1.Under the standard methodology, the operator shall calculate combustion emissions per source stream by multiplying the activity data related to the amount of fuel combusted, expressed as terajoules based on net calorific value (NCV), with the corresponding emission factor, expressed as tonnes CO2 per terajoule (t CO2/TJ) consistent with the use of NCV, and with the corresponding oxidation factor.
The competent authority may allow the use of emission factors for fuels, expressed as t CO2/t or t CO2/Nm3. In that case, the operator shall determine combustion emissions by multiplying the activity data related to the amount of fuel combusted, expressed as tonnes or normal cubic metres, with the corresponding emission factor and the corresponding oxidation factor.
2.The operator shall determine process emissions per source stream by multiplying the activity data related to the material consumption, throughput or production output, expressed in tonnes or normal cubic metres with the corresponding emission factor, expressed in t CO2/t or t CO2/Nm3, and the corresponding conversion factor.
3.Where a tier 1 or tier 2 emission factor already includes the effect of incomplete chemical reactions, the oxidation factor or conversion factor shall be set to 1.
1.Under the mass balance methodology, the operator shall calculate the CO2 quantity corresponding to each source stream included in the mass balance by multiplying the activity data related to the amount of material entering or leaving the boundaries of the mass balance, with the material’s carbon content multiplied by [X13,664 t CO 2 /t C,] applying section 3 of Annex II.
2.Notwithstanding Article 49, the emissions of the total process covered by the mass balance shall be the sum of the CO2 quantities corresponding to all source streams covered by the mass balance. CO emitted to the atmosphere shall be calculated in the mass balance as emission of the molar equivalent amount of CO2.
Editorial Information
1.When defining the relevant tiers in accordance with Article 21(1), to determine the activity data and each calculation factor, each operator shall apply the following:
(a)at least the tiers listed in Annex V, in the case of an installation that is a category A installation, or where a calculation factor is required for a source stream that is a commercial standard fuel;
(b)in other cases than those referred to in point (a), the highest tier as defined in Annex II.
However, the operator may apply a tier one level lower than required in accordance with the first subparagraph for category C installations and up to two levels lower for category A and B installations, with a minimum of tier 1, where it shows to the satisfaction of the competent authority that the tier required in accordance with the first subparagraph is technically not feasible or incurs unreasonable costs.
The competent authority may, for a transitional period of up to three years, allow an operator to apply lower tiers than those referred to in the second subparagraph, with a minimum of tier 1, provided that both of the following conditions are met:
(a)the operator shows to the satisfaction of the competent authority that the tier required pursuant to the second subparagraph is technically not feasible or incurs unreasonable costs;
(b)the operator provides an improvement plan indicating how and by when at least the tier required pursuant to the second subparagraph will be reached.
2.For activity data and each calculation factor for minor source streams, the operator shall apply the highest tier which is technically feasible and does not incur unreasonable costs, with a minimum of tier 1.
3.For activity data and each calculation factor for de-minimis source streams, the operator may determine activity data and each calculation factor by using conservative estimations instead of using tiers, unless a defined tier is achievable without additional effort.
4.For the oxidation factor and conversion factor, the operator shall, as a minimum, apply the lowest tiers listed in Annex II.
5.Where the competent authority has allowed the use of emission factors expressed as t CO2/t or t CO2/Nm3 for fuels, and for fuels used as process input or in mass balances in accordance with Article 25, the net calorific value may be monitored using lower tiers than the highest tier as defined in Annex II.
1.The operator shall determine the activity data of a source stream in one of the following ways:
(a)based on continual metering at the process which causes the emissions;
(b)based on aggregation of metering of quantities separately delivered taking into account relevant stock changes.
2.For the purposes of point (b) of paragraph 1, the quantity of fuel or material processed during the reporting period shall be calculated as the quantity of fuel or material purchased during the reporting period, minus the quantity of fuel or material exported from the installation, plus the quantity of fuel or material in stock at the beginning of the reporting period, minus the quantity of fuel or material in stock at the end of the reporting period.
Where it is technically not feasible or would incur unreasonable costs to determine quantities in stock by direct measurement, the operator may estimate those quantities based on one of the following:
(a)data from previous years and correlated with output for the reporting period;
(b)documented procedures and respective data in audited financial statements for the reporting period.
Where the determination of activity data for the entire calendar year is technically not feasible or would incur unreasonable costs, the operator may choose the next most appropriate day to separate a reporting year from the following one, and reconcile accordingly to the calendar year required. The deviations involved for one or more source streams shall be clearly recorded, form the basis of a value representative for the calendar year, and be considered consistently in relation to the next year.
