DANISH emission inventories for stationary combustion plants Inventories until NERI Technical Report no. 795 2010 AU NATIONAL ENVIRONMENTAL RESEARCH INSTITUTE AARHUS UNIVERSITY
[Blank page]
Danish emission inventories for stationary combustion plants Inventories until NERI Technical Report no. 795 2010 Malene Nielsen Ole-Kenneth Nielsen Marlene Plejdrup Katja Hjelgaard AU NATIONAL ENVIRONMENTAL RESEARCH institute AARHUS UNIVERSITY
'DWDVKHHW Series title and no.: NERI Technical Report No. 795 Title: Danish emission inventories for stationary combustion plants Subtitle: Inventories until Authors: Department: Malene Nielsen, Ole-Kenneth Nielsen. Marlene Plejdrup, Katja Hjelgaard Department of Policy Analysis Publisher: National Environmental Research Institute Aarhus University - Denmark URL: http://www.neri.dk Year of publication: October 2010 Editing completed: September 2010 Financial support: Please cite as: No external financial support Nielsen, M., Nielsen, O.-K., Plejdrup, M. & Hjelgaard, K., 2010: Danish Emission Inventories for Stationary Combustion Plants. Inventories until. National Environmental Research Institute, Aarhus University, Denmark. 236 pp. NERI Technical Report No. 795. http://www.dmu.dk/pub/fr795.pdf. Reproduction permitted provided the source is explicitly acknowledged Abstract: Keywords: Layout: Emission inventories for stationary combustion plants are presented and the methodologies and assumptions used for the inventories are described. The pollutants considered are SO 2, NO x, NMVOC, CH 4, CO, CO 2, N 2O, NH 3, particulate matter, heavy metals, dioxins, HCB and PAH. The CO 2 emission in was 16 % lower than in. However, fluctuations in the emission level are large as a result of electricity import/export. The emission of CH 4 has increased due to increased use of lean-burn gas engines in combined heating and power (CHP) plants. However, the emission has decreased in recent years due to structural changes in the Danish electricity market. The N 2O emission was higher in than in but the fluctuations in the timeseries are significant. A considerable decrease of the SO 2, NO x and heavy metal emissions is mainly a result of decreased emissions from large power plants and waste incineration plants. The combustion of wood in residential plants has increased considerably in recent years resulting in increased emission of PAH, particulate matter and CO. The emission of NMVOC has increased since as a result of both the increased combustion of wood in residential plants and the increased emission from lean-burn gas engines. The dioxin emission decreased since due to flue gas cleaning on waste incineration plants. However in recent years the emission has increased as a result of the increased combustion of wood in residential plants. Emission, combustion, power plants, district heating, CHP, co-generation, incineration, MSW, residential combustion, SO 2, NO x, NMVOC, CH 4, CO, CO 2, N 2O, PM, NH 3, heavy metals, dioxin, PAH, HCB, greenhouse gas, emission inventory, uncertainty. Ann-Katrine Holme Christoffersen ISBN: 978-87-7073-192-8 ISSN (electronic): 1600-0048 Number of pages: 236 Internet version: The report is available in electronic format (pdf) at NERI's website http://www.dmu.dk/pub/fr795.pdf
&RQWHQWV /LVWRIDEEUHYLDWLRQV 3UHIDFH 6XPPDU\ 6DPPHQGUDJ,QWURGXFWLRQ 1DWLRQDOHPLVVLRQV )XHOFRQVXPSWLRQGDWD *UHHQKRXVHJDVHPLVVLRQ 4.1 CO 2 24 4.2 CH 4 26 4.3 N 2O 28 62 12 [ 1092&DQG&2 5.1 SO 2 30 5.2 NO x 32 5.3 NMVOC 33 5.4 CO 35 3DUWLFXODWHPDWWHU30 +HDY\PHWDOV 3$+ 'LR[LQ +&% 1+ 6HFWRUDOWUHQG 12.1 1A1 Energy industries 53 12.2 1A2 Industry 63 12.3 1A4 Other Sectors 69 *HRJUDSKLFDOGLVWULEXWLRQRIWKHHPLVVLRQV 0HWKRGRORJLFDOLVVXHV 14.1 Emission source categories 82 14.2 Tiers 84 14.3 Large point sources 84
14.4 Area sources 85 14.5 Activity rates, fuel consumption 85 14.6 Town gas 86 14.7 Emission factors 88 14.8 Disaggregation to specific industrial subcategories 106 8QFHUWDLQW\ 15.1 Methodology 107 15.2 Results 110 4$4&DQGYHULILFDWLRQ 16.1 Reference approach 112 16.2 External review 113 16.3 Key source analysis 114,PSURYHPHQWVDQGUHFDOFXODWLRQVVLQFHUHSRUWLQJLQ 3ODQQHGLPSURYHPHQWV &RQFOXVLRQ 5HIHUHQFHV $QQH[HV
/LVWRIDEEUHYLDWLRQV As Arsenic BAT Best Available Techniques BREF BAT Reference Document Cd Cadmium CH 4 Methane CHP Combined Heat and Power CLRTAP Convention on Long-Range Transboundary Air Pollution CO Carbon Monoxide CO 2 Carbon Dioxide CORINAIR CORe INventory on AIR emissions Cr Chromium CRF Common Reporting Format Cu Copper DEA Danish Energy Agency DEPA Danish Environmental Protection Agency EEA European Environment Agency EMEP European Monitoring and Evaluation Programme EU ETS EU Emission Trading Scheme GHG GreenHouse Gas HCB Hexachlorobenzene Hg Mercury HM Heavy metals IIR Informative Inventory Report IPCC Intergovernmental Panel on Climate Change LPG Liquefied Petroleum Gas LRTAP Long-Range Transboundary Air Pollution LULUCF Land Use, Land-Use Change and Forestry MSW Municipal Solid Waste N 2O Nitrous Oxide NECD European Commissions National Emissions Ceiling Directive NH 3 Ammonia Ni Nickel NIR National Inventory Report NMVOC Non-Methane Volatile Organic Compounds NO x Nitrogen Oxides PAH Polycyclic Aromatic Hydrocarbons Pb Lead PCB Polychlorinated biphenyl PCDD/-F Poly Chlorinated Dibenzo Dioxins and Furans PM Particulate Matter PM 10 Particulate Matter < 2.5 µm PM 2.5 Particulate Matter < 10 µm POP Persistent Organic Pollutant Se Selenium SNAP Selected Nomenclature for Air Pollution SO 2 Sulphur dioxide TSP Total Suspended Particulates UHC Unburned hydrocarbons UNECE United Nations Economic Commission for Europe Zn Zinc 5
6
3UHIDFH On behalf of the Ministry of the Environment and the Ministry of Climate and Energy, the Danish National Environmental Research Institute (NERI) at Aarhus University prepares the Danish atmospheric emission inventories and reports the results on an annual basis to the United Nations Framework Convention on Climate Change (UNFCCC) and to the United Nations Economic Commission for Europe (UNECE) Convention on Long-Range Transboundary Air Pollution (LRTAP Convention). This report forms part of the documentation for the inventories and covers emissions from stationary combustion plants. The results of inventories up to are included. The report updates the four reports published in,, and 2009. The, and 2009 updates of this report were reviewed by Jan Erik Johnsson from the Technical University of Denmark, Bo Sander from Elsam Engineering and Annemette Geertinger from FORCE Technology. 7
