59% of sites are ISO 50001 certified (2023: 57%)
Metrics Definitions and Methodologies
Percentage of sites ISO 50001 certified: Calculated as percentage of sites that are ISO 50001 certified over the total number of operational sites. Aside from the assurance provider, this metric is not validated by an external body.
E1-5 Energy Consumption and Mix
In MWh |
|
|
|---|---|---|
|
2024 |
2023 |
|
|
|
Total energy consumption |
46,265,174 |
38,994,387 |
of which non-renewable energy consumption |
43,775,979 |
37,399,001 |
of which nuclear energy consumption |
281,639 |
n.a. |
of which renewable energy consumption |
2,207,556 |
1,595,387 |
thereof total energy consumption from fossil fuel sources |
41,851,084 |
33,916,489 |
thereof from coal and coal products |
0 |
n.a. |
thereof from crude oil and petroleum products |
4,030,888 |
4,214,558 |
thereof from natural gas |
35,805,770 |
28,082,617 |
thereof from other fossil fuel sources |
2,014,426 |
1,619,314 |
thereof total consumption of purchased electricity, heat, steam, and cooling from fossil sources |
1,924,895 |
3,482,512 |
thereof electricity |
1,146,867 |
2,059,688 |
thereof heating |
4,626 |
237,429 |
thereof cooling |
0 |
0 |
thereof steam |
773,401 |
1,185,394 |
thereof total energy consumption from nuclear sources |
281,639 |
n.a. |
thereof self-generated non-fuel renewable energy for own consumption |
39,775 |
34,497 |
thereof total fuel consumption of renewable sources, including biomass |
82,628 |
0 |
thereof total consumption of purchased electricity, heat, steam, and cooling from renewable sources |
2,085,153 |
1,560,890 |
thereof electricity |
2,050,046 |
1,558,048 |
thereof heating |
803 |
1,644 |
thereof cooling |
0 |
0 |
thereof steam |
34,304 |
1,197 |
Share of fossil fuel sources in total energy consumption (%) |
95% |
96% |
Share of consumption from nuclear sources in total energy consumption (%) |
1% |
n.a. |
Share of renewable sources in total energy consumption (%) |
5% |
4% |
Energy consumption outside the organization |
|
|
Total energy production (to market) |
344,166,550 |
380,740,954 |
thereof from non-renewable sources |
335,524,028 |
375,023,036 |
thereof fuels |
327,592,038 |
367,322,279 |
thereof electricity |
7,095,544 |
6,896,826 |
thereof heating |
836,446 |
803,931 |
thereof cooling |
0 |
0 |
thereof steam |
0 |
0 |
thereof from renewable |
8,642,522 |
5,717,918 |
Metrics Definitions and Methodologies
The measurement of all metrics below, unless otherwise specified, is not validated by an external body other than the assurance provider.
Total energy consumption: The aggregated total energy consumption is derived from site-specific information, utilizing a combination of direct measurements, calculations, and estimations. When direct measurements or calculations are not feasible, estimations are used to determine the energy consumption. Potential limitations of the methodology include the accuracy and reliability of estimations when direct measurements and calculations are not feasible. The total energy consumption is reported separately for non-renewable, nuclear, and renewable energy consumption. The shares of fossil fuel, nuclear, and renewable sources are calculated by dividing the respective energy consumption by the total energy consumption. The data related to energy consumption is reported with the same reporting boundaries as described for Scope 1 and 2 GHG emissions. Some data included in this metric undergoes verification by an external body when the fuel consumption is directly correlated with GHG emissions under a regulated emission trading system.
Total energy consumption from fossil fuel sources: The aggregated energy consumption from fossil fuel sources is derived from site-specific information, utilizing a combination of direct measurements, calculations, and estimations. When direct measurements or calculations are not feasible, estimations are used to determine the energy consumption. Potential limitations of the methodology include the accuracy and reliability of estimations when direct measurements and calculations are not feasible. The total is also reported separately for four source types of fuels, from coal and coal products, from crude oil and petroleum products (refers to diesel, heating oil, and residue/waste oil, as well as other liquid fuels), from natural gas (refers to natural gas, residual gas, and other gaseous fuels), and from other fossil fuel sources (refers to FCC coke and other solid fuels). Some data included in this metric undergoes verification by an external body when the fuel consumption is directly correlated with GHG emissions under a regulated emission trading system.
