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UNFCCC/CCNUCC CDM – Executive Board Page 1 PROJECT DESIGN DOCUMENT FORM FOR CDM PROJECT ACTIVITIES (F-CDM-PDD) Version 04.1 PROJECT DESIGN DOCUMENT (PDD) Title of the project activity Version number of the PDD Completion date of the PDD Project participant(s) Host Party(ies) Sectoral scope and selected methodology(ies) Estimated amount of annual average GHG emission reductions Aksu Wind Farm Project, Turkey 1.0 30/04/2013 Aksu Temiz Enerji Elektrik Uretim Sanayi ve Ticaret A. S. (private entity) Turkey Scope number : 1 Sectoral scope : Energy industries (renewable - / non-renewable sources) Methodology: “ACM0002: Consolidated baseline methodology for grid-connected electricity generation from renewable sources -- Version 13.0.0” 118,737 tCO2-eq UNFCCC/CCNUCC CDM – Executive Board Page 2 SECTION A. Description of project activity A.1. Purpose and general description of project activity Basic Description: Aksu Wind Farm Project, Turkey (Hereafter referred to as “The Project”) is a large scale wind farm project located in Yahyalı District, Kayseri Province of Turkey. The Project is owned by Aksu Temiz Enerji Elektrik Uretim Sanayi ve Ticaret A. S. (Hereafter referred to as “The Project Proponent”), a private entity. Technical Description: The installed capacity of the project is 72 MW, and the project involves installation and operation of 36 wind turbines, each having a rated power output of 2 MW. The turbines will be of Vestas brand, V1002.0MW model, and IEC IIIA class. The diameter of the area swept by the blades will be 100 meters and the hub height will be 80 meters. The output voltage of each turbine will be 690 VAC, and this will be stepped up to medium voltage at 33.6 kV. This voltage will again be increased by a power transformer to high voltage at 154 kV and the wind farm will be connected to Camlica-I HEPP substation at this 154 kV level as a single group via an overhead transmission line and from this point the energy will be fed to the national grid. The estimated annual net electricity generation of the project will be about 194,003 MWh. This electrical energy will replace electrical energy of the national grid, based mainly on various fossil fuel sources like natural gas and coal. The expected annual emission reduction to be caused by the project will be around 118,737 tonnes of CO2e. For a 7-year crediting period the expected emission reductions will be about 825,899 tonnes of CO2e. The operation of the project and electricity generation started in 2012 and the expected operational life of the project is 20 years. Description of sources and gases included in the project boundary: Baseline Emission Sources included in the project boundary are the generation mix of the national grid whose CO2 emissions are displaced due to the project activity. Project Activity Emission Sources included in the project boundary are those sources emitting gases and particulate matters during construction and operation of the project activity. However, these are minor sources with emissions of very small amounts; so their emissions are neglected and they are excluded. Only CO 2 is included as the gas whose emissions and/or emission reductions will be taken into account due to the project activity. 1) The purpose of the project activity: The purpose of the project activity is to generate renewable electrical energy utilising wind as the primary energy source and deliver this energy to the national grid of Turkey. This energy will help supply Turkey’s ever-increasing electricity demand through a clean, sustainable, and reliable technology. The project will displace the same amount of electricity that would otherwise be generated by the fossil fired power plants dominating the national grid. Being the first operational wind farm in Kayseri Province, the project will help renewable energy become more widespread in Turkey. 1.a. The scenario existing prior to the start of the implementation of the project activity: UNFCCC/CCNUCC CDM – Executive Board Page 3 The scenario existing prior to the start of the implementation of the project activity was no electricity generation since the project is a greenfield project. Without the implementation of the project, the same amount of energy would be generated by other power plants of the national grid. Considering the general fossil fuel domination in the national grid, a natural gas or coal fired thermal power plant on average would generate this energy. This imaginary power plant would also emit greenhouse gases including CO2 and particulate matters. Since the project will emit no greenhouse gases within its boundary and no leakage is in question, an emission caused by the net electricity generation displaced by the project activity was produced prior to the implementation of the project. 