6XPPDU\ Danish emission inventories are prepared on an annual basis and are reported to the United Nations Framework Convention on Climate Change (UNFCCC or Climate Convention) and to the Kyoto Protocol as well as to the United Nations Economic Commission for Europe (UN- ECE) Convention on Long-Range Transboundary Air Pollution (LRTAP Convention). Furthermore, a greenhouse gas emission inventory is reported to the European Union (EU) due to the EU as well as the individual member states being party to the Climate Convention. Four pollutants are estimated for reporting to the European Commissions National Emissions Ceiling Directive (NECD). The annual Danish emission inventories are prepared by the Danish National Environmental Research Institute (NERI), Aarhus University (AU). The inventories include the following pollutants relevant to stationary combustion: CO 2, CH 4, N 2O, SO 2, NO x, NMVOC, CO, particulate matter, NH 3, heavy metals, dioxins, PAH and HCB. In addition to annual national emissions, the report includes emission data for a number of source categories. Every five years the reporting includes data on the geographical distribution of the emissions, a projection of emissions, data and details of the activity data, e.g. fuel consumption on which the inventories are based. The inventories for stationary combustion are based on the Danish energy statistics and on a set of emission factors for various source categories, technologies and fuels. Plant specific emissions for large combustion sources are incorporated into the inventories. This report provides detailed background information on the methodology and references for the input data in the inventory - energy statistics and emission factors. The emission factors are based on either national references or on international guidebooks (EEA, ; IPCC, ). The majority of the country-specific emission factors refer to: Danish legislation, Danish research reports or calculations based on plant-specific emission data from a considerable number of large point sources. The plant-specific emission factors are provided by plant operators, e.g. in annual environmental reports or in the EU ETS 1. In the inventory for the year, 70 stationary combustion plants are specified as large point sources. The point sources include large power plants, municipal waste incineration plants, industrial combustion plants and petroleum refining plants. The fuel consumption of these large point sources corresponds to 58 % of the overall fuel consumption of stationary combustion. In the total fuel consumption was 7 % higher than in ; the fossil fuel consumption, however, was 7 % lower than in. The use of coal has decreased whereas the use of natural gas and biomass has increased. The fuel consumption for stationary combustion plants fluctuates due to variation in the import/export of electricity from year to year. 1 EU Emission Trading Scheme. 8
Stationary combustion plants account for more than 50 % of the national emission for the following pollutants: SO 2, CO 2, heavy metals (except Cu, Pb and Zn), PM 10, PM 2.5, dioxin, HCB and PAH. Furthermore, the emission from stationary combustion plants accounts for more than 10 % of the national emission for the following pollutants: NO x, CO, NMVOC, TSP, Cu, Pb and Zn. Stationary combustion plants account for less than 10 % of the national emission of CH 4, N 2O and NH 3. Public electricity and heat production are the most important stationary combustion emission source for CO 2, N 2O, SO 2 and NO x. Lean-burn gas engines installed in decentralised combined heating and power (CHP) plants and combustion of biomass in residential plants are the two largest emission sources for CH 4. Residential plants represent the most important stationary combustion emission source for CO, NMVOC, particulate matter, PAH and dioxin. Wood combustion in residential plants is the predominant emission source. Industrial plants, public electricity and heat production plants and residential plants are the main emission sources for the different heavy metals. The greenhouse gas (GHG) emission trend follows the CO 2 emission trend closely. Both the CO 2 and the total GHG emission were lower in than in : CO 2 by 16 % and GHG by 15 %. However, fluctuations in the GHG emission level are large. The fluctuations in the time-series are mainly a result of electricity import/export but also of outdoor temperature variations from year to year that results in fluctuations in the consumption for space heating. The CH 4 emission from stationary combustion has increased by a factor of 3.5 since. This is mainly a result of the considerable number of lean-burn gas engines installed in CHP plants in Denmark during the s. In recent years the emission has declined. This is due to structural changes in the Danish electricity market, which means that the fuel consumption in gas engines has decreased. The CH 4 emission from residential plants has increased since due to increased combustion of wood in residential plants. The emission of N 2O was 7 % higher in than in. The fluctuations follow the fluctuations of the fuel consumption, which is a result of import/export of electricity. SO 2 emission from stationary combustion plants has decreased by 90 % since. The considerable emission decrease is mainly a result of the reduced emission from electricity and heat production due to installation of desulphurisation technology and the use of fuels with lower sulphur content. These improvements are a result of both sulphur tax laws and legislation concerning sulphur content of fuels, emission ceilings for large power plants and emission limits for several plant categories. The NO x emission from stationary combustion plants has decreased by 56 % since. The reduced emission is mainly a result of the reduced 9
