‘ANNEX XII

Guidelines for determination of emissions or amount of transfer of greenhouse gases by continuous measurement systems

1.   BOUNDARIES AND COMPLETENESS

The provisions of this Annex apply to emissions of greenhouse gases from all activities covered by Directive 2003/87/EC. Emissions may occur at several emission sources in an installation.

The provisions of this Annex apply furthermore to continuous measurement systems used for determination of CO2 flows in pipelines, in particular when used for the transfer of CO2 between installations such as for the capture, transport and geological storage of CO2. For this purpose, the references to emissions in Sections 6 and 7.2 of Annex I shall be interpreted as references to the amount of CO2 transferred in accordance with Section 5.7 of Annex I.

2.   DETERMINATION OF GREENHOUSE GAS EMISSIONS

Tier 1

For each measurement point a total uncertainty of the overall emissions or CO2 flow over the reporting period of less than ± 10 % shall be achieved.

Tier 2

For each measurement point a total uncertainty of the overall emissions or CO2 flow over the reporting period of less than ± 7,5 % shall be achieved.

Tier 3

For each measurement point a total uncertainty of the overall emissions or CO2 flow over the reporting period of less than ± 5 % shall be achieved.

Tier 4

For each measurement point a total uncertainty of the overall emissions or CO2 flow over the reporting period of less than ± 2,5 % shall be achieved.

Overall approach

Total emissions of a greenhouse gas (GHG) from an emission source or the amount of CO2 conducted through the measurement point over the reporting period shall be determined by using the formula below. In case several emission sources exist in one installation and cannot be measured as one, emissions from these emission sources shall be measured separately and summed up to the total emissions of the specific gas over the reporting period in the whole installation.

Determination of the parameters GHG-concentration and flue gas flow shall be carried out according to the provisions of Section 6 of Annex I. For measurement of transferred CO2 in pipelines, Section 6 of Annex I shall apply as if the measurement point were an emission source, as appropriate. For such measurement points no corroborating calculation pursuant to section 6.3 subsection (c) shall be required.

GHG-concentration

The GHG-concentration in the flue gas is determined by continuous measurement at a representative point. The GHG-concentration can be measured by two approaches:

METHOD A

The concentration of GHG is measured directly.

METHOD B

For very high GHG concentrations such as in transport networks, the GHG concentration may be calculated using a mass balance, taking into account measured concentration values of all other components of the gas stream as laid down in the installation’s monitoring-plan:

Flue gas flow

The dry flue gas flow can be determined using one of the following methods.

METHOD A

The flue gas flow Qe is calculated by means of a mass balance approach, taking into account all significant parameters such as input material loads, input airflow, process efficiency, and on the output side the product output, the O2 concentration, SO2 and NOx concentrations.

The specific calculation approach shall be approved by the competent authority as part of the evaluation of the monitoring plan and the monitoring methodology therein.

METHOD B

The flue gas flow Qe is determined by continuous flow measurement at a representative point.’

‘ANNEX XVI

Activity-specific guidelines for determination of greenhouse gas emissions from CO2 capture activities for the purposes of transport and geological storage in a storage site permitted under Directive 2009/31/EC of the European Parliament and of the Council

1.   BOUNDARIES AND COMPLETENESS

The activity-specific guidelines contained in this Annex apply to the monitoring of emissions from CO2 capture activities.

CO2 capture can be performed either by dedicated installations receiving CO2 by transfer from other installations, or by installations carrying out the activities emitting the CO2 to be captured under the same greenhouse gas emissions permit. All parts of the installation related to the purpose of CO2 capture, intermediate storage, transfer to a CO2 transport network or to a site for geological storage of CO2 greenhouse gas emissions shall be included in the greenhouse gas emissions permit. In case the installation carries out other activities covered by Directive 2003/87/EC, the emissions of these activities shall be monitored in accordance with the respective Annexes of these Guidelines.

2.   EMISSIONS FROM CO2 CAPTURE ACTIVITIES

In CO2 capture operations potential emission sources for CO2 include:

—	CO2 transferred to the capture installation,

—	combustion and other associated activities at the installation (capture-related), i.e., fuel and input material use.

3.   QUANTIFICATION OF TRANSFERRED AND EMITTED CO2 AMOUNTS

3.1.   INSTALLATION LEVEL QUANTIFICATION

Emissions are calculated using a complete mass-balance, taking into account the potential CO2 emissions from all emission relevant processes at the installation as well as the amount of CO2 captured and transferred to the transport network.