1.b. The project scenario: The project scenario involves implementation of a wind farm utilising wind as the primary energy source to generate electrical energy and delivery of the generated electricity to the national grid. 36 wind turbines, a high voltage overhead transmission line, a switchyard, an administrative and control building and other necessary minor structures will be installed within the proposed project activity. Necessary measures have been and will be taken during both in the constructional and operational phases of the project in order not to cause any harmful impact on environmental, economical and social structure of the region. All the related legislation and regulations are observed. In addition, the project proponent will make contributions to the sustainable development of the region. 1.c. The baseline scenario: The baseline scenario is the same as the scenario existing prior to the start of implementation of the project activity. 2) Greenhouse gas emission reduction mechanism of the proposed project activity: The project activity will reduce greenhouse gas emissions as reference to the baseline scenario taking into account that it is a zero emission project. No greenhouse gas or particulate matter emission will take place within project boundary and no leakage emissions will occur. Hence, a net emission reduction from the baseline emission level to zero level will result with the energy generated by the project that will displace the energy that would otherwise be generated by the fossil fuel fired power plants in the national grid. Although many harmful gases including the greenhouse gases and particulate matters will be avoided by the emission reduction process, only CO 2 will be considered in the emission reduction. 3) The view of the project participants (The Project Proponent) on the contribution of the project activity to sustainable development: The project activity will result in many positive impacts on the sustainable development of the region. Environment: The electricity produced by the project activity will replace the electricity that would otherwise have been produced by the generation mix of the grid that is mainly composed of fossil fuel fired power plants like natural gas and coal. With the replacement of this energy and resultant avoidance of fossil fuel consumption, not only CO2 emission will be prevented, but the emission of other greenhouse and various harmful gases and particulate matters will also not occur. As a result, the negative impacts of these pollutants will be reduced. During constructional phase of the project activity, roads to the project site area and the power plant itself on the project site area will be built. Mainly some few amount of dust emission will take place UNFCCC/CCNUCC CDM – Executive Board Page 4 during the construction. Other emissions are negligible. Maximum effort will be shown to keep this dust emission as low as possible and all the related national regulations will be observed. Most of the project site area is agricultural fields owned by the inhabitants from the surrounding villages. The project developer made a commitment to solve this problem in an optimal way to satisfy the land owners. Real estate easement agreements were made with land owners to lease the lands for the licence period of the power plant, which is 49 years. So, this issue can be assumed as having been mitigated and solved. The land owners will be able to use parts of their lands that are not used by the wind farm structures within technical limits for agricultural purposes. Landscape arrangements will be made to keep the impact on project site area as low as possible as compared to its original form. Social development The jobs that will be created by the project activity will be high quality jobs requiring professional skills and training. Furthermore, the personnel to be employed in the project will be trained on subjects like occupational health and safety, first aid and fire protection. As a result, employment quality will be increased in the region as compared to the baseline in which more ordinary jobs not requiring professional skills and training would be produced, if any. The Project Proponent intends to make a positive contribution to the livelihood of the poor in the region. In this respect, local people and local authorities and representatives were consulted and their related needs and requests were questioned. As a result, the project proponent undertook the construction of a community health centre built in Dikme Village, the nearest settlement to the project site. This community health centre will ease the access to health care services in the region compared to the baseline. Economical and technological development: Economically, the main positive effect