emission from electricity and heat production due to installation of low NO x burners and selective catalytic reduction (SCR) units. The installation of the technical improvements was launched by legislation including emission ceilings for large power plants and lower emission limits for several plant categories. The fluctuations in the emission time-series follow fluctuations in electricity import/export. In the wood consumption in residential plants was four times the level. This increase causes considerable changes in the emission of NMVOC, CO, PM and PAH from stationary combustion due to the fact that residential wood combustion is a major emission source for these pollutants. However, a change of technology (installation of modern stoves) has caused decreasing emission factors for several pollutants. The CO emission from stationary combustion has increased 16 % since. The increase in CO emission from residential plants is less than the increase in wood consumption because the CO emission factor for wood combustion in residential plants has decreased since. Furthermore, the emission from straw-fired farmhouse boilers has decreased considerably. The NMVOC emission from stationary combustion plants has increased 50 % since. The increased NMVOC emission is mainly a result of the increasing wood combustion in residential plants and the increased use of lean-burn gas engines. The emission from straw-fired farmhouse boilers has decreased. The emission of TSP, PM 10 and PM 2.5 has increased by 57-62 % since due to the increase of wood combustion in residential plants. The emission of PAHs has increased by 120-170 % since, also a result of the increased combustion of wood in residential plants. All the heavy metal emissions have decreased considerably since between 65 % and 87 %; Zn, however, only 5 %. This is a result of the installation and improved performance of gas cleaning devices in municipal waste incineration plants and large power plants. Dioxin emission has decreased 55 % since mainly due to installation of dioxin filters in municipal solid waste (MSW) incineration plants that was necessary due to the emission limit included in Danish legislation. However, the emission from residential plants has increased due to the increased wood combustion in the sector. This has caused an increase of dioxin emission from stationary combustion since. The uncertainty level of the Danish greenhouse gas (GHG) emission from stationary combustion is estimated to be within a range of ±2.1 % and the trend in GHG emission (-) is -14.6 % ± 1.4 %-age points 2. 2 Tier 1 approach. This year a tier 2 approach for uncertainty estimates have also been applied. 10
6DPPHQGUDJ Opgørelser over de samlede danske luftemissioner rapporteres årligt til Klimakonventionen (United Nation Framework Convention on Climate Change, UNFCCC) og Kyotoprotokollen samt til UNECE (United Nations Economic Commission for Europe) Konventionen om langtransporteret grænseoverskridende luftforurening (UNECE Convention on Long-Range Transboundary Air Pollution, der forkortes LRTAP Convention). Endvidere rapporteres drivhusgasemissionen til EU, fordi EU såvel som de enkelte medlemslande har ratificeret klimakonventionen. Der udarbejdes også opgørelser til rapportering til Europa- Kommissionens NEC (National Emissions Ceiling) direktiv. De danske emissioner opgøres og rapporteres af Danmarks Miljøundersøgelser (DMU) ved Aarhus Universitet (AU). Emissionsopgørelserne omfatter følgende stoffer af relevans for stationær forbrænding: CO 2, CH 4, N 2O, SO 2, NO x, NMVOC, CO, partikler, NH 3, tungmetaller, dioxin, PAH og HCB. Foruden de årlige opgørelser over samlede nationale emissioner, rapporteres også sektoropdelt emission. Hvert femte år rapporteres endvidere en geografisk fordeling af emissionerne, fremskrivning af emissionerne samt de aktivitetsdata fx brændselsforbrug der ligger til grund for opgørelserne. Emissionsopgørelserne for stationære forbrændingsanlæg (ikke mobile kilder) er baseret på den danske energistatistik og på et sæt emissionsfaktorer for forskellige sektorer, teknologier og brændsler. Anlægsspecifikke emissionsdata for store anlæg, som fx kraftværker, indarbejdes i opgørelserne. Denne rapport giver detaljeret baggrundsinformation om den anvendte metode samt referencer for de data der ligger til grund for opgørelsen energistatistikken og emissionsfaktorerne. Emissionsfaktorerne stammer enten fra danske referencer eller fra internationale guidebøger (EEA, 2009 og IPCC, ) udarbejdet til brug for denne type emissionsopgørelser. De danske referencer omfatter miljølovgivning, danske rapporter samt middelværdier baseret på anlægsspecifikke emissionsdata fra et betydeligt antal større værker. Anlægsspecifikke emissionsfaktorer oplyses af anlægsejere, bl.a. i grønne regnskaber og i CO 2-kvoteindberetninger. I emissionsopgørelsen for er 70 stationære forbrændingsanlæg defineret som punktkilder. Punktkilderne omfatter: kraftværker, decentrale kraftvarmeværker, affaldsforbrændingsanlæg, industrielle forbrændingsanlæg samt raffinaderier. Brændselsforbruget for disse anlæg udgør 58 % af det samlede brændselsforbrug for stationære forbrændingsanlæg. Variationen i årlig import/eksport af el medvirker til at brændselsforbruget til stationære forbrændingsanlæg varierer. I var det samlede brændselsforbruget 7 % højere end i, mens forbruget af fossile brændsler var 7 % lavere. Forbruget af kul er faldet, mens forbruget af naturgas og af biobrændsler er steget. 11