1.For determining the activity data in accordance with Article 27, the operator shall use metering results based on measurement systems under its own control at the installation, provided that all of the following conditions are complied with:
(a)the operator must carry out an uncertainty assessment and ensures that the uncertainty threshold of the relevant tier level is met;
(b)the operator must ensure at least once per year, and after each calibration of measuring instruments, that the calibration results multiplied by a conservative adjustment factor based on an appropriate time series of previous calibrations of that or similar measuring instruments for taking into account the effect of uncertainty in service, are compared with the relevant uncertainty thresholds.
Where tier thresholds approved in accordance with Article 12 are exceeded or equipment found not to conform to other requirements, the operator shall take corrective action without undue delay and notify the competent authority thereof.
2.The operator shall provide the uncertainty assessment referred to in point (a) of paragraph 1 to the competent authority when notifying a new monitoring plan or when it is relevant for a change to the approved monitoring plan.
The assessment shall comprise the specified uncertainty of the applied measuring instruments, uncertainty associated with the calibration, and any additional uncertainty connected to how the measuring instruments are used in practice. Uncertainty related to stock changes shall be included in the uncertainty assessment where the storage facilities are capable of containing at least 5 % of the annual used quantity of the fuel or material considered. When carrying out the assessment, the operator shall take into account the fact that the stated values used to define tier uncertainty thresholds in Annex II refer to the uncertainty over the full reporting period.
The operator may simplify the uncertainty assessment by assuming that the maximum permissible errors specified for the measuring instrument in service, or where lower, the uncertainty obtained by calibration, multiplied by a conservative adjustment factor for taking into account the effect of uncertainty in service, is to be regarded as the uncertainty over the whole reporting period as required by the tier definitions in Annex II, provided that measuring instruments are installed in an environment appropriate for their use specifications.
3.Notwithstanding paragraph 2, the competent authority may allow the operator to use metering results based on measurement systems under its own control at the installation, where the operator provides evidence that the measuring instruments applied are subject to relevant national legal metrological control.
For that purpose, the maximum permissible error in service allowed by the relevant national legislation on legal metrological control for the relevant measuring task may be used as the uncertainty value without providing further evidence.
1.Where, based on a simplified uncertainty assessment, the use of measurement systems outside the operator’s own control, compared to the use of those within the operator’s own control pursuant to Article 28, allows the operator to comply with at least as high a tier, gives more reliable results and is less prone to control risks, the operator shall determine the activity data from measurement systems outside its own control.
To that end, the operator may revert to one of the following data sources:
(a)amounts from invoices issued by a trade partner, provided that a commercial transaction between two independent trade partners takes place;
(b)direct readings from the measurement systems.
2.The operator shall ensure compliance with the applicable tier pursuant to Article 26.
To that end, the maximum permissible error in service allowed by relevant legislation for national legal metrological control for the relevant commercial transaction may be used as uncertainty without providing further evidence.
Where the applicable requirements under national legal metrological control are less stringent than the applicable tier pursuant to Article 26, the operator shall obtain evidence on the applicable uncertainty from the trade partner responsible for the measurement system.
1.The operator shall determine calculation factors either as default values or values based on analysis depending on the applicable tier.
2.The operator shall determine and report calculation factors consistently with the state used for related activity data, referring to the fuel’s or material’s state in which the fuel or material is purchased or used in the emission causing process, before it is dried or otherwise treated for laboratory analysis.
Where such an approach incurs unreasonable costs, or where higher accuracy can be achieved, the operator may consistently report activity data and calculation factors referring to the state in which laboratory analyses are carried out.
1.Where the operator determines calculation factors as default values, it shall, in accordance with the requirement of the applicable tier, as set out in Annexes II and VI, use one of the following values:
(a)standard factors and stoichiometric factors listed in Annex VI;
(b)standard factors used by the Member State for its national inventory submission to the Secretariat of the United Nations Framework Convention on Climate Change;
(c)literature values agreed with the competent authority, including standard factors published by the competent authority, which are compatible with factors referred to in point (b), but they are representative of more disaggregated sources of fuel streams;
(d)values specified and guaranteed by the supplier of a material where the operator can demonstrate to the satisfaction of the competent authority that the carbon content exhibits a 95 % confidence interval of not more than 1 %;
(e)values based on analyses carried out in the past, where the operator can demonstrate to the satisfaction of the competent authority that those values are representative for future batches of the same material.