Total consumption of purchased electricity, heat, steam, and cooling from fossil sources: the aggregated total consumption of purchased electricity, heat, steam, and cooling is derived from site-specific measurements recorded and invoiced by the energy providers. Potential limitations of this method include discrepancies or errors in provider invoices, variations in measurement accuracy, and possible delays in reporting. Determining the fossil part of the purchased energy involves using either a market-based approach, which utilizes the supplier-specific mix, or a location-based approach, using the general energy mix of the location if the supplier-specific mix is not available. A limitation of this methodology is the potential misalignment in timelines for suppliers to publish their energy mix compared to the reporting schedule for a company’s sustainability statement. Consequently, the energy mix from the previous period may need to be used, potentially leading to discrepancies or a less accurate representation of the current renewable energy consumption. The total consumption is also reported separately for electricity, heat, steam, and cooling.
Total energy consumption from nuclear sources: The aggregated energy consumption from nuclear sources refers to consumption of purchased electricity from nuclear sources. Determining this portion of the purchased electricity involves using site-specific electricity purchased and electricity mixes, either market-based with the supplier-specific mix, or location-based with the general energy mix of the location if the supplier-specific mix is not available. A key limitation of this methodology is the potential misalignment in timelines for suppliers to publish their energy mix compared to the reporting schedule for a company’s sustainability statement. Consequently, the energy mix from the previous period may need to be used, potentially leading to discrepancies or a less accurate representation of the current renewable energy consumption.
Self-generated non-fuel renewable energy for own consumption: The aggregated self-generated non-fuel renewable energy for own consumption refers to the generation of electricity using solar photovoltaic (PV) technology for own consumption in operated assets. This is derived from site-specific measurements recorded at the solar PV station. A potential limitation of such measurements is the accuracy and reliability of the meter equipment.
Total fuel consumption from renewable sources, including biomass: The aggregated fuel consumption from renewable sources is derived from site-specific information, utilizing a combination of direct measurements, calculations, and estimations. When direct measurements or calculations are not feasible, estimations are used to determine the fuel consumption. Potential limitations of the methodology include the accuracy and reliability of estimations when direct measurements and calculations are not feasible.
Total consumption of purchased electricity, heat, steam, and cooling from renewable sources: The aggregated total consumption of purchased electricity, heat, steam, and cooling from renewable sources is derived from site-specific measurements recorded and invoiced by the energy providers. Potential limitations of this method include discrepancies or errors in provider invoices, variations in measurement accuracy, and possible delays in reporting. Determining the renewable part of the purchased energy involves using either a market-based approach, which utilizes the supplier-specific mix, or a location-based approach, using the general energy mix of the location if the supplier-specific mix is not available. A limitation of this methodology is the potential misalignment in timelines for suppliers to publish their energy mix compared to the reporting schedule for a company’s sustainability statement. Consequently, the energy mix from the previous period may need to be used, potentially leading to discrepancies or a less accurate representation of the current renewable energy consumption. The total consumption is also reported separately for electricity, heat, steam, and cooling.
Total energy production (to market): The aggregated value is determined by invoiced amounts and documented transactions for all energy products produced and sold to third-party customers. Intracompany sales are excluded from this measurement. The total energy production (to market) from non-renewable and renewable sources is reported separately. Whereas renewables refer to our biofuels in sold products (such as sustainable aviation fuels), non-renewables refer to fossil fuel energy sales, reported separately for fuels (such as diesel, gasoline), and electricity/heat/cooling/steam (such as electricity produced at the Brazi power plant using natural gas).
Energy intensity per unit of sales revenue |
|
|
|---|---|---|
|
|
2024 |
Total energy consumption per unit of sales revenue from activities in high and low climate impact sectors |
MWh/EUR |
0.001 |
Total energy consumption from activities in high and low climate impact sectors |
MWh |
46,265,174 |
Revenues from contracts with customers |
EUR mn |
32,411 |
Revenues from other sources |
EUR mn |
1,569 |
Total sales revenues from activities in high and low climate impact sectors (see Note 7 – Sales Revenues) |
EUR mn |
33,981 |
Metrics Definitions and Methodologies
The metric below also refers to metrics reported under [E1-5.37a-37c] [E1-5.38a-38e] [E1-5.39 AR 34]
Total energy consumption per unit of sales revenue from activities in high and low climate impact sectors: The energy intensity per unit of sales revenue refers to the total energy consumption in both high and low climate impact sectors over the total sales revenues in EUR. A breakdown of the energy consumption from activities in the high climate impact sectors and low climate impact sectors is not available. The sales revenues are disclosed in the financial statement. The measurement of these metrics is not validated by an external body other than the assurance provider.