The emissions of the installation shall be calculated using the following formula:

Ecapture installation  = Tinput  + Ewithout capture  – Tfor storage

With:

Ecapture installation	=	Total greenhouse gas emissions of the capture installation
Tinput	=	Amount of CO2 transferred to the capture installation, determined in accordance with Annex XII and Section 5.7 of Annex I; If the operator can demonstrate to the satisfaction of the competent authority that the total CO2 emissions of the emitting installation are transferred to the capture installation, the competent authority may allow the operator to use the emissions of the emitting installation determined pursuant to Annexes I to XII instead of using CEMS.
Ewithout capture	=	Emissions of the installation if the CO2 were not captured, i.e. the sum of the emissions from all other activities at the installation, monitored in accordance with the respective Annexes;
Tfor storage	=	Amount of CO2 transferred to a transport network or a storage site, determined in accordance with Annex XII and section 5.7 of Annex I.

In cases, in which CO2 capture is carried out by the same installation as the one from which the captured CO2 originates, Tinput is zero.

In cases of stand-alone capture installations, Ewithout capture represents the amount of emissions that occur from other sources than the CO2 transferred to the installation for capture, such as combustion emissions from turbines, compressors, heaters. These emissions can be determined by calculation or measurement in accordance with the appropriate activity specific Annex.

In the case of stand-alone capture installations, the installation transferring CO2 to the capture installation shall deduct the amount Tinput from its own emissions.

3.2.   DETERMINATION OF TRANSFERRED CO2

The amount of CO2 transferred from and to the capture installation shall be determined in accordance with Section 5.7 of Annex I by means of CEMS carried out in accordance with Annex XII. As a minimum, Tier 4 as defined in Annex XII shall be applied. Only if it is shown to the satisfaction of the competent authority that this tier approach is technically not feasible, may a next lower tier be used for the relevant emission source.’

‘ANNEX XVII

Activity-specific guidelines for determination of greenhouse gas emissions from the transport of CO2 by pipelines for geological storage in a storage site permitted under Directive 2009/31/EC

1.   BOUNDARIES AND COMPLETENESS

The boundaries for monitoring and reporting of emissions from CO2 transport by pipeline are laid down in the transport network’s greenhouse gas emissions permit, including all installations functionally connected to the transport network, including booster stations and heaters. Each transport network has as a minimum one starting point and one ending point, each connected to other installations carrying out one or more of the activities capture, transport or geological storage of CO2. Starting and ending points can include bifurcations of the transport network and national borders. Starting and ending points as well as the installations they are connecting to, shall be laid down in the greenhouse gas emissions permit.

2.   QUANTIFICATION OF CO2 EMISSIONS

During the transport of CO2 by pipeline, potential emission sources for CO2 emissions include:

—	combustion and other processes at installations functionally connected to the transport network, e.g. booster stations,

—	fugitive emissions from the transport network,

—	vented emissions from the transport network,

—	emissions from leakage incidents in the transport network.

A transport network using Method B below shall not add to its calculated level of emissions CO2 received from another ETS installation, and shall not subtract from its calculated level of emissions any CO2 which is transferred to another ETS installation.

2.1.   QUANTIFICATION APPROACHES

Operators of transport networks may choose one of the following approaches:

METHOD A

The emissions of the transport network are determined using a mass balance according to the following formula:

With:

Emissions	=	Total CO2 emissions of the transport network [t CO2];
Eown activity	=	Emissions from the transport network’s own activity (i.e. not stemming from CO2 transported), like from fuel use in booster stations, monitored in accordance with the respective Annexes of these Guidelines;
TIN,i	=	Amount of CO2 transferred to the transport network at entry point i, determined in accordance with Annex XII and Section 5.7 of Annex I;
TOUT,j	=	Amount of CO2 transferred out of the transport network at exit point j, determined in accordance with Annex XII and Section 5.7 of Annex I.

METHOD B

Emissions shall be calculated taking into account the potential CO2-emissions from all emission relevant processes at the installation as well as the amount of CO2 captured and transferred to the transport facility, using the following formula:

Emissions [tCO2] = CO2 fugitive + CO2 vented + CO2 leakage events + CO2 installations

With:

Emissions	=	Total CO2 emissions of the transport network [tCO2];
CO2 fugitive	=	Amount of fugitive emissions [tCO2] from CO2 transported in the transport network, including from seals, valves, intermediate compressor stations and intermediate storage facilities;
CO2 vented	=	Amount of vented emissions [tCO2] from CO2 transported in the transport network;
CO2 leakage events	=	Amount of CO2 [tCO2] transported in the transport network, which is emitted as the result of failure of one or more components of the transport network;
CO2 installations	=	Amount of CO2 [tCO2] being emitted from combustion or other processes functionally connected to the pipeline transport in the transport network, monitored in accordance with the respective Annexes of these Guidelines.

