Scope 1, 2 and 3 emissions are the three categories the Greenhouse Gas Protocol (GHG Protocol) uses to measure a company's annual carbon footprint in tonnes of CO2 equivalent (tCO2e). Scope 1 is direct emissions from on-site fuel and processes, Scope 2 is purchased electricity and heat, and Scope 3 is every other indirect emission in the value chain.
Key takeaways
- Scope 1 is on-site fuel and process emissions, Scope 2 is purchased electricity and heat, and Scope 3 is all other indirect value-chain emissions.
- The GHG Protocol's 2011 Scope 3 Standard splits value-chain emissions into 15 categories: eight upstream and seven downstream.
- Türkiye's Climate Law No. 7552 (2025) creates an Emissions Trading System (ETS); plants in scope must obtain an emission permit within three years.
- The EU Carbon Border Adjustment Mechanism (CBAM) entered its definitive, paying phase on 1 January 2026, and EU buyers are asking suppliers for emissions data.
- The hard part of calculating a carbon footprint is not the formula but reliable activity data from meters, the ERP and purchasing records.
Why are manufacturers being asked about their carbon footprint?
A few years ago, carbon footprints were a chapter in large corporations' sustainability reports. As of 2026 the question reaches mid-sized manufacturers too: in a customer's supplier questionnaire, a bank's credit review or a tender specification. It usually reads the same way: "What were your Scope 1 and Scope 2 emissions last year, and what are you doing about Scope 3?"
The usual reaction is to hire a consultant and fill in a spreadsheet. Gas bills sit with accounts, electricity data lives on the utility's portal, forklift fuel is in purchasing and refrigerant top-ups are in a maintenance logbook. The sheet gets finished, the scramble repeats next year, and nobody can say which line pushed the number up.
This guide is about the corporate, company-level footprint and how a plant turns it into a repeatable data process. Product-level embedded emissions for goods shipped to the EU fall under the Carbon Border Adjustment Mechanism and are a different exercise, covered in our guide to CBAM reporting for Turkish exporters.
What do Scope 1, 2 and 3 emissions cover in a plant?
The split into Scope 1, 2 and 3 emissions prevents double counting and clarifies responsibility: your Scope 1 is your customer's Scope 3. The table below maps the typical factory sources of each scope to where the data comes from:
| Scope | What it covers | Typical sources in a plant | Where the data lives | How hard to measure |
|---|---|---|---|---|
| Scope 1 | Direct emissions from sources you own or control | Boilers, furnaces, generators, forklift and fleet fuel, process emissions, refrigerant leaks | Gas meters, fuel purchase records, maintenance logs | Medium: data exists but is scattered |
| Scope 2 | Indirect emissions from purchased electricity, steam, heat or cooling | Machines, compressors, lighting, HVAC | Electricity bills, automatic meter reading (AMR), sub-meters | Low: metering is usually in place |
| Scope 3 | All other indirect value-chain emissions, upstream and downstream | Purchased materials, logistics, business travel, waste, use of sold products | Purchasing, ERP (enterprise resource planning), supplier declarations, freight records | High: largely estimate-based at first |
Scope 2 emissions can be calculated two ways. The location-based method uses the average emission factor of the grid, while the market-based method reflects what you actually contracted, such as renewable energy certificates. The GHG Protocol's Scope 2 Guidance requires both to be reported where contractual instruments are available, and customer questionnaires usually say which one they want.
Scope 3 is the widest part of a carbon footprint and the hardest to measure. The GHG Protocol's Scope 3 Standard, published in 2011, splits value-chain emissions into 15 categories: eight upstream, such as purchased goods and services, capital goods, business travel and employee commuting, and seven downstream (GHG Protocol, Corporate Value Chain (Scope 3) Standard). Not every category matters to every company; for most manufacturers, purchased materials and freight dominate.
What is the cost of not measuring your carbon footprint?
As of 2026, carbon accounting in Türkiye is no longer purely voluntary. A legal framework is in place and commercial pressure is growing:
Türkiye's Climate Law No. 7552, published on 9 July 2025, establishes a national Emissions Trading System (ETS). Plants in scope must obtain a greenhouse gas emission permit within three years of the law's entry into force and surrender allowances each year matching their verified emissions. (Legislation Information System, Climate Law No. 7552)
Under the same law, every allowance not surrendered is fined at twice the weighted average allowance price of the previous three months (the higher of the primary and secondary market prices). The law provides for a pilot phase before full implementation, during which administrative fines are reduced by 80%. Even so, for a plant that falls within the ETS, inaccurate or incomplete Scope 1 data can have a direct financial consequence; which installations are covered will be settled by secondary legislation, so the regulations need to be followed as they are issued.
On the EU side, the Carbon Border Adjustment Mechanism moved into its definitive, paying phase on 1 January 2026 after a 2023–2025 transitional period (European Commission, Carbon Border Adjustment Mechanism). Even in sectors CBAM does not cover, EU buyers are collecting emissions data from suppliers for their own Scope 3 inventories. For suppliers who cannot provide it, buyers typically fall back on sector averages or conservative estimates, which can become a disadvantage when they choose between suppliers.