OMV’s main NACE codes are C.19.2. Manufacture of refined petroleum products, B.6.2. Extraction of natural gas, B.6.1. Extraction of crude petroleum, C.29.2. Manufacture of refined petroleum products, and C.20.16 Manufacture of plastics in primary forms. All disclosed energy consumption numbers reflect consumption in both high and low climate impact sectors.
E1-6 Gross Scope 1, 2, 3, and Total GHG Emissions
Health, Safety, Security, and Environment (HSSE) data, including consumed energy and greenhouse gas (GHG) data for Scope 1, Scope 2, and Scope 3 emissions, is reported (100%) for activities that OMV operates or where OMV holds a stake of more than 50% and exerts a controlling influence. The exception to this is Scope 3 Category 15 “Investments,” which follows the equity approach. OMV’s share of the investment’s Scope 1, 2, and, where relevant, Scope 3 emissions are accounted for in this category. If an investment is a business partner in OMV’s upstream or downstream value chain, the respective Scope 3 emissions are included in the appropriate category. OMV calculates its corporate carbon footprint (Scope 1, 2, and 3 emissions) following the principles, requirements, and guidance provided by the GHG Protocol Corporate Standard (version 2004), the GHG Protocol Scope 2 Guidance (version 2015), and the GHG Protocol Corporate Value Chain (Scope 3) Accounting and Reporting Standard (Version 2011).
- Scope 1: This refers to direct emissions from sources that are owned or controlled by OMV. OMV uses emission factors from various sources, such as the IPCC and API GHG Compendium. OMV includes the greenhouse gases CO2, CH4, and N2O in its Scope 1 calculations. Since 2024, OMV has been applying the global warming potentials (GWPs) from the IPCC Sixth Assessment Report (AR6 – 100 years) to calculate CO2e emissions of non-CO2 gases. Assets subject to EU-ETS report in accordance with the EU-ETS methodology.
- Scope 2: This refers to indirect emissions resulting from the generation of purchased or acquired electricity, heating, cooling, or steam. OMV reports according to both the location-based and market-based methods, using emission factors from different sources, including the International Energy Agency and supplier-specific emission factors.
- Scope 3: This covers other indirect emissions occurring outside the organization, including both upstream and downstream emissions. OMV uses emission factors from various sources, such as the IPCC, Plastics Europe, and DBEIS. The data includes Scope 3 emissions from the use and processing of sold products, excluding pure “trading margin” sales and intracompany sales. Since 2015, emissions from purchased goods, services, and capital goods have been included. Since 2018, the net import of refinery feedstock has also been included.
In t CO2e |
|
|
|
|---|---|---|---|
|
2024 |
||
|
Scope 1 |
Scope 2 |
Scope 2 |
Total OMV Group emissions |
9,778,526 |
991,275 |
1,036,020 |
Consolidated Group |
9,605,122 |
989,062 |
1,033,789 |
Partners’ share in joint operations controlled by OMV |
173,403 |
2,213 |
2,231 |
Metrics Definitions and Methodologies
The metrics below refer also to metrics reported under [E1-6.44a, 44b] [E1-6.48a] [E1-6.48 AR 43] [E1-6.44-52] [E1-6.49a, 49b] [E1-6.52a, 52b] [E1-6.49 AR 45] [E1-6.47].
Scope 1 and 2 emissions, divided into consolidated Group and not fully consolidated entities with operational control: Scope 1 and 2 GHG emissions from the consolidated accounting group includes 100% of gross Scope 1 and 100% of gross Scope 2 emissions from the parent and subsidiaries, as well as OMV’s proportionate share of emissions from joint operations that it operationally controls. Scope 1 and Scope 2 emissions reported under “not fully consolidated entities with operational control” include partners’ shares in joint operations where OMV has operational control. Some data included in this metric undergoes verification by an external body when GHG emissions are regulated under an emission trading system.