will be on quantitative employment and income generation. Local people will be given priority when employing new personnel for the wind farm depending on their qualifications and professional skills. This will cause an increase in employment quantity and income in the region as compared to the baseline scenario. Without the project, no jobs at all or jobs with lower quality with lower incomes would be generated in the baseline scenario. The project activity will be the first operational wind farm in Kayseri Province. Kayseri Province is an industrially developed part of the Central Anatolian Region of Turkey and had been the only private distribution region of Turkey for a long time before the widespread privatization in electricity distributions of Turkey began. Implementation of the project activity will enhance wind power technology especially in local level. Technological improvements, research and development and production of auxiliary equipment related with wind power technology will be enhanced with the implementation of the project activity. A.2. Location of project activity A.2.1. Host Party(ies) The host party is Turkey. A.2.2. Region/State/Province etc. Central Anatolian Region / Kayseri Province / Yahyalı District UNFCCC/CCNUCC CDM – Executive Board Page 5 A.2.3. City/Town/Community etc. The project site is about 35 km away from Yahyalı District Centre, near Dikme Village. Other nearby villages are Karaköy, Delialiuşağı and Avlağa. The nearest turbine to the Dikme Village is about 600 meters away. A.2.4. Physical/Geographical location Location of the project is given in the following figure including the maps of the project region and the turbine layout and the table giving the final coordinates of the individual turbines. (a) (b) UNFCCC/CCNUCC CDM – Executive Board Page 6 (c) Figure 1. Maps showing the project location and layout of the turbines. (a) Project location in Turkey. (b) Project location in Central Anatolian Region and Kayseri Province. (c) Layout of the turbines near Dikme Village in the project site area. Table 1. Final turbine coordinates of the project Final Turbine Coordinates of Aksu Wind Farm, Turkey UTM ED50 Coordinates, UTM Zone: 36S Turbine Turbine E N Number Number T01 723,049 4,210,172 T19 T02 723,287 4,210,230 T20 T03 723,532 4,210,248 T21 T04 724,990 4,210,224 T22 T05 725,248 4,210,078 T23 T06 725,482 4,209,884 T24 T07 725,807 4,210,010 T25 T08 726,622 4,209,482 T26 T09 726,387 4,209,676 T27 T10 726,182 4,209,449 T28 T11 725,881 4,209,423 T29 T12 725,596 4,209,393 T30 T13 725,355 4,209,539 T31 T14 725,040 4,209,526 T32 T15 724,733 4,209,433 T33 T16 724,418 4,209,321 T34 T17 723,957 4,209,038 T35 E N 723,249 723,183 722,853 722,485 722,243 721,912 721,685 721,329 721,193 721,028 720,778 720,987 721,276 721,508 724,323 721,968 722,232 4,208,636 4,209,170 4,209,031 4,209,313 4,209,382 4,209,196 4,209,327 4,209,407 4,209,226 4,209,071 4,209,029 4,208,519 4,208,567 4,208,573 4,208,677 4,208,471 4,208,313 UNFCCC/CCNUCC CDM – Executive Board T18 Page 7 721,739 4,208,579 T36 724,707 4,210,397 A.3. Technologies and/or measures The project activity involves electricity generation from renewable energy sources utilising wind energy as the primary energy source. Wind power is one of the main renewable energy sources used in the world for electricity generation. Turkey’s electricity generation mainly depends on fossil fuel fired power plants. Natural gas and coal are the main fossil fuels used in the power plants.1 Although the share of power plants using renewable energy sources is increasing in the recent years, most of these are hydro power plants and the wind power plants still constitute a very small percentage of the national installed capacity. 2,3,4 In the absence of the project, the same amount of electricity would be generated by a hypothetical thermal power plant representing the fossil fuel dominated character of the national grid. This power plant would have most probably been a natural gas coal fired plant. This power plant would cause GHG emissions, mainly CO2 emissions. The project will cause no GHG emissions. Hence, the project will reduce all the emissions that would take place in its absence. The project is a greenfield project, therefore no other project would be developed in its absence. The baseline scenario and the scenario existing prior to the start of the implementation of the project activity is the same and corresponds to a situation in which the same energy would be generated by the national grid causing GHG emissions. In the scope of the project, 36 wind turbines each having a 2 MW output power will be installed along with auxiliary structures including switchyard, administrative and control buildings, etc. The main components of the turbines include blades, hub, nose