For følgende stoffer udgør emissionen fra stationær forbrænding over 50 % af den nationale emission: SO 2, CO 2, tungmetaller (dog ikke Cu, Pb og Zn), PM 10, PM 2.5, dioxin, HCB og PAH. Endvidere udgør emissionen over 10 % for NO x, CO, NMVOC, TSP, Cu, Pb og Zn. Stationær forbrænding bidrager med mindre end 10 % af den nationale emission af CH 4, N 2O og NH 3. Indenfor stationær forbrænding er kraftværker og decentrale kraftvarmeværker den betydeligste emissionskilde for CO 2, N 2O, SO 2 og NO x. Gasmotorer installeret på decentrale kraftvarmeværker er sammen med forbrænding af biomasse i forbindelse med beboelse de største emissionskilder for CH 4. Emissioner fra kedler, brændeovne mv. i forbindelse med beboelse er den betydeligste emissionskilde for CO, NMVOC, partikler, dioxin og PAH. Det er især forbrænding af træ, som bidrager til disse emissioner. Både industrianlæg, kraftværker/kraftvarmeværker samt villakedler/- brændeovne er væsentlige emissionskilder for de forskellige tungmetaller. I rapporten vises tidsserier for emissioner fra stationær forbrænding. Udviklingen i drivhusgasemissionen følger udviklingen i CO 2-emissionen ganske tæt. Både CO 2-emissionen og den samlede drivhusgasemission fra stationær forbrænding er lavere i end i. CO 2 er 16 % lavere og drivhusgasemissionen er 15 % lavere. Emissionerne fluktuerer dog betydeligt, primært pga. variationerne i import/eksport af el men også pga. varierende udetemperatur og deraf følgende brændselsforbrug til rumopvarmning. CH 4-emissionen fra stationær forbrænding er steget med en faktor 3,5 siden. Denne stigning skyldes primært, at der i erne blev installeret et betydeligt antal gasmotorer på decentrale kraftvarmeværker. De senere år er emissionen dog faldet lidt. Som følge af de ændrede afregningsregler i henhold til det frie elmarked. Emissionen fra beboelse er steget væsentligt de senere år pga. den øgede forbrænding af træ i brændeovne mv. Emissionen af N 2O var 7 % højere i end i. Emissionen af N 2O fluktuerer som følge af variationerne i import/eksport af el. SO 2-emissionen fra stationær forbrænding er faldet med 90 % siden. Den store reduktion er primært et resultat af installering af afsvovlningsanlæg fra el- og fjernvarmeproducerende anlæg samt brug af brændsler med lavere svovlindhold. Dette er sket på baggrund af en indført svovlafgift, grænseværdier for svovlindhold i brændsler, emissionskvotebestemmelser for centrale kraftværker samt emissionsgrænseværdier. NO x-emissionen fra stationær forbrænding er faldet med 56 % siden. Reduktionen er primært et resultat af, at emissionen fra el- og fjernvarmeproducerende anlæg er faldet som følge af, at der benyttes lav-no x-brændere på flere anlæg og at der er idriftsat NO x- røggasrensning på flere store kraftværker. Baggrunden herfor er emissi- 12
onskvotebestemmelser for de centrale kraftværker samt skærpede emissionsgrænseværdier for flere anlægstyper. NO x-emissionen fluktuerer som følge af variationen i import/eksport af el. Mængden af træ forbrændt i villakedler og brændeovne var i fire gange så højt som i. Dette har stor betydning for emissionstidsserierne for en række emissionskomponenter for hvilke netop træ, anvendt i villakedler/brændeovne, er en væsentlig emissionskilde: NMVOC, CO, partikler og PAH. Emissionen fra nyere brændeovne mv. er lavere end for de ældre, idet forbrændingsteknologien er forbedret, og stigningen i emissioner er således lavere end stigningen i brændselsforbruget. CO-emissionen fra stationær forbrænding er steget 16 % siden. Emissionen fra brændeovne er steget, men samtidig er emissionen fra halmfyrede gårdanlæg faldet. Emissionen af NMVOC fra stationær forbrænding er øget med 50 % siden. Stigningen er primært et resultat af det øgede forbrug af træ i forbindelse med beboelse (brændeovne mv.) og idriftsættelsen af gasmotorer på decentrale kraftvarmeværker. Emissionen af TSP er steget 57 % siden år - igen på grund af den øgede brug af træ i brændeovne og små villakedler. Emissionen af de forskellige PAH er er af samme grund steget 120-170 % siden. Emissionen af dioxin var 55 % lavere i end i. Dette fald skyldes primært installering af dioxinrensningsanlæg på affaldsforbrændingsanlæg som alle affaldsforbrændingsanlæg iht. forbrændingsbekendtgørelsen 3 skulle idriftsætte senest i. Emissionen fra brændeovne er dog samtidig steget og dette har resulteret i en stigning i dioxinemissionen de senere år. Tungmetalemissionerne er faldet betydeligt siden. Emissionen af de enkelte tungmetaller er reduceret mellem 65 % og 87 %, Zn dog kun 5 %. Reduktionen er et resultat af den forbedrede røggasrensning på affaldsforbrændingsanlæg og på kraftværker. Emissionen af drivhusgasser er bestemt med en usikkerhed på ±2,1 %. Drivhusgasemissionen er siden faldet 14,6 % ± 1,4 %-point 4. 3 Bekendtgørelse om anlæg der forbrænder affald, Bekendtgørelse 162 af 11. marts. 4 Resultater af Tier 1 approach. I år er der endvidere beregnet usikkerhed med tier 2 approach. 13
,QWURGXFWLRQ Danish emission inventories are prepared on an annual basis and are reported to the United Nations Framework Convention on Climate Change (UNFCCC or Climate Convention) and to the Kyoto Protocol as well as to the United Nations Economic Commission for Europe (UN- ECE) Convention on Long-Range Transboundary Air Pollution (LRTAP Convention). Furthermore, a greenhouse gas emission inventory is reported to the European Union (EU), due to the EU as well as the individual member states being party to the Climate Convention. Four pollutants are estimated for reporting to the European Commissions National Emissions Ceiling Directive (NECD). The annual Danish emission inventories are prepared by the Danish National Environmental Research Institute (NERI), Aarhus University (AU) on behalf of the Ministry of the Environment and the Ministry of Climate and Energy. The data in this report do not include emissions from Greenland and the Faroe Islands. Stationary combustion plants include power plants, district heating plants, non-industrial and industrial combustion plants, industrial process burners, petroleum-refining plants, as well as combustion in oil/gas extraction and in pipeline compressors. Emissions from flaring in oil/gas production and from flaring carried out in refineries are not covered by this report. This report presents detailed emission inventories and time-series for emissions from stationary combustion plants. Furthermore, emissions from stationary combustion plants are compared with national emissions. The methodology and references for the emission inventories for stationary combustion plants are described. Furthermore, the report includes key source analysis, uncertainty estimates and reporting of QA/QC activities. 14