In t CO2e |
|
|
|
|
|
|
|
||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
|
Retrospective |
Milestones and target years |
|||||||||||||||
|
2019 |
2023 |
2024 |
20301 |
20401 |
Annual % target/ |
|||||||||||
Scope 1 & 2 GHG emissions |
13,920,157 |
10,297,163 |
10,769,800 |
105% |
9,744,110 |
5,568,063 |
3.00% |
||||||||||
Scope 1 GHG emissions |
|
|
|
|
|
|
|
||||||||||
Gross Scope 1 GHG emissions |
12,648,004 |
9,307,079 |
9,778,526 |
105% |
– |
– |
– |
||||||||||
of which from OMV’s Energy business segment |
9,516,872 |
6,523,692 |
6,675,721 |
102% |
– |
– |
– |
||||||||||
of which is CO2 |
7,790,533 |
6,161,600 |
6,384,552 |
104% |
– |
– |
– |
||||||||||
of which is CH42 |
1,708,657 |
353,402 |
282,589 |
80% |
– |
– |
– |
||||||||||
of which is N2O |
17,682 |
8,690 |
8,580 |
99% |
– |
– |
– |
||||||||||
of which from OMV’s non-Energy business segment |
3,131,132 |
2,783,387 |
3,102,805 |
111% |
– |
– |
– |
||||||||||
of which is CO2 |
3,126,781 |
2,778,850 |
3,098,710 |
112% |
– |
– |
– |
||||||||||
of which is CH4 |
2,020 |
2,255 |
1,909 |
85% |
– |
– |
– |
||||||||||
of which is N2O |
2,332 |
2,281 |
2,186 |
96% |
– |
– |
– |
||||||||||
Percentage of Scope 1 GHG emissions from regulated emissions trading schemes (%) |
67% |
83% |
85% |
102% |
– |
– |
– |
||||||||||
Scope 2 GHG emissions |
|
|
|
|
|
|
|
||||||||||
Gross location-based Scope 2 GHG emissions |
906,219 |
778,761 |
1,036,020 |
133% |
– |
– |
– |
||||||||||
Gross market-based Scope 2 GHG emissions |
1,272,153 |
990,084 |
991,275 |
100% |
– |
– |
– |
||||||||||
Significant Scope 3 GHG emissions |
|
|
|
|
|
|
|
||||||||||
Total gross indirect (Scope 3) GHG emissions (t.r.) |
114,857,247 |
103,850,767 |
95,362,239 |
92% |
91,885,798 |
57,428,624 |
2.00% |
||||||||||
Total gross indirect (Scope 3) GHG emissions (all significant categories) |
135,579,824 |
120,512,791 |
145,906,773 |
121% |
– |
– |
– |
||||||||||
1 Purchased goods and services3 |
13,274,484 |
13,156,102 |
13,494,945 |
103% |
– |
– |
– |
||||||||||
of which from feedstock (t.r.)3 |
6,638,325 |
6,764,709 |
5,755,170 |
85% |
|
|
|
||||||||||
2 Capital goods3 |
536,442 |
503,792 |
462,182 |
92% |
– |
– |
– |
||||||||||
3 Fuel and energy-related activities (not included in Scope 1 or Scope 2) |
212,529 |
221,034 |
161,192 |
73% |
– |
– |
– |
||||||||||
5 Waste generated in operations |
1,142,347 |
263,685 |
216,402 |
82% |
– |
– |
– |
||||||||||
10 Processing of sold products |
12,195,100 |
8,486,094 |
9,541,912 |
112% |
– |
– |
– |
||||||||||
of which from oil for non-energy use |
7,775,223 |
5,144,729 |
4,918,252 |
96% |
– |
– |
– |
||||||||||
of which from gas for non-energy use |
2,042,525 |
1,295,459 |
472,575 |
36% |
– |
– |
– |
||||||||||
of which from chemicals |
2,377,352 |
2,045,906 |
4,151,085 |
203% |
– |
– |
– |
||||||||||
11 Use of sold products |
96,466,758 |
88,170,050 |
79,908,065 |
91% |
– |
– |
– |
||||||||||
of which from oil for energy use (t.r.) |
64,543,321 |
56,799,969 |
56,038,351 |
99% |
– |
– |
– |
||||||||||
of which from gas for energy use (t.r.) |
31,923,436 |
30,574,054 |
23,025,700 |
75% |
– |
– |
– |
||||||||||
of which from chemicals |
– |
796,026 |
844,014 |
106% |
– |
– |
– |
||||||||||
12 End-of-life treatment of sold products (t.r.) |
11,752,165 |
9,712,034 |
10,543,018 |
109% |
– |
– |
– |
||||||||||
15 Investments4 |
– |
– |
31,579,057 |
0% |
– |
– |
– |
||||||||||
Total GHG emissions |
|
|
|
|
|
|
|
||||||||||
Total GHG emissions (location-based) |
149,134,047 |
130,598,631 |
156,721,318 |
120% |
– |
– |
– |
||||||||||
Total GHG emissions (market-based) |
149,499,981 |
130,809,954 |
156,676,573 |
120% |
– |
– |
– |
||||||||||
|
|||||||||||||||||
OMV uses various contractual instruments to manage the sale and purchase of energy, both bundled with attributes about energy generation and unbundled energy attribute claims. These contractual instruments form the basis of the Scope 2 market-based emissions. Of the 4,291,687 MWh of purchased electricity, heat, and steam, 55% is covered by contractual instruments. The main types of contractual instruments OMV uses are full supply contracts, Power Purchase Agreements, and Guarantees of Origin. Some 36% of the purchased energy is bundled with attributes about energy generation and 64% is unbundled.