2.2.   QUANTIFICATION REQUIREMENTS

In choosing either Method A or Method B, the operator has to demonstrate to the competent authority that the chosen methodology will lead to more reliable results with lower uncertainty of the overall emissions, using best available technology and knowledge at the time of application for the greenhouse gas emissions permit, without leading to unreasonable costs. If Method B is chosen the operator shall demonstrate to the satisfaction of the competent authority that the overall uncertainty for the annual level of greenhouse gas emissions for the operator’s transport network does not exceed 7,5 %.

2.2.1.   SPECIAL REQUIREMENTS FOR METHOD A

The amount of CO2 transferred from and to the transport network shall be determined in accordance with Section 5.7 of Annex I by means of CEMS carried out in accordance with Annex XII. As a minimum, Tier 4 as defined in Annex XII shall be applied. Only if it is shown to the satisfaction of the competent authority that this tier approach is technically not feasible, may a next lower tier be used for the relevant emission source.

2.2.2.   SPECIAL REQUIREMENTS FOR METHOD B

2.2.2.1.   Combustion emissions

Potential combustion emissions from fuel use shall be monitored in accordance with Annex II.

2.2.2.2.   Fugitive emissions from the transport network

Fugitive emissions include the emissions from the following types of equipment:

—

seals,

—	measurement devices,

—

valves,

—	intermediate compressor stations,

—	intermediate storage facilities.

Average emission factors EF (expressed in g CO2/unit time) per piece of equipment/occurrence where fugitive emissions can be expected shall be determined by the operator at the beginning of operation, and at the latest by the end of the first reporting year in which the transport network is in operation. These factors shall be reviewed by the operator at least every 5 years in the light of the best available techniques in this field.

Overall emissions shall be calculated by multiplying the number of pieces of equipment in each category by the emission factor and adding up the results for the single categories as shown in the equation below:

The number of occurrences is the number of pieces of the given equipment per category, multiplied by the number of time units per year.

2.2.2.3.   Emissions from leakage events

The operator of the transport network shall provide proof of the network integrity by using representative (spatial and time-related) temperature and pressure data. If the data indicates that a leakage has occurred, the operator shall calculate the amount of CO2 leaked with a suitable methodology documented in the monitoring plan, based on industry best practice guidelines, e.g. by using the differences in temperature and pressure data compared to integrity related average pressure and temperature values.

2.2.2.4.   Vented emissions

The operator shall provide in the monitoring plan an analysis regarding potential situations of venting emissions, including for maintenance or emergency reasons, and provide a suitable documented methodology to calculate the amount of CO2 vented, based on industry best practice guidelines.

2.2.2.5.   Validation of calculation result for fugitive and leaked emissions

Given that monitoring of CO2 transferred to and from the transport network will in any case be carried out for commercial reasons, the operator of a transport network shall use Method A for validation of the results of Method B at least once annually. In this regard, for measurement of transferred CO2 lower tiers defined in Annex XII may be used.’

‘ANNEX XVIII

Activity-specific guidelines for the geological storage of CO2 in a storage site permitted under Directive 2009/31/EC

1.   BOUNDARIES

Boundaries for monitoring and reporting of emissions from geological storage of CO2 shall be site-specific and shall be based on the delimitation of the storage site and storage complex as specified in the permit pursuant Directive 2009/31/EC. All emission sources from the CO2 injection facility shall be included in the greenhouse gas emissions permit. Where leakages from the storage complex are identified and lead to emissions or release of CO2 to the water column, they shall be included as emission sources for the respective installation until corrective measures pursuant to Article 16 of Directive 2009/31/EC have been taken and emissions or release into the water column from that leakage can no longer be detected.

2.   DETERMINATION OF CO2 EMISSIONS

Potential emissions sources for CO2 emissions from the geological storage of CO2 include:

—	fuel use at booster stations and other combustion activities such as on-site power plants,

—	venting at injection or at enhanced hydrocarbon recovery operations,

—	fugitive emissions at injection,

—	breakthrough CO2 from enhanced hydrocarbon recovery operations,

—

leakage.

A storage site shall not add to its calculated level of emissions CO2 received from another installation, and shall not subtract from its calculated level of emissions any CO2 which is transferred to another installation or geologically stored in the storage site.

