How Your Facility’s Energy Data Supports Scope 2 Emissions Reporting
Key takeaways
- Scope 2 emissions are the greenhouse gas emissions from purchased electricity, calculated by combining consumption with grid emissions factors.
- The GHG Protocol allows two reporting methods, location-based and market-based, and each requires different input data.
- Interval-level metering data is the foundation for accurate market-based reporting, hourly matching, and audit-ready documentation.
Scope 2 is the emissions category most facilities can control directly. Scope 1 is what your equipment burns. Scope 3 is your supply chain. Scope 2 is the electricity you buy, and every kilowatt-hour you consume carries a grid-average emissions footprint that shows up on your annual sustainability report.
The methods you use to calculate Scope 2, and the data you use to support them, increasingly determine whether your reporting will hold up to third-party assurance, investor scrutiny, or customer supply chain audits. Utility bills alone are no longer sufficient.
The Two Reporting Methods
The GHG Protocol Scope 2 Guidance recognizes two methods for calculating emissions from purchased electricity.
Location-based. Uses grid-average emissions factors published by governments or grid operators (in the US, typically EPA eGRID subregion factors). Multiply your annual kWh consumption by the annual average factor for your region and you have location-based Scope 2 emissions. Straightforward. Requires only monthly bill totals.
Market-based. Uses factors specific to the electricity you actually purchased, reflecting any renewable energy certificates (RECs), power purchase agreements (PPAs), green tariffs, or utility green power programs. Market-based factors require documentation of the specific supply, and increasingly require temporal alignment between consumption and supply.
Why Bill Data Is Not Enough for Market-Based
Location-based reporting only needs annual kWh. Any utility bill provides that. Market-based reporting is more demanding.
REC matching requires timing granularity. If you buy 100,000 MWh of RECs and consume 100,000 MWh, you can claim zero market-based emissions. But if the emerging 24/7 CFE standard is applied, you need to demonstrate that RECs were generated during the same hour your facility consumed electricity. Annual matching is being replaced by hourly matching. The trap: assuming annual REC volume equals market-based zero.
PPA carve-outs need interval data. If you signed a PPA that supplies 30% of your load, market-based reporting requires you to isolate that 30% at the interval level and apply the PPA-specific factor. Without interval data you cannot document that carve-out defensibly. The trap: proportional attribution instead of interval-level accounting.
Green tariff verification. Utility green power programs typically deliver renewable energy at aggregate portfolio levels. Auditors want to see that the green tariff volume matches your actual consumption in the same reporting period at meaningful granularity. The trap: relying on utility marketing materials without underlying data.
Auditors trace claims back to source data. If the trace ends at a bill, the claim is fragile.
What Interval Data Enables
Interval data (15-minute or 1-minute meter readings across the full year) provides the foundation for defensible Scope 2 reporting under both methods.
Under location-based, interval data lets you use time-varying grid emissions factors rather than annual averages. Regional grids get greener when solar peaks. They get dirtier when coal ramps up overnight. A facility with midday operations in a solar-heavy grid will report lower emissions with interval matching than the annual-average number would suggest.
Under market-based, interval data lets you match your specific supply contracts to actual consumption at the same timing granularity the contracts specify. Hourly REC matching becomes possible. PPA carve-outs are traceable. Green tariff volumes can be verified.
What Assurance Firms Now Ask For
Third-party assurance on Scope 2 emissions is becoming standard for larger reporters. Assurance providers now routinely ask for the underlying data supporting each emissions calculation. When the data ends at a monthly bill, the assurance opinion carries qualifications. When it traces back to interval-level meter data with time-aligned emissions factors, the opinion is cleaner.
The best emissions reporting is boring. It ties every number back to a specific measurement.
Assurance-grade reporting
How DataWrangler Supports Scope 2 Reporting
DataWrangler installs precision meters that capture consumption at 15-minute intervals across the entire year. The same data that drives our demand management work also produces the interval-level foundation for defensible Scope 2 reporting under both location-based and market-based methods. Facilities working with DataWrangler have audit-ready source data whether they are reporting to SBTi, CSRD, or a Fortune 500 customer’s supplier scorecard. That capability is part of how DataWrangler helps commercial and industrial facilities cut electric bills 10 to 25% while building emissions reporting they can defend.
Check Your Current Data
If your Scope 2 emissions are calculated from monthly bill totals, your current method is location-based whether you call it that or not. Market-based claims require documented supply contracts and interval-level consumption data. If either is missing, the claim will not hold up under scrutiny.
Upload your bill for a data-readiness review or see the full commercial and industrial platform.
No responses yet