In 2024, 0.1% of Scope 3.1 “Purchased goods and services” and 1% of Scope 3.2 “Capital goods” were calculated using data obtained from suppliers. This corresponds to 0.02% of total Scope 3 emissions.
Metrics Definitions and Methodologies
The measurement of all metrics below, unless otherwise specified, is not validated by an external body other than the assurance provider.
Scope 1 and 2 GHG emissions (market-based): The aggregated Scope 1 and 2 GHG emissions (market-based) is the sum of 100% of gross Scope 1 and 100% of gross Scope 2 (market-based) emissions. Some data included in this metric undergoes verification by an external body when GHG emissions are regulated under an emission trading system.
Gross Scope 1 GHG emissions: The aggregated gross Scope 1 GHG emissions include emissions source types such as stationary combustion, mobile combustion, flaring and venting, process emission, and fugitive emissions. Scope 1 GHG emissions are calculated by multiplying activity data with emission factors. Activity data is derived from site-specific information, utilizing a combination of direct measurements, calculations, and estimations. When direct measurements or calculations are not feasible, estimations are used to determine the energy consumption. Potential limitations of the methodology include the accuracy and reliability of estimations when direct measurements and calculations are not feasible. Further potential limitations include the accuracy of measurement devices, the reliability of estimation methods, variations in emission factors, and potential gaps in data collection from all relevant sources. The total Scope 1 emissions are reported separately for OMV’s Energy business segment (Energy and F&F) and OMV’s non-energy business segment (Chemicals) for each of the reported greenhouse gases, CO2, CH4, and N2O, converted to t CO2e with the respective GWP. Some data included in this metric undergoes verification by an external body when GHG emissions are regulated under an emission trading system.
Scope 1 GHG emissions from regulated emissions trading schemes in %: The percentage of Scope 1 GHG emissions from regulated emissions trading schemes is calculated by dividing the sum of GHG emissions from EU ETS installations and non-EU ETS installations by the total Scope 1 GHG emissions. Limitations can arise when emissions are reported in the company’s annual sustainability statement before the final verification report is issued by an external body due to differing reporting deadlines. Emission trading systems may also vary in terms of specific deadlines and processes, tailored to their respective regulatory environments. The measurement of the nominator of this metric (GHG emissions from EU ETS installations and non-EU ETS installations) is validated by an external body other than the assurance provider. Where not specified, the measurement of the metric has not been validated by any external body other than the assurance provider.
Gross location-based and market-based Scope 2 GHG emissions: Scope 2 emissions are reported separately applying the location-based and the market-based approach. Aggregated Scope 2 GHG emissions are calculated in t CO2e based on activity data (MWh of electricity consumption) multiplied by GHG emission factors. The market-based method reflects emissions from electricity that companies have purposefully chosen. It derives emission factors from contractual instruments. Where no contractual data is available, residual mix or location-based emission factors is used.
One limitation of this methodology is the potential misalignment of timelines for suppliers to publish their energy mix and emission factor compared to the reporting schedule for a company’s sustainability statement. Consequently, an emission factor from the previous period may need to be used, potentially leading to discrepancies or a less accurate representation of the current renewable energy consumption.
