A corporate carbon footprint is the total greenhouse gas emitted as a result of a company’s activities, expressed in tonnes of CO₂ equivalent (tCO₂e). It should not be confused with personal carbon calculators: corporate accounting follows an internationally recognised standard, can be independently verified, and increasingly carries legal and commercial consequences.
In Türkiye, 2026 is the year this calculation moved from “nice to have” to “necessary.” Here is why — and how the calculation is actually done.
Why It Became Urgent in 2026
Three developments converged:
- Climate Law No. 7552 entered into force on 9 July 2025, establishing the legal basis for Türkiye’s 2053 net zero target.
- The Turkish Emissions Trading System (ETS) entered its pilot phase covering 2026–2027. The pilot covers installations in the cement, iron and steel, aluminium and fertiliser sectors with emission capacity above 50,000 tonnes CO₂ equivalent per year. Allowances are allocated 100% free of charge on a benchmark basis and no financial obligation applies; the purpose is to test the monitoring, reporting and verification (MRV) infrastructure.
- The EU Carbon Border Adjustment Mechanism (CBAM) entered its definitive period on 1 January 2026. For imports during 2026, the first annual declaration and certificate surrender falls due on 30 September 2027.
The practical meaning: during the pilot there is no financial burden, but there is a data obligation. And data not generated today cannot be reconstructed retrospectively once financial obligations begin. We covered the exporter-side implications in which energy and carbon data industrial facilities must track under CBAM.
Which Standard Applies?
Two reference frameworks are in common use and are largely compatible:
- GHG Protocol Corporate Standard — the origin of the Scope 1, 2 and 3 concepts and the most widely used framework globally.
- ISO 14064-1 — a standard for the design, development and reporting of greenhouse gas inventories, often preferred in Türkiye because it is certifiable and verifiable.
Whichever you choose, two boundaries must be set first:
- Organisational boundary: which sites, subsidiaries and joint ventures are inside the inventory? Two approaches exist — operational control (every facility you operate) and financial control / equity share. Operational control is the most common choice in Türkiye.
- Operational boundary: which emission sources are counted? This is what the Scope distinction addresses.
Scope 1: Direct Emissions
Emissions from sources owned or controlled by the company, in four groups:
- Stationary combustion: boilers, furnaces, generators — natural gas, fuel oil, coal, LPG.
- Mobile combustion: company vehicle fleet, forklifts, plant machinery — diesel and petrol.
- Process emissions: emissions from chemical reactions rather than fuel, such as calcination in clinker production. In cement and steel this can dominate the total.
- Fugitive emissions: fluorinated gases escaping from refrigeration and air conditioning systems, plus SF₆. Small in volume but impossible to ignore because of very high global warming potential (GWP).
The fourth item is the one most often missed on site. Without refrigerant top-up records, these emissions remain invisible.
Scope 2: Indirect Emissions from Purchased Energy
Emissions associated with purchased electricity, and with purchased steam, heating and cooling. The emission physically occurs at the power station but is attributed to the consuming company.
Two calculation methods exist, and reporting frameworks generally ask for both:
- Location-based: uses the national grid average emission factor, which is updated annually.
- Market-based: takes into account renewable energy certificates (such as I-REC) or green electricity purchased under bilateral contracts. Companies buying certified green power see a markedly lower figure here.
In most manufacturing operations Scope 2 is the largest or second-largest item in the inventory — and the good news is that it is also the easiest to measure.
Scope 3: Value Chain Emissions
Emissions outside the company’s control but resulting from its activities. The GHG Protocol divides these into 15 categories, the main ones being:
- Purchased goods and services (usually the largest item)
- Capital goods
- Fuel- and energy-related activities not included in Scope 1 or 2
- Upstream and downstream transportation and distribution
- Waste generated in operations
- Business travel and employee commuting
- Use and end-of-life treatment of sold products
Be realistic about Scope 3: attempting all 15 categories in year one stalls most projects. The widely accepted approach is a screening exercise first, then focusing on the three to five categories that make up more than 80% of the total.
How the Calculation Works
The core formula is simple:
Emissions (tCO₂e) = Activity data × Emission factor × GWP
- Activity data: natural gas consumed (m³ or kWh), electricity purchased (kWh), diesel (litres), refrigerant charged (kg), freight tonne-kilometres.
- Emission factor: greenhouse gas released per unit of activity. National inventory, IPCC, DEFRA or supplier-specific factors may be used. The source and vintage of the factor must be stated in the report.
- GWP: global warming potential, converting non-CO₂ gases (CH₄, N₂O, F-gases) into CO₂ equivalent.
