented in an inventory. The GHG Protocol’s interim update on accounting for biomethane certificates addresses this issue. The lifecycle footprint also depends on the fuel pathway, feedstock or source, processing and distribution.
Calculate purchased electricity separately
Report location-based Scope 2 emissions using relevant grid-average data. Where applicable and supported by qualifying supplier or contractual instruments, also report market-based emissions. Label the methods separately: they answer different accounting questions and should not be blended into an unlabeled electricity figure. The GHG Protocol’s Scope 2 Guidance, Chapter 6 covers calculation, while Google Cloud’s data-center methodology illustrates the distinction between on-site fossil combustion sources, such as backup diesel and natural-gas heating, and clean-electricity matching.
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Present a result others can interpret
A useful estimate states its boundary, activity data and accounting choices alongside the total. Report:
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- Reporting entity, facilities, organizational boundary, reporting year and geography.
- Fuel types, quantities, units, known pathways or blends, and the equipment where each fuel was used.
- Emissions factors and versions, factor units and conversions, gases calculated, and GWP basis.
- How biogenic CO2 is presented, which scopes and Scope 3 categories are included, and any material data limitations.
- Location-based and, where applicable, market-based Scope 2 results as distinct totals.
- For an intensity metric, the exact denominator and how it was measured—for example, the activity or capacity basis used.
Comparisons between facilities or fuels are meaningful only when boundaries, reporting periods, fuel pathways, factor versions and methods are sufficiently consistent. The GHG Protocol’s Corporate Value Chain (Scope 3) Standard notes that additional measures are needed for valid comparisons. Its Scope 3 Evaluator is a free resource for broader value-chain estimation, not a replacement for the direct combustion calculation.
Why there is no single footprint number
A data center’s emissions cannot be calculated from the label “powered by renewable fuels” alone. The result depends on the facility’s measured fuel use, fuel pathway and blend, combustion equipment, electricity accounting, reporting boundary, jurisdiction and year. Without those inputs, a single number or universal factor would be misleading; the repeatable method is to disclose the assumptions and calculate each source using matching, documented data.
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