Total gross indirect (Scope 3) GHG emissions (t.r. – target-relevant): This metric is an aggregated value of target-relevant Scope 3 emissions in the following categories: Scope 3.1 from feedstock of OMV’s non-energy business segment (Chemicals), Scope 3.11 from OMV’s energy business segment (Energy and Fuels & Feedstock), and Scope 3.12 emissions from OMV’s non-energy business segment (Chemicals).
Total gross indirect (Scope 3) GHG emissions (all significant categories): This metric is an aggregated emissions value of all significant Scope 3 categories.
1 Purchased goods and services: The aggregated Scope 3.1 emissions from purchased goods and services are derived from purchased feedstock, goods, and services with a combination of an average data method for purchased feedstock, and a hybrid method (average emission factors and supplier-specific factors if available) for purchased goods and services. The primary sources of emission factors are DBEIS, Ecoinvent©, and other sources. OMV actively engages with suppliers to increase the proportion of emissions calculated using supplier-specific emission factors.
2 Capital goods: The aggregated Scope 3.2 emissions from capital goods are derived from the expenditure on capital goods using a hybrid method (average emission factors and supplier-specific factors if available). The primary source of emission factors is DBEIS. OMV actively engages with suppliers to increase the proportion of emissions calculated using supplier-specific emission factors.
3 Fuel- and energy-related activities (not included in Scope 1 or Scope 2): The aggregated Scope 3.3 emissions are derived from the amount of purchased and consumed fuels, electricity, heat, steam, and cooling and appropriate emission factors from the IEA, DEFRA, or other sources on a country basis.
5 Waste generated in operations: The aggregated Scope 3.5 emissions are derived from waste data and appropriate emission factors from DEFRA, Ecoinvent©, and other sources.
10 Processing of sold products (t.r.): The aggregated Scope 3.10 emissions are derived from the volume of sold products to third parties and estimated emission factors. Scope 3.10 emissions are reported separately for oil to non-energy, gas to non-energy, and chemicals.
11 Use of sold products (t.r.): The aggregated Scope 3.11 emissions are derived from the volume of sold products to third parties and appropriate emission factors from IPCC or other sources. Scope 3.11 emissions are reported separately for oil to energy, gas to energy, and chemicals.
12 End-of-life treatment of sold products (t.r.): The aggregated Scope 3.12 emissions are derived from the recycled and biogenic content of Borealis products. This conservative and transparent approach, known as the circular product offering cut-off methodology, ensures that Borealis assumes the burden of recycling and end-of-life emissions in its own GHG calculation, rather than relying on the efforts of other organizations to achieve climate neutrality or drive circularity.
15 Investments: The aggregated Scope 3.15 emissions include Scope 1, 2, and 3 emission estimates and are derived from a combination of primary data from investments, and activity data multiplied with appropriate emission factors from the IMF or other sources.
Total GHG emissions: The total GHG emissions are reported separately as location-based and market-based total GHG emissions. Both metrics are calculated as the sum of 100% of gross Scope 1, 100% of gross Scope 2 (location-based and market-based respectively) emissions, and 100% of gross indirect (Scope 3) GHG emissions (all significant categories). Some data included in this metric undergoes verification by an external body when GHG emissions are regulated under an emission trading system.
Certain categories are excluded from our Scope 3 emissions, with justifications as follows: Category 3.4 “Upstream transportation and distribution” is excluded based on Ipieca guidelines, which suggest that upstream transportation and distribution emissions should not be counted separately, as the fuels used are already accounted for in Scope 3 Category 11, “Use of sold products”. This prevents double counting and applies to OMV including Borealis, although it may be relevant for Borealis as an independent company.
Similarly, Category 3.6 “Business travel,” Category 3.7 “Employee commuting,” and Category 3.9 “Downstream transportation and distribution” are excluded to avoid double counting because the fuels involved are included under Category 11 “Use of sold products.” These exclusions apply to OMV including Borealis but may be relevant for Borealis independently.
Category 3.8 “Upstream leased assets” are not separately accounted for as offshore platforms and joint ventures are already accounted for under Scope 1 emissions for OMV. For Borealis, this category is not included as it falls under the 0.5% cutoff criterion of their total Scope 3 emissions.