Carbon measurement has an energy cost angle too. The International Energy Agency (IEA) reports that around two-thirds of global final energy demand growth since 2019 has come from industry, where the annual rate of energy intensity improvement fell below 0.5% (IEA, Energy Efficiency 2025, Executive summary). In a factory, most Scope 1 and Scope 2 emissions come from energy use, so not measuring emissions usually means not seeing energy waste either.
How do you calculate Scope 1, 2 and 3 emissions? A seven-step method
The seven-step carbon footprint sequence below works for a manufacturer preparing its first inventory or trying to turn a spreadsheet exercise into something repeatable:
- Set the organisational boundary. Decide which legal entities, sites and warehouses are included. The GHG Protocol allows an equity share approach or a control approach. Write your choice down, because a boundary that shifts from year to year makes comparisons meaningless.
- Choose a base year. Reduction targets are measured against it. Pick a recent year with the most complete data, and agree a rule for recalculating the base year after acquisitions, closures or other structural changes.
- Build an inventory of emission sources. List every combustion source, refrigeration unit, vehicle and electricity consumer. For Scope 1 and 2, this list should match your plant's meter and asset registers.
- Tie activity data to measurement. Use meter readings rather than annual invoice totals. If you already have automatic meter reading on electricity, start there; for line and machine breakdowns you need the sub-metering approach described in factory energy monitoring.
- Select and document emission factors. The core formula is: emissions (tCO2e) = activity data (e.g. kWh, m³ of natural gas, litres of fuel) × emission factor. Record each factor's source, year and version, so past years can be restated consistently when factors change.
- Prioritise the Scope 3 categories that matter. Do not try to model all 15 categories in detail in year one. Run a spend-based screening to find the two or three largest, then start asking key suppliers for primary data. Consistent supplier and material codes are essential here, which is where master data management earns its keep.
- Make the calculation reproducible, then report. Version the source data, factors and formulas, and keep a record of who changed what and when. When a verifier or customer asks, you should be able to regenerate the same result from the same data.
Quick self-check
- Can you split last year's gas consumption by boiler and furnace?
- Are refrigerant top-ups, which replace leaked gas, recorded?
- Can you see electricity use at least per production line?
- Are the source and year of every emission factor written down?
- Have you asked your ten largest suppliers for emissions data?
More than three "no" answers suggest the metering and data foundations need attention before any reporting.
Common carbon footprint calculation mistakes
The most common carbon footprint calculation mistake is treating the footprint as an annual reporting task. An inventory built from yearly totals answers "how much" but never "why". A plant that wants to reduce emissions needs to see how much energy each line, shift and product consumes per tonne.
The second mistake is keeping energy and emissions data in separate silos. Consumption data kept for Türkiye's Energy Efficiency Law No. 5627 should feed the carbon inventory from the same source; we cover those duties in energy efficiency obligations for Turkish industry. The third is tying the whole calculation to one person's file: when that person leaves, the method leaves with them.
The fourth is leaving emissions data where management never sees it. Intensity metrics such as tonnes of CO2e per tonne of output belong next to production and energy indicators. Our guide on how to set KPIs helps decide which ones earn a place on the dashboard.
How Digital Bridge makes carbon data measurable
Emission factor selection and the reporting standard are agreed with your sustainability adviser, and third-party verification is carried out by an accredited verifier. Our job is to make sure the activity data behind that calculation is measured, collected and stored in a traceable way:
- Discovery and needs analysis. Through our digital transformation consultancy we map your boundary, emission sources, existing meters and data owners, then share a written list of missing measurement points in priority order.
- Metering and a pilot. Using our energy monitoring and management platform, we start with the most energy-hungry line, furnace or compressor room and collect time-stamped electricity, gas and compressed air data. The typical losses on the compressor side are covered in compressed air leak detection.
- Integration and a single source. With system integrations we connect meters, PLCs (programmable logic controllers), SCADA and the ERP, and bring production volumes, purchasing and fuel records together with energy data in a data warehouse, keyed by period and site. The technical design is explained in our data warehouse and ETL guide.
- Visible indicators. We put emissions by scope, intensity per unit of output and variance against target on a BI dashboard that management, production and maintenance see at the same time. The design principles we follow are set out in BI dashboards and KPIs.
Once this foundation is in place, the same data feeds the corporate inventory, customer questionnaires, CBAM declarations and energy efficiency filings. For available support towards projects that cut energy or carbon intensity, see SME digitalisation grants in Türkiye. For the wider sequence, start with our digital transformation roadmap, and find related guides on our Digital Transformation topic page.
Next step: measure first, then report
The hard part of a carbon footprint is not the formula but reliable activity data. For Scope 1 and Scope 2, most plants already hold that data in meters and invoices; what is missing is the breakdown to line and product level, and the ability to reproduce it with the same method every year. Scope 3 only becomes meaningful once supplier and material data are in order.
If you want to plan how each emission source in your plant should be measured, get in touch with us. In a first conversation we listen to how your site and data sources are set up, then share a written plan for measurement points and data flows.