1DWLRQDOHPLVVLRQV An overview of the national emission inventories for including all emission source categories is shown in Table 1 to 4 5. The emission inventories reported to the LRTAP Convention and to the Climate Convention are organised in six main source categories and a number of subcategories. The emission source (QHUJ\ covers combustion in stationary and mobile sources as well as fugitive emissions from the energy source category. Emissions from incineration of municipal waste in power plants or district heating plants are included in the source category (QHUJ\, rather than in the source category :DVWH. Links to the latest emission inventories can be found at the NERI home page: http://www.dmu.dk/luft/emissioner/home+of+inventory/ or via http://www.dmu.dk/. Surveys of the latest inventories and the updated emission factors are also available on the NERI homepage. Note that according to convention decisions emissions from certain specific sources are not included in the inventory totals. These emissions are reported as memo items and are thus estimated, but not included in the totals. The data for the national emission included in this report does not include memo items. CO 2 emission from combustion of biomass is not included in national totals, but reported as a memo item. Likewise emissions from international bunkers and from international aviation are not included in national totals. Further emission data for stationary combustion plants are provided in Chapters 4 to 11. Table 1 National greenhouse gas emission for the year (Nielsen et al., 2010a). Pollutant CO 2 CH 4 N 2O HFCs, PFCs & SF 6 Unit Gg CO 2 equivalent 1. Energy 492 12 580 438-2. Industrial Processes 13 60 - - 897 3. Solvent and Other Product Use 65-27 - 4. Agriculture - 3 872 6 154-5. Land-Use Change and Forestry 492-9 - 6. Waste 29 1 107 105 - National emission excluding LULUCF 1) 63 845 National emission including LULUCF 2) 64 346 1) Not including Land Use, Land-Use Change and Forestry. 2) Including Land Use, Land-Use Change and Forestry. 5 Emissions from Greenland and the Faroe Islands are not included. 15
Table 2 National emissions reported to the LRTAP Convention (Nielsen et al., 2010b). Pollutant NO x Gg CO NMVOC Gg Gg SO 2 Gg NH 3 Gg TSP Mg PM 10 Mg PM 2.5 Mg 1. Energy 151 432 66 19 2 32 288 29 075 27 012 2. Industrial Processes 0 0 10 0 0 - - - 3. Solvent and Other Product Use - - 27 - - - - - 4. Agriculture 0 3 2 0 71 11 855 5 914 1 267 5. Land-Use Change and Forestry - - - - - - - - 6. Waste 0 1 0 1 0 14 13 13 National emission 152 436 106 20 74 44 158 35 002 28 291 Table 3 National heavy metal (HM) emissions reported to the LRTAP Convention (Nielsen et al., 2010b). Pollutant Pb Mg Cd Mg Hg Mg As Mg Cr Mg Cu Mg Ni Mg Se Mg Zn Mg 1. Energy 4.37 0.41 0.77 0.43 1.10 9.48 7.43 1.76 12.32 2. Industrial Processes 0.07 0.00 - - - 0.05 - - 0.63 3. Solvent and Other Product Use - - - - - - - - - 4. Agriculture 0.04 0.00 0.00 0.00 0.01 0.00 0.01 0.00 0.00 5. Land-Use Change and Forestry - - - - - - - - - 6. Waste 3.74 0.01 0.05 0.00 0.02 0.12 0.01 0.00 14.60 National emission 8.21 0.42 0.82 0.43 1.12 9.65 7.45 1.77 27.56 Table 4 National PAH, dioxin and hexachlorobenzene (HCB) emissions reported to the LRTAP Convention (Nielsen et al., 2010b). Pollutant Ben- zo(a)- pyrene Mg Ben- zo(b)- fluoranthene Mg Ben- zo(k)- fluoranthene Mg Indeno (1,2,3- c,d) pyrene Mg Dioxin g I-teq HCB kg 1. Energy 4.80 5.11 2.83 3.42 21.46 0.54 2. Industrial Processes - - - - 0.01-3. Solvent and Other Product Use - - - - - - 4. Agriculture 0.12 0.12 0.05 0.04 0.03-5. Land-Use Change and Forestry - - - - - - 6. Waste 0.09 0.11 0.09 0.13 10.04 0.01 7. Other - - - - - - National emission 5.02 5.34 2.97 3.59 31.54 0.55 16
)XHOFRQVXPSWLRQGDWD In the total fuel consumption for stationary combustion plants was 531 PJ of which 423 PJ was fossil fuels and 108 PJ was biomass. Fuel consumption distributed according to the stationary combustion subcategories is shown in Figure 1. The majority - 58 % - of all fuels is combusted in the source category, 3XEOLF HOHFWULFLW\ DQG KHDW SURGXFWLRQ Other source categories with high fuel consumption are 5HVLGHQWLDO and,qgxvwu\. Fuel consumption including biomass 1A4a Commercial/ Institutional 3% 1A2 Industry 13% 1A1c Other energy industries 5% 1A4b i Residential 16% 1A1b Petroleum refining 3% 1A4c i Agriculture/ Forestry 2% 1A1a Electricity and heat production 58% Fuel consumption, fossil fuels 1A4a Commercial/ Institutional 3% 1A2 Industry 14% 1A1c Other energy industries 7% 1A4b i Residential 11% 1A1b Petroleum refining 4% 1A4c i Agriculture/ Forestry 1% 1A1a Electricity and heat production 60% Figure 1 Fuel consumption of stationary combustion source categories, (based on DEA (2009a)). Coal and natural gas are the most utilised fuels for stationary combustion plants. Coal is mainly used in power plants and natural gas is used in power plants and decentralised combined heating and power (CHP) plants, as well as in industry, district heating, residential plants and offshore gas turbines (see Figure 2). Detailed fuel consumption rates are shown in Appendix 4. 17
200 180 160 Fuel consumption,pj 140 120 100 80 60 40 20 0 COAL COKE OVEN COKE PETROLEUM COKE WOOD MUNICIP. WASTES STRAW RESIDUAL OIL GAS OIL KEROSENE FISH & RAPE OIL NATURAL GAS LPG REFINERY GAS BIOGAS BIO PROD GAS 1A1a Electricity and heat production 1A1b Petroleum refining 1A1c Other energy industries 1A2 Industry 1A4a Commercial/ Institutional 1A4b i Residential 1A4c i Agriculture/ Forestry NATURAL GAS 32% FISH & RAPE OIL 0.4% KEROSENE 0.02% LPG 0.3% REFINERY GAS 3% GAS OIL RESIDUAL OIL 4% 3% STRAW 3% BIOGAS 0.7% BIO PROD GAS 0.02% MUNICIP. WASTES 8% COAL 32% COKE OVEN COKE 0.2% PETROLEUM COKE 2% WOOD 12% Figure 2 Fuel consumption of stationary combustion, disaggregated to fuel type (based on DEA, 2009a). Fuel consumption time-series for stationary combustion plants are presented in Figure 3 6. The fuel consumption for stationary combustion was 7 % higher in than in, while the fossil fuel consumption was 7 % lower and the biomass fuel consumption 153 % higher than in. The consumption of natural gas and biomass has increased since, whereas coal consumption has decreased. 6 Time-series 1980 onwards are included in Appendix 15. 18