Category 3.13 involves emissions from “Downstream leased assets” owned by OMV, which are, however, already included in Scope 1 or 2, with no emissions allocated to this category. Lastly, OMV does not have any franchise activities, so there are no emissions for Category 3.14 “Franchises. ”
|
|
2024 |
|---|---|---|
GHG intensity per unit of sales revenue |
|
|
Total GHG emissions (location-based) per unit of sales revenue |
tCO2e/EUR |
0.005 |
Total GHG emissions (market-based) per unit of sales revenue |
tCO2e/EUR |
0.005 |
Total sales revenues (see Note 7 – Sales Revenues) |
EUR mn |
33,981 |
Metrics Definitions and Methodologies
The metrics below refer also to metrics reported under [E1-6.44a-44d] [E1-6.48a] [E1-6.48a AR 43] [E1-6.44-52] [E1-6.49a-49b] [E1-6.52a-52b] [E1-6.48 AR 43] [E1-6.49 AR 45] [E1-6.51 AR 46] [E1-6.52 AR 47] [E1-6.47]
Total GHG emissions per unit of sales revenue: The GHG intensity per unit of sales revenue refers to the total GHG emissions, separated by location-based and market-based, over the total sales revenues in EUR. The total sales revenues are disclosed in the financial statement. The measurement of these metrics is not validated by an external body other than the assurance provider.
In t CO2 |
|
|
||
|---|---|---|---|---|
|
2024 |
2023 |
||
Biogenic emissions of CO2 not included in Scope 1 GHG emissions |
16,219 |
n.a |
||
Biogenic emissions of CO2 not included in Scope 2 GHG emissions (market-based) |
205,337 |
n.a |
||
Biogenic emissions of CO2 not included in Scope 3 GHG emissions1 |
2,713,258 |
1,900,541 |
||
|
||||
Metrics Definitions and Methodologies
The metric below also refers to metrics reported under [E1-5.37a, 37b, 37c] [E1-5.38a, 38b, 38c, 38d, 38e] [E1-5.39 AR 34]
Biogenic CO2 emissions: Biogenic CO2 emissions are calculated by measuring the CO2 released from the combustion or decomposition of organic materials, such as biomass and biofuels. This is reported separately referring to each scope of GHG emissions. Biogenic CO2 emissions not included in Scope 1 GHG emissions are derived by site-specific consumption of renewable fuels, including biomass, and established emission factors published by IPCC. Biogenic CO2 emissions not included in Scope 2 GHG emissions are derived from site-specific energy purchases under consideration of the biomass share in the energy mix (either market-based, or location-based in the absence of supplier-specific information) and established emission factors published by IPCC. Biogenic CO2 emissions not included in Scope 3 GHG emissions are derived from energy sales from renewable sources such as biofuels, and established emission factors published by IPCC. Aside from the assurance provider, the measurement of all metrics in this table is not validated by an external body.
In t |
|
|
|---|---|---|
|
2024 |
2023 |
Hydrocarbons flared |
87,912 |
100,162 |
Hydrocarbons vented |
6,228 |
8,967 |
Metrics Definitions and Methodologies
Hydrocarbons flared and vented: The aggregated hydrocarbons flared and vented are determined from site-specific information, using a combination of direct measurements, calculations, and estimations of gas directed to flares or vents, factoring in the hydrocarbon content in the gas composition. When direct measurements or calculations are not feasible, estimations are employed to determine the amount of gas flared or vented. Potential limitations of this methodology include the accuracy and reliability of estimations in the absence of direct measurements and calculations, as well as the frequency of gas analyses. Aside from the assurance provider, the measurement of all metrics in this table is not validated by an external body.
E1-7 GHG Removals and GHG Mitigation Projects Financed Through Carbon Credits
In 2024, OMV did not have any GHG removals and storage resulting from projects in its own operations nor in its upstream or downstream value chain.