The data quality hierarchy
The first thing a verifier examines is not the number itself but where it came from. The quality ranking is:
- Measured data — meter and flow meter records. The most reliable.
- Invoice data — verifiable, but gives no breakdown by site, line or product.
- Estimates and pro-rating — derived from capacity or operating hours. Acceptable, but carries high uncertainty and gets challenged during verification.
Why Invoices Alone Are Not Enough
Most carbon inventory projects start on the assumption that “we have the invoices, we can calculate,” and stall at three points:
- No site separation. Production and administrative buildings fed from the same meter merge into one invoice. If your organisational boundary is site-based, you cannot make the split.
- Product-level intensity cannot be derived. CBAM asks not for total emissions but for embedded emissions per product (tCO₂e per tonne of steel, for instance). That requires electricity and fuel to be allocated to production lines, which invoices cannot do.
- Period mismatch. Billing periods do not align with calendar months, while production data is monthly. When the two datasets do not overlap, intensity figures drift.
All three have the same remedy: measuring energy at source and continuously. Energy data is already the input to the carbon calculation, so a company that installs an energy monitoring system has also built the raw data layer for its carbon inventory. We listed the minimum data set for Scope 1, 2 and 3 in carbon emissions tracking.
From Measurement to Report: A Practical Setup
The data architecture that makes carbon reporting sustainable has four layers:
- Electricity: measurement at the transformer outgoing, main distribution busbars and large consumers using energy analysers. → Scope 2
- Fuel: gas meters, fuel oil and diesel consumption records, generator running hours. → Scope 1
- Utilities: steam flow, compressed air, water — on the same time axis through multi-utility monitoring. → Scope 1 and efficiency
- Production data: output in tonnes, units or m². This is the denominator of every intensity indicator; without it no benchmarking is possible.
The ATS Energy Monitoring System is designed to present electricity, natural gas, water and compressed air consumption together with carbon emission reporting on a single platform, so energy efficiency and carbon reporting draw from the same database.
Verification and Reporting
Once the inventory is prepared, verification by an accredited body is generally expected (under ISO 14064-3). Verifiers look for three things: traceability of the data (the chain from invoice down to meter), the source and vintage of the emission factors used, and the reproducibility of the calculation.
For that reason, the inventory should be built not as a one-off spreadsheet exercise but as a process repeatable each year with the same methodology. Changing the method forces a base year recalculation, which undermines the comparability of your previous reports.
Frequently Asked Questions
What is the difference between corporate and personal carbon footprints?
Personal calculators are rough estimates intended to raise awareness. Corporate accounting follows a standard such as the GHG Protocol or ISO 14064-1, defines organisational and operational boundaries, relies on traceable data and can be independently verified.
Do I have to calculate Scope 3?
It depends on the reporting framework. ISO 14064-1 requires a materiality assessment of indirect emissions, while CBAM focuses on the embedded emissions of the product. The common approach is to establish Scope 1 and 2 fully and verifiably first, then start Scope 3 with the priority categories.
Does the Turkish ETS pilot cover us?
The pilot covers installations in the cement, iron and steel, aluminium and fertiliser sectors with emission capacity above 50,000 tCO₂e per year. Companies below that threshold or in other sectors have no direct obligation — although customer and supply chain requirements continue independently.
Does buying green electricity zero our carbon footprint?
No. Certified renewable electricity only reduces the market-based Scope 2 figure. Scope 1 (fuel, process and fugitive emissions) and Scope 3 remain unchanged, and the location-based Scope 2 figure is normally reported as well.
Where should we start?
In order: define the organisational boundary, choose a base year, inventory your existing data sources for Scope 1 and 2 (meters, invoices, refrigerant records), identify missing measurement points and close them. A calculation made before the data collection infrastructure is ready will come back at the verification stage.
Can an energy monitoring system calculate our carbon footprint automatically?
It can produce a continuous, automatic emissions report for Scope 1 and Scope 2 by multiplying measured energy data with emission factors. Scope 3 requires supplier and logistics data and therefore sits outside an energy monitoring system.
Conclusion
Corporate carbon footprinting looks like a reporting exercise, but it is really a data infrastructure exercise. The standard is chosen in a day and the boundaries defined in a week; traceable energy data that can be allocated to products and stays consistent year over year is produced only through measurement.
That is the shared message of the regulations that took effect in 2026: the financial obligation arrives later, but the data obligation has already started. To assess whether your site’s measurement infrastructure is sufficient for carbon reporting, get in touch with us.