800 Fuel consumption, PJ 700 600 500 400 300 200 Total 100 0 1A1a Electricity and heat production 1A1c Other energy industries 1A4a Commercial/ Institutional 1A4c i Agriculture/ Forestry 1A1b Petroleum refining 1A2 Industry 1A4b i Residential Stationary comb. Total 800 700 600 500 400 300 200 100 0 Fuel consumption, PJ BIOMASS GAS LIQUID SOLID Figure 3 Fuel consumption time-series, stationary combustion (based on DEA, 2009a). The fluctuations in the time-series for fuel consumption are mainly a result of electricity import/export but also of outdoor temperature variations from year to year. This, in turn, leads to fluctuations in emission levels. The fluctuations in electricity trade, fuel consumption, CO 2 and NO x emission are illustrated and compared in Figure 4. In the Danish electricity import was large causing relatively low fuel consumption, whereas the fuel consumption was high in due to a large electricity export. In the net electricity import was 5234 TJ, whereas there was a 3420 TJ electricity import in. The large electricity export that occurs some years is a result of low rainfalls in Norway and Sweden causing insufficient hydropower production in both countries. To be able to follow the national energy consumption for statistical and reporting purposes, the Danish Energy Agency produces a correction of the actual fuel consumption and CO 2 emission without random variations in electricity imports/exports and in ambient temperature. This fuel consumption trend is also illustrated in Figure 4. The corrections are included here to explain the fluctuations in the time-series for fuel rate and emission. 19
Degree days Fuel consumption adjusted for electricity trade 4500 4000 3500 3000 V \ D G 2500 H U J H ' 1500 Fuel consumption, PJ 800 700 600 500 400 300 200 100 1000 500 0 0 Coal, brown coal and coke Natural gas Residual oil Gas oil Other fossil fuels Waste, biomass part Other biomass Electricity trade NO x emission 30 180 20 10 160 140 120 Total Electricity import, PJ 0-10 -20-30 -40 NO x, Gg 100 80 60 40 20 0 1A1a Public electricity and heat production -50-60 1A1a Public electricity and heat production Total CO 2 emission adjustment as a result of electricity trade GHG emission 10 60 50 Total Adjustment of CO2 emission, Tg 5 0-5 -10 GHG, Tg CO 2 eq. 40 30 20 10 0 CH4 CO2 N2O -15 CO2 CH4 N2O Total Fluctuations in electricity trade compared to fuel consumption Adjusted GHG emission, stationary combustion plants 800 100 60 Fuel consumption, PJ 700 Fossil fuel 600 500 400 Electricity 300 200 Coal 100 0 80 60 40 20 0-20 -40-60 Electricity export, PJ GHG, Tg CO 2 eq. 50 40 30 20 10 0 Total CO2 CH4 N2O CO2 CH4 N2O Total Figure 4 Comparison of time-series fluctuations for electricity trade, fuel consumption and NO x emission (based on DEA 2009b). Fuel consumption time-series for the subcategories to stationary combustion are shown in Figure 5, 6 and 7. 20
Fuel consumption for (QHUJ\,QGXVWULHV fluctuates due to electricity trade as discussed above. The fuel consumption in was 13 % higher than in. The fluctuation in electricity production is based on fossil fuel consumption in the subcategory (OHFWULFLW\ DQG +HDW 3URGXFWLRQ. The energy consumption in 2WKHUHQHUJ\LQGXVWULHV is mainly natural gas used in gas turbines in the off-shore industry. The biomass fuel consumption in (QHUJ\,QGXVWULHV added up to 56 PJ, which is 3.1 times the level in. The fuel consumption in,qgxvwu\ was the same in as it was in (Figure 6). However, in recent years the fuel consumption has been decreasing and the consumption in was 15 % lower than in. The biomass fuel consumption in,qgxvwu\ in added up to 8 PJ, which is a 36 % increase since. The fuel consumption in 2WKHU6HFWRUV has decreased 6 % since (Figure 7). The biomass part of the fuel consumption has increased from 16 % in to 40 % in. Wood consumption in residential plants in was 2.4 times the consumption in year. Time-series for subcategories are shown in Chapter 12. 600 Fuel consumption, PJ 500 400 300 200 Total 100 0 1A1a Electricity and heat production 1A1c Other energy industries 1A1b Petroleum refining 1A1 Energy industries 600 500 Fuel consumption, PJ 400 300 200 100 0 BIOMASS GAS LIQUID SOLID Figure 5 Fuel consumption time-series for subcategories - 1A1 Energy Industries. 21
90 80 Total 70 60 50 40 30 20 10 0 Fuel consumption, PJ 1A2 Industry 90 80 Fuel consumption, PJ 70 60 50 40 30 20 10 0 BIOMASS GAS LIQUID SOLID Figure 6 Fuel consumption time-series for subcategories - 1A2 Industry.Ã 140 120 Total Fuel consumption, PJ 100 80 60 40 20 0 1A4a Commercial/ Institutional 1A4c i Agriculture/ Forestry 1A4b i Residential 1A4 Other energy sectors 140 120 Fuel consumption, PJ 100 80 60 40 20 0 BIOMASS GAS LIQUID SOLID Figure 7 Fuel consumption time-series for subcategories - 1A4 Other Sectors. 22
*UHHQKRXVHJDVHPLVVLRQ The national greenhouse gas (GHG) emission in was 64,346 Gg CO 2 equivalent, including Land-Use, Land-Use Change and Forestry (LU- LUCF) or 63,845 Gg CO 2 equivalent, excluding LULUCF. The greenhouse gas pollutants HFCs, PFCs and SF 6 are not emitted from combustion plants and, as such, only the pollutants CO 2, CH 4 and N 2O are considered below. The global warming potentials of CH 4 and N 2O applied in greenhouse gas inventories refer to the second IPCC assessment report (IPCC ): 1 g CH 4 equals 21 g CO 2 1 g N 2O equals 310 g CO 2 The GHG emissions from stationary combustion are listed in Table 5. The emission from stationary combustion accounted for 51 % of the national GHG emission (excluding LULUCF) in. The CO 2 emission from stationary combustion plants accounts for 63 % of the national CO 2 emission (excluding LULUCF). The CH 4 emission accounts for 8 % of the national CH 4 emission and the N 2O emission for 4 % of the national N 2O emission. Table 5 Greenhouse gas emission, 1). CO 2 CH 4 N 2O Gg CO 2 equivalent 1A1 Fuel Combustion, Energy industries 23 553 183 133 1A2 Fuel Combustion, Manufacturing Industries and Construction 1) 4 081 20 43 1A4 Fuel Combustion, Other sectors 1) 4 239 218 81 Emission from stationary combustion plants 31 872 421 257 National emission (excluding LULUCF) 50 665 5 559 6 724 % Emission share for stationary combustion 63 % 8 % 4 % 1) Only stationary combustion sources of the category is included. CO 2 is the most important GHG pollutant accounting for 97.9 % of the GHG emission (CO 2 eq.) from stationary combustion. CH 4 accounts for 1.3 % and N 2O for 0.8 % of the GHG emission (CO 2 eq.) from stationary combustion (Figure 8). 23