|
|
2024 |
|---|---|---|
Total |
t CO2e |
346,094 |
Share from removal projects |
% |
0 |
Share from reduction projects |
% |
100 |
Share from projects within the EU |
% |
0.03 |
Share of carbon credits that qualify as corresponding adjustments under Article 6 of the Paris Agreement. |
% |
0 |
Recognized quality standards |
|
|
CDM (Clean Development Mechanism) |
% |
18.4 |
Gold Standard |
% |
0.13 |
VCS (Verified Carbon Standard) |
% |
81.4 |
Voluntary Carbon Offsetting
OMV offers customers voluntary carbon offsetting and works closely with ClimatePartner, an internationally trusted service partner based in Munich. OMV selects certified carbon offsetting projects and ClimatePartner provides them, ensuring that OMV customers who use this option are able to contribute a dedicated amount to these projects. The criteria for these carbon offset credits to be used for voluntary offsetting are clearly defined in OMV’s GHG Management Framework. In 2024, the biggest contributors in terms of CO2 offsets in OMV’s portfolio were wind projects in India and China, and forest protection in Brazil. The climate protection projects used for CO2 offsetting consisted of: hydropower projects (5.68%) in Turkey, India, and China; solar projects (5.49%) in China and India; wind energy projects (71.15%) in Bulgaria, Turkey, China, and India; nature-based projects (15.53%) in Brazil; and a waste heat recovery project (2.15%) in Pakistan. These carbon offsets are verified according to one or more of the following internationally recognized standards: Gold Standard (GS), Verified Carbon Standard (VCS), Clean Development Mechanism (CDM), and Climate, Community & Biodiversity Standard (CCBS).
None of these voluntary carbon offsets have been accounted to contribute toward achieving OMV’s GHG reduction target. OMV’s GHG Management Framework Standard provides minimum requirements for voluntary carbon offset credits. The total amount of carbon credits outside of OMV’s value chain that are due to be canceled in the future is 612,288 t of CO2e. All of these credits are based on existing contractual agreements.
Metrics Definitions and Methodologies
The metrics in this table are validated by an external body other than the assurance provider in line with the respective recognized quality standards.
Total carbon credits canceled in the reporting year: Total carbon credits canceled in the reporting year is determined by documenting the number of carbon credits officially retired or canceled within the reporting year. This is done by tracking credit transactions and ensuring they meet regulatory and voluntary offset program requirements. The total value is reported separately for the share by type of project, the share of projects within the EU, and the share of carbon credits that qualify as corresponding adjustment. Potential limitations include the accuracy and completeness of the records, possible delays in the credit cancelation processing, and adherence to evolving regulatory standards.
Recognized quality standards: The metric for reporting total carbon credits canceled in the reporting year per recognized quality standard is determined by tracking and verifying the number of carbon credits that have been officially retired or canceled within the reporting period, ensuring they meet the criteria of established standards such as the Verified Carbon Standard (VCS) or the Gold Standard. This process involves detailed documentation and validation of credit transactions against the recognized quality standards. Potential limitations include the accuracy and completeness of the documentation, delays in the validation and cancelation processes, and the consistency in applying and interpreting the quality standards across different projects and registries.
Total carbon credits to be canceled in the future: This metric is determined by identifying the number of carbon credits allocated for cancelation based on an estimation of future needs. Potential limitations include uncertainties regarding future regulatory changes, market volatility affecting the availability and cost of carbon credits, and the accuracy of estimating future needs.
E1-8 Internal Carbon Pricing
OMV applies internal carbon pricing for investment decisions across all business segments. In the base case, the costs of CO2 emissions are included wherever carbon pricing schemes are in place within the respective countries. Additionally, a stress test based on a “net zero emissions by 2050” scenario is conducted. For this stress test, for the period 2025–2030, shadow prices are applied to all of OMV’s Scope 1 emissions worldwide, except for EU assets that fall outside of the EU ETS. From 2031 onward, the internal carbon prices are applied to 100% of Scope 1 emissions. As internal carbon prices are applied for future investments, they do not apply to the reporting year in which actual carbon prices are considered. These actual carbon prices covered 85% of OMV’s reported Scope 1 emissions in 2024, equivalent to 8.3 mn t of CO2.
The internal carbon prices applied are consistent with the carbon prices included in the mid-term planning (MTP), as well as with the carbon prices used for accounting purposes including impairment testing, calculation of depreciation, and assessments of the useful life according to IFRS. Base case carbon prices are informed by the IEA’s Announced Pledges Scenario (APS) and other external and internal market analyses, while the “net zero emissions by 2050” case prices are largely based on the IEA’s Net Zero Emissions by 2050 (NZE) scenario. The applied carbon prices are detailed in Note 3 – Effects of climate change and the energy transition in the Consolidated Financial Statements.