2.1.   EMISSIONS FROM FUEL USE

Combustion emissions from above ground activities shall be determined in accordance with Annex II.

2.2.   VENTED AND FUGITIVE EMISSIONS FROM INJECTION

Emissions from venting and fugitive emissions shall be determined as follows:

CO2 emitted [tCO2] = V CO2 [tCO2] + F CO2 [tCO2]

With

V CO2= amount of CO2 vented

F CO2= amount of CO2 from fugitive emissions

V CO2 shall be determined by using CEMS according to Annex XII of these Guidelines. If the application of CEMS would lead to unreasonable costs, the operator may include in the monitoring plan an appropriate methodology based on industry best practice, subject to approval by the competent authority.

F CO2 shall be considered as one source, meaning that the uncertainty requirements of Annex XII and Section 6.2 of Annex I apply to the total value and not to the individual emission points. The operator shall provide in the monitoring plan an analysis regarding potential sources of fugitive emissions, and provide a suitable documented methodology to calculate or measure the amount of F CO2, based on industry best practice guidelines. For the determination of F CO2 data collected pursuant to Article 13 and Annex II 1.1 (e) – (h) of Directive 2009/31/EC for the injection facility can be used, where they comply with the requirements of these Guidelines.

2.3.   VENTED AND FUGITIVE EMISSIONS FROM ENHANCED HYDROCARBON RECOVERY OPERATIONS

The combination of enhanced hydrocarbon recovery (EHR) with geological storage of CO2 is likely to provide an additional source stream of emissions, namely the breakthrough of CO2 with the produced hydrocarbons. Additional emission sources from EHR operations include:

—	the oil-gas separation units and gas recycling plant, where fugitive emissions of CO2 could occur,

—	the flare stack, where emissions might occur due to the application of continuous positive purge systems and during depressurisation of the hydrocarbon production installation,

—	the CO2 purge system, to avoid that high concentrations of CO2 extinguish the flare.

Any fugitive emissions occurring will usually be rerouted in a gas containment system, to the flare or CO2 purge system. Any such fugitive emissions or CO2 vented e.g. from the CO2 purge system shall be determined in accordance to Section 2.2 of this Annex.

Emissions from the flare stack shall be determined in accordance with Annex II, taking into account potential inherent CO2 in the flare gas.

3.   LEAKAGE FROM THE STORAGE COMPLEX

Monitoring shall start in the case that any leakage results in emissions or release to the water column. Emissions resulting from a release of CO2 into the water column shall be deemed to be equal to the amount released to the water column.

Monitoring of emissions or of release into the water column from a leakage shall continue until corrective measures pursuant to Article 16 of Directive 2009/31/EC have been taken and emissions or release into the water column can no longer be detected.

Emissions and release to the water column shall be quantified as follows:

With

L CO2	=	mass of CO2 emitted or released per calendar day due to the leakage. For each calendar day for which leakage is monitored it shall be calculated as the average of the mass leaked per hour [tCO2/h] multiplied by 24. The mass leaked per hour shall be determined according to the provisions in the approved monitoring plan for the storage site and the leakage. For each calendar day prior to commencement of monitoring, the mass leaked per day shall be taken to equal the mass leaked per day for the first day of monitoring.
Tstart	=	the latest of: (a) the last date when no emissions or release to the water column from the source under consideration were reported; (b) the date the CO2 injection started; (c) another date such that there is evidence demonstrating to the satisfaction of the competent authority that the emission or release to the water column cannot have started before that date.
Tend	=	the date by which corrective measures pursuant to Article 16 of Directive 2009/31/EC have been taken and emissions or release to the water column can no longer be detected.

Other methods for quantification of emissions or release into the water column from leakages can be applied if approved by the competent authority on the basis of providing a higher accuracy than the above approach.

The amount of emissions leaked from the storage complex shall be quantified for each of the leakage events with a maximum overall uncertainty over the reporting period of ± 7,5 %. In case the overall uncertainty of the applied quantification approach exceeds ± 7,5 %, an adjustment shall be applied, as follows:

CO2, Reported [tCO2] = CO2, Quantified [tCO2] × (1 + (UncertaintySystem [%]/100) – 0,075)

With

CO2, Reported	:	Amount of CO2 to be included into the annual emission report with regards to the leakage event in question;
CO2, Quantified	:	Amount of CO2 determined through the used quantification approach for the leakage event in question;
UncertaintySystem	:	The level of uncertainty which is associated to the quantification approach used for the leakage event in question, determined according to section 7 of Annex I to these guidelines.’