CH 4 1.3% N 2 O 0.8% CO 2 97.9% Figure 8 Stationary combustion - GHG emission (CO 2 equivalent), contribution from each pollutant. Figure 9 depicts the time-series of GHG emission (CO 2 eqv.) from stationary combustion and it can be seen that the GHG emission development follows the CO 2 emission development very closely. Both the CO 2 and the total GHG emission are lower in than in, CO 2 by 16 % and GHG by 15 %. However, fluctuations in the GHG emission level are large. 60 50 Total GHG, Tg CO 2 eq. 40 30 20 CO 2 10 0 CH 4 N 2 O CO2 CH4 N2O Total Figure 9 GHG emission time-series for stationary combustion. The fluctuations in the time-series are largely a result of electricity import/export but also of outdoor temperature variations from year to year. The fluctuations follow the fluctuations in fuel consumption discussed in Chapter 3. As mentioned in Chapter 3, the Danish Energy Agency estimates a correction of the actual CO 2 emission without random variations in electricity imports/exports and in ambient temperature. The GHG emission corrected for electricity import/export and ambient temperature has decreased by 24 % since and the CO 2 emission by 25 %. These data are included here to explain the fluctuations in the emission time-series. &2 The carbon dioxide (CO 2) emission from stationary combustion plants is one of the most important GHG emission sources. Thus the CO 2 emission from stationary combustion plants accounts for 63 % of the national 24
CO 2 emission. Table 6 lists the CO 2 emission inventory for stationary combustion plants for. (OHFWULFLW\DQGKHDWSURGXFWLRQ accounts for 66 % of the CO 2 emission from stationary combustion. This share is somewhat higher than the fossil fuel consumption share for this category, which is 60 % (Figure 1). This is due to a large share of coal in this category. Other large CO 2 emission sources are,qgxvwu\ and 5HVLGHQWLDO plants. These are the source categories, which also account for a considerable share of fuel consumption. Table 6 CO 2 emission from stationary combustion plants, 1). CO 2 Gg 1A1a Public electricity and heat production 21 032 1A1b Petroleum refining 912 1A1c Other energy industries 1 608 1A2 Industry 4 081 1A4a Commercial/Institutional 818 1A4b Residential 3 012 1A4c Agriculture/Forestry/Fisheries 409 Total 31 872 1A4a Commercial / Institutional 3% 1A2 Industry 13% 1A1c Other energy industries 5% 1A1b Petroleum refining 3% 1) Only emission from stationary combustion plants in the categories is included. 1A4b Residential 9% 1A4c Agriculture / Forestry / Fisheries 1.3% 1A1a Public electricity and heat production 66% In the Danish inventory the source category (OHFWULFLW\DQGKHDWSURGXFWLRQ is further disaggregated. The CO 2 emission from each of the subcategories is shown in Table 7. The largest subcategory is power plant boilers >300MW. Table 7 CO 2 emission from subcategories to 1A1a Electricity and heat production. Subcategory Subcategory name CO 2, Gg ID (SNAP) 0101 Public power à 010100 Public power 0 010101 Combustion plants 300MW (boilers) 16 094 010102 Combustion plants 50MW and < 1 460 300 MW (boilers) 010103 Combustion plants <50 MW (boilers) 432 010104 Gas turbines 1 875 010105 Stationary engines 829 0102 District heating plants 010200 District heating plants 010201 Combustion plants 300MW (boilers) 4 010202 Combustion plants 50MW and < 47 300 MW (boilers) 010203 Combustion plants <50 MW (boilers) 285 010204 Gas turbines 0 010205 Stationary engines 8 Public power, gas turbines 9% Public power, boilers < 50 MW 2% Public power, boilers > 50MW and < 300 MW 7% Public power, stationary engines 4% District heating, boilers < 50 MW 1% Public power, boilers > 300MW (boilers) 77% CO 2 emission from combustion of biomass fuels is not included in the total CO 2 emission data because biomass fuels are considered CO 2 neutral. The CO 2 emission from biomass combustion is reported as a memo item in the Climate Convention reporting. In the CO 2 emission from biomass combustion was 11 688 Gg. In Figure 10 the fuel consumption share (fossil fuels) is compared to the CO 2 emission share disaggregated to fuel origin. Due to the higher CO 2 emission factor for coal than for oil and gas, the CO 2 emission share from coal combustion is higher than the fuel consumption share. Coal accounts for 40 % of the fossil fuel consumption and for 51 % of the CO 2 25
emission. Natural gas accounts for 42 % of the fossil fuel consumption but only for 31 % of the CO 2 emission. NATURAL GAS 42% KEROSENE 0.03% Fossil fuel consumption share. LPG 0.3% GAS OIL 5% REFINERY GAS 3% RESIDUAL OILPLASTIC 4% WASTE 4% Figure 10 CO 2 emission, fuel origin. COAL 40% COKE OVEN COKE 0.2% PETROLEUM COKE 2% GAS OIL 5% RESIDUAL OIL 4% CO 2 emission, fuel origin. NATURAL GAS 31% KEROSENE 0.03% PLASTIC WASTE 4% LPG 0.3% PETROLEUM COKE 2% REFINERY GAS 3% COAL 51% COKE OVEN COKE 0.4% Time-series for CO 2 emission are provided in Figure 11. Despite an increase in fuel consumption of 7 % since the CO 2 emission from stationary combustion has decreased by 16 % because of the change of fuel type used. The fluctuations in total CO 2 emission follow the fluctuations in CO 2 emission from (OHFWULFLW\DQGKHDWSURGXFWLRQ (Figure 11) and in coal consumption (Figure 4). The fluctuations are a result of electricity import/export as discussed in Chapter 3. 70 60 50 Total 40 30 20 10 0 CO 2, Tg 1A1a Public electricity and heat production 1A1c Other energy industries 1A4a Commercial / Institutional 1A4c Agriculture / Forestry / Fisheries 1A1b Petroleum refining 1A2 Industry 1A4b Residential Total Figure 11 CO 2 emission time-series for stationary combustion plants. &+ The methane (CH 4) emission from stationary combustion plants accounts for 8 % of the national CH 4 emission. Table 8 lists the CH 4 emission inventory for stationary combustion plants in. (OHFWULFLW\DQGKHDWSUR GXFWLRQ accounts for 43 % of the CH 4 emission from stationary combustion, which is somewhat less than the fuel consumption share. The emission from residential plants adds up to 42 % of the emission. 26