2.The operator shall specify all default values used in the monitoring plan.
Where the default values change on an annual basis, the operator shall specify the authoritative applicable source of that value in the monitoring plan.
3.The competent authority may only approve a change of default values for a calculation factor in the monitoring plan pursuant to Article 15(2), where the operator provides evidence that the new default value leads to a more accurate determination of emissions.
4.Upon application by the operator, the competent authority may allow that the net calorific value and emission factors of fuels are determined using the same tiers as required for commercial standard fuels provided that the operator submits, at least every three years, evidence that the 1 % interval for the specified calorific value has been met during the last three years.
1.The operator shall ensure that any analyses, sampling, calibrations and validations for the determination of calculation factors are carried out by applying methods based on corresponding EN standards.
Where such standards are not available, the methods shall be based on suitable ISO standards or national standards. Where no applicable published standards exist, suitable draft standards, industry best practice guidelines or other scientifically proven methodologies shall be used, limiting sampling and measurement bias.
2.Where online gas chromatographs or extractive or non-extractive gas analysers are used for emission determination, the operator shall obtain approval from the competent authority for the use of such equipment. The equipment shall be used only with regard to composition data of gaseous fuels and materials. As minimum quality assurance measures, the operator shall ensure that an initial validation and annually repeated validations of the instrument are performed.
3.The result of any analysis shall be used only for the delivery period or batch of fuel or material for which the samples have been taken, and for which the samples were intended to be representative.
For the determination of a specific parameter the operator shall use the results of all analyses made with regards to that parameter.
1.Where calculation factors are determined by analyses, the operator shall submit to the competent authority for approval for each fuel or material a sampling plan in the form of a written procedure, which contains information on methodologies for the preparation of samples, including information on responsibilities, locations, frequencies and quantities, and methodologies for the storage and transport of samples.
The operator shall ensure that the derived samples are representative for the relevant batch or delivery period and free of bias. Relevant elements of the sampling plan shall be agreed with the laboratory carrying out the analysis for the respective fuel or material, and evidence of that agreement shall be included in the plan. The operator shall make the plan available for the purposes of verification pursuant to Regulation (EU) No 600/2012.
2.The operator shall, in agreement with the laboratory carrying out the analysis for the respective fuel or material and subject to the approval of the competent authority, adapt the elements of the sampling plan where analytical results indicate that the heterogeneity of the fuel or material significantly differs from the information on heterogeneity on which the original sampling plan for that specific fuel or material was based.
1.The operator shall ensure that laboratories used to carry out analyses for the determination of calculation factors are accredited in accordance with EN ISO/IEC 17025, for the relevant analytical methods.
2.Laboratories not accredited in accordance with EN ISO/IEC 17025 may only be used for the determination of calculation factors where the operator can demonstrate to the satisfaction of the competent authority that access to laboratories referred to in paragraph 1 is technically not feasible or would incur unreasonable costs and that the non-accredited laboratory meets requirements equivalent to EN ISO/IEC 17025.
3.The competent authority shall deem a laboratory to meet the requirements equivalent to EN ISO/IEC 17025 within the meaning of paragraph 2 where the operator provides, to the extent feasible, in the form of and to a similar level of detail required for procedures pursuant to Article 12(2), evidence in accordance with the second and the third subparagraph of this paragraph.
With respect to quality management, the operator shall produce an accredited certification of the laboratory in conformity with EN ISO/IEC 9001, or other certified quality management systems that cover the laboratory. In the absence of such certified quality management systems, the operator shall provide other appropriate evidence that the laboratory is capable of managing its personnel, procedures, documents and tasks in a reliable manner.
With respect to technical competence, the operator shall provide evidence that the laboratory is competent and able to generate technically valid results using the relevant analytical procedures. Such evidence shall cover at least the following elements:
(a)management of the personnel’s competence for the specific tasks assigned;
(b)suitability of accommodation and environmental conditions;
(c)selection of analytical methods and relevant standards;
(d)where applicable, management of sampling and sample preparation, including control of sample integrity;
(e)where applicable, development and validation of new analytical methods or application of methods not covered by international or national standards;
(f)uncertainty estimation;
(g)management of equipment, including procedures for calibration, adjustment, maintenance and repair of equipment, and record keeping thereof;
(h)management and control of data, documents and software;
(i)management of calibration items and reference materials;
(j)quality assurance for calibration and test results, including regular participation in proficiency testing schemes, applying analytical methods to certified reference materials, or inter-comparison with an accredited laboratory;
(k)management of outsourced processes;
(l)management of assignments, customer complaints, and ensuring timely corrective action.