Table 8 CH 4 emission from stationary combustion plants, 1). CH 4 Mg 1A1a Public electricity and heat production 8 643 1A1b Petroleum refining 4 1A1c Other energy industries 45 1A2 Industry 976 1A4a Commercial/Institutional 848 1A4b Residential 8 477 1A4c Agriculture/Forestry/Fisheries 1 040 Total 20 033 1A4b Residential 42% 1A4a Commercial / Institutional 4% 1A4c Agriculture / Forestry / Fisheries 5% 1A2 Industry 5% 1) Only emission from stationary combustion plants in the source categories is included. 1A1a Public electricity and heat production 44% 1A1b Petroleum refining 0.02% 1A1c Other energy industries 0.2% The CH 4 emission factor for reciprocating gas engines is much higher than for other combustion plants due to the continuous ignition/burnout of the gas. Lean-burn gas engines have an especially high emission factor as discussed in Chapter 14.7.3. A considerable number of leanburn gas engines are in operation in Denmark and in these plants accounted for 49 % of the CH 4 emission from stationary combustion plants (Figure 12). Most engines are installed in CHP plants and the fuel used is either natural gas or biogas. Residential wood combustion is also a large emission source. Other stationary combustion plants 16% Gas engines 49% Residential wood combustion 35% Figure 12 CH 4 emission share for gas engines and residential wood combustion,. Figure 13 shows the time-series for CH 4 emission. The CH 4 emission from stationary combustion has increased by a factor of 3.5 since. This results from the considerable number of lean-burn gas engines installed in CHP plants in Denmark during the s. Figure 14 provides time-series for the fuel consumption rate in gas engines and the corresponding increase of CH 4 emission. The decline in later years is due to structural changes in the Danish electricity market, which means that the fuel consumption in gas engines has been decreasing. The emission from residential plants has increased since due to increased combustion of biomass in residential plants. Combustion of wood accounted for more than 80 % of the emission from residential plants in. 27
30 CH 4, Gg 25 20 15 10 5 Total 0 40 35 30 25 20 15 10 5 0 Fuel consumption, PJ NATURAL GAS BIOGAS 30 25 20 15 10 5 0 1A1a Public electricity and heat production 1A1b Petroleum refining 1A1c Other energy industries 1A2 Industry 1A4a Commercial / Institutional 1A4b Residential 1A4c Agriculture / Forestry / Fisheries Total Figure 13 CH 4 emission time-series for stationary combustion plants. CH 4 emission, Gg Gas engines Other stationary combustion plants Figure 14 Fuel consumption and CH 4 emission from gas engines, time-series. 1 2 The nitrous oxide (N 2O) emission from stationary combustion plants accounts for 4 % of the national N 2O emission. Table 9 lists the N 2O emission inventory for stationary combustion plants in. (OHFWULFLW\ DQG KHDW SURGXFWLRQ accounts for 40 % of the N 2O emission from stationary combustion. 28
Table 9 N 2O emission from stationary combustion plants, 1). N 2O Mg 1A1a Public electricity and heat production 332 1A4b Residential 27% 1A1b Petroleum refining 34 1A1c Other energy industries 62 1A2 Industry 138 1A4a Commercial / Institutional 1A4a Commercial/Institutional 22 3% 1A4b Residential 221 1A2 Industry 17% 1A4c Agriculture/Forestry/Fisheries 19 Total 829 1) Only emission from stationary combustion plants in the source categories is included. 1A4c Agriculture / Forestry / Fisheries 2% 1A1a Public electricity and heat production 40% 1A1c Other energy industries 7% 1A1b Petroleum refining 4% Figure 15 shows time-series for N 2O emission. The N 2O emission from stationary combustion has increased by 7 % from to, but again fluctuations in emission level due to electricity import/export are considerable. 1.2 1.0 0.8 0.6 0.4 0.2 0.0 N 2 O, Gg Total 1A1a Public electricity and heat production 1A1c Other energy industries 1A4a Commercial / Institutional 1A4c Agriculture / Forestry / Fisheries 1A1b Petroleum refining 1A2 Industry 1A4b Residential Total Figure 15 N 2O emission time-series for stationary combustion plants. 29
62 12 [ 1092&DQG&2 The emissions of sulphur dioxide (SO 2), nitrogen oxides (NO x), nonvolatile organic compounds (NMVOC) and carbon monoxide (CO) from Danish stationary combustion plants are presented in Table 10. The emission of these pollutants is included in the reporting to both the Climate Convention and the LRTAP Convention. Emissions of SO 2, NO x and NMVOC are also included in the reporting to the National Emissions Ceiling Directive (NECD). The NECD reporting also includes NH 3. SO 2 from stationary combustion plants accounts for 83 % of the national emission. NO x, CO and NMVOC account for 33 %, 38 % and 21 % of national emissions, respectively. Table 10 SO 2, NO x, NMVOC and CO emission, 1). Pollutant NO x Gg CO Gg NMVOC Gg SO 2 Gg 1A1 Fuel consumption, Energy industries 32.6 8.2 1.9 6.6 1A2 Fuel consumption, Manufacturing Industries and Construction 1) 9.6 12.9 0.4 5.4 1A4 Fuel consumption, Other sectors 1) 8.2 144.0 20.1 4.3 Emission from stationary combustion plants 50.4 165.1 22.3 16.3 Emission share for stationary combustion 33 38 21 83 1) Only emissions from stationary combustion plants in the source categories are included. 62 Stationary combustion is the most important emission source for SO 2 accounting for 83 % of the national emission. Table 11 presents the SO 2 emission inventory for the stationary combustion subcategories. (OHFWULFLW\DQGKHDWSURGXFWLRQis the largest emission source accounting for 39 % of the emission. However, the SO 2 emission share is lower than the fuel consumption share for this source category, which is 58 %. This is a result of effective flue gas desulphurisation equipment installed in power plants combusting coal. In the Danish inventory the source category (OHFWULFLW\ DQG KHDW SURGXFWLRQ is further disaggregated. Figure 16 shows the SO 2 emission from (OHFWULFLW\ DQG KHDW SURGXFWLRQ on a disaggregated level. Power plants >300MW th are the main emission source, accounting for 70 % of the emission. The SO 2 emission from industrial plants is 33 %, a remarkably high emission share compared with fuel consumption. The main emission sources in the industrial category are combustion of coal and residual oil, but emissions from the cement industry is also a considerable emission source. Ten years ago SO 2 emission from the industrial category only accounted for a small part of the emission from stationary combustion, but as a result of reduced emissions from power plants the share has now increased. 30