1.The operator shall apply the minimum frequencies for analyses for relevant fuels and materials listed in Annex VII. Annex VII will be reviewed on a regular basis and in the first instance not more than two years from this Regulation entering into force.
2.The competent authority may allow the operator to use a different frequency than those referred to in paragraph 1, where minimum frequencies are not available or where the operator demonstrates one of the following:
(a)based on historical data, including analytical values for the respective fuels or materials in the reporting period immediately preceding the current reporting period, any variation in the analytical values for the respective fuel or material does not exceed 1/3 of the uncertainty value to which the operator has to adhere with regard to the activity data determination of the relevant fuel or material;
(b)using the required frequency would incur unreasonable costs.
1.The operator shall determine activity-specific emission factors for CO2 emissions.
2.Emission factors of fuels, including when used as process input, shall be expressed as t CO2/TJ.
The competent authority may allow the operator to use an emission factor for a fuel expressed as t CO2/t or t CO2/Nm3 for combustion emissions, where the use of an emission factor expressed as t CO2/TJ incurs unreasonable costs or where at least equivalent accuracy of the calculated emissions can be achieved by using such an emission factor.
3.For the conversion of the carbon content into the respective value of a CO2 related emission factor or vice versa, the operator shall use the factor [X13,664 t CO 2 /t C.]
Editorial Information
1.The operator shall use as a minimum tier 1 to determine oxidation or conversion factors. The operator shall use a value of 1 for oxidation or for a conversion factor where the emission factor includes the effect of incomplete oxidation or conversion.
However, the competent authority may require operators to always use tier 1.
2.Where several fuels are used within an installation and tier 3 is to be used for the specific oxidation factor, the operator may ask for the approval of the competent authority for one or both of the following:
(a)the determination of one aggregate oxidation factor for the whole combustion process and to apply it to all fuels;
(b)the attribution of the incomplete oxidation to one major source stream and use of a value of 1 for the oxidation factor of the other source streams.
Where biomass or mixed fuels are used, the operator shall provide evidence that application of points (a) or (b) of the first subparagraph does not lead to an underestimation of emissions.
1.The operator may determine the activity data of biomass source streams without using tiers and providing analytical evidence regarding the biomass content, where that source stream consists exclusively of biomass and the operator can ensure that it is not contaminated with other materials or fuels.
2.The emission factor of biomass shall be zero.
The emission factor of a mixed fuel or material shall be calculated and reported as the preliminary emission factor determined in accordance with Article 30 multiplied by the fossil fraction of the fuel or material.
3.Peat, xylite and fossil fractions of mixed fuels or materials shall not be considered biomass.
4.Where the biomass fraction of mixed fuels or materials is equal or higher than 97 %, or where due to the amount of the emissions associated with the fossil fraction of the fuel or material it qualifies as a de-minimis source stream, the competent authority may allow the operator to apply no-tier methodologies, including the energy balance method, for determining activity data and relevant calculation factors, unless the respective value is to be used for the subtraction of biomass derived CO2 from emissions determined by means of continuous emission measurement.
1.Where subject to the tier level required and to the availability of appropriate default values as referred to in Article 31(1), the biomass fraction of a specific fuel or material are determined using analyses, the operator shall determine that biomass fraction on the basis of a relevant standard and the analytical methods therein, and apply that standard only if approved by the competent authority.
2.Where the determination of the biomass fraction of a mixed fuel or material by analysis in accordance with paragraph 1 is technically not feasible or would incur unreasonable costs, the operator shall base its calculation on standard emission factors and biomass fraction values for mixed fuels and materials and estimation methods published by the Commission.
In the absence of such standard factors and values, the operator shall either assume the absence of a biomass share or submit an estimation method to determine the biomass fraction to the competent authority for approval. For fuels or materials originating from a production process with defined and traceable input streams, the operator may base such estimation on a mass balance of fossil and biomass carbon entering and leaving the process.
3.By way of derogation from paragraphs 1 and 2 and Article 30, where the guarantee of origin has been established in accordance with Articles 2(j) and 15 of Directive 2009/28/EC for biogas injected into and subsequently removed from a gas network, the operator shall not use analyses for the determination of the biomass fraction.