cone, nacelle, rotor, gearbox, generator, braking and yaw systems, tower, control systems, etc. among many others. Turbine specifications are summarised in the table below: Table 2. Specifications of Vestas V100-2.0 MW wind turbine Component / Explanation / Value Specification Brand Vestas Model V100 – 2.0 MW Class IEC IIIA Rated Power 2000 kW Number of blades 3 (Horizontal axis) Rotor diameter 100 m Rotor swept area 7,854 m2 Hub height 80 m Cut-in Wind Speed 3.0 m/s Rated Wind Speed 12.5 m/s Cut-out Wind Speed 20 m/s Recut-in Wind Speed 18 m/s 1 Fuels Consumed In Thermal Power Plants In Turkey By The Electricity Utilities (2006-2011) (http://www.teias.gov.tr/TürkiyeElektrikİstatistikleri/istatistik2011/yakıt46-49/47.xls) 2 TEIAS Installed Capacity Data of Turkey (http://www.teias.gov.tr/yukdagitim/kuruluguc.xls) (Accessed on 22 January 2013) 3 http://www.yegm.gov.tr/yenilenebilir/document/kuruluguc.xls 4 Turkish Electrical Energy 10-Year Generation Capacity Projection Report (2012-2021). (http://www.teias.gov.tr/KapasiteProjeksiyonuARALIK2012.pdf) UNFCCC/CCNUCC CDM – Executive Board Load Factor Generator Efficiency Average Lifetime Page 8 % 37.2 % 97 20 years The output voltage of each turbine will be 690 VAC, and this will be stepped up to medium voltage at 33.6 kV. The turbines will be collected in two groups each consisting of 18 turbines and having 36 MW capacities. Each group will be connected to a 154/33.6 kV 50-62.5 MVA transformer and the voltage will again be increased to high voltage at 154 kV. The wind farm will then be connected to Camlica-I HEPP substation at this 154 kV level as a single group via a 12 km long overhead transmission line. From this point on the energy will be fed to the national interconnected grid. Regarding the way how the technologies and measures and know-how to be used in the project are transferred to host party (Turkey), it can be said that the development of the project will most likely cause a positive impact on technological innovation and technology transfer in the region. Although main parts of the project including the turbines and the control system have been exported from abroad, many electrical parts including transformers, switchyard equipment, cabling instruments and most of the constructional material have been supplied from domestic sources. Also, construction work which is specific to wind power technology has been performed by a domestic company. Kayseri Province is a special region that has a unique status in the electricity distribution system of Turkey. Up until recently, Kayseri and Vicinity Electricity Turkish Incorporated Company (KCETAS), the company responsible for the electricity distribution of Kayseri Province, had been the only private electricity distribution company of Turkey5. Kayseri is one of the most developed provinces of Turkey with respect to industry and trade6. However, there had been no wind farms in Kayseri Province until the commissioning of Aksu Wind Farm, even though the fact that several licenses have been granted to various companies by Energy Market Regulatory Authority (EPDK)7. Aksu Wind Farm became the first operational wind farm in Kayseri Province. This is also true for surrounding provinces8. Although wind power technology is not new in Turkey, most of the wind farms are concentrated in Aegean, Marmara and to a lesser extent some parts of Mediterranean Geographical Regions of Turkey. Due to these reasons, it will very likely enhance technological innovation, technology and know-how transfer and technological self-reliance in the region consisting of Kayseri and surrounding provinces. A.4. Parties and project participants The Project Proponent is the only project participant. The project participant is listed in the following table, and the contact information of the project participant is provided in Annex 1. 5 http://www.kcetas.com.tr/?kanal=tarihce http://www.kayserito.org.tr/media/Kayseri_Ekonomisinin_Turkiyedeki_Yeri.pdf 7 http://lisans.epdk.org.tr/epvys-web/faces/pages/lisans/elektrikUretim/elektrikUretimOzetSorgula.xhtml http://www2.epdk.org.tr/data/index.htm http://www2.epdk.org.tr/data/EPDSantral/kayseri.pdf 8 http://www2.epdk.org.tr/data/index.htm 6 UNFCCC/CCNUCC CDM – Executive Board Page 9 Table 3. Parties and Project Participants involved in the Project Party involved (host) indicates a host Party Turkey (host) Private and/or public entity(ies) project participants (as applicable) Indicate if the Party involved wishes to be considered as project participant (Yes/No) Aksu Temiz Enerji Elektrik Uretim Sanayi ve Ticaret A. S. (private entity) No The Project Proponent, Aksu Temiz Enerji Elektrik Uretim Sanayi ve Ticaret A. S., is the owner and developer of the project. The Republic of Turkey is the host country. Turkey ratified the Kyoto Protocol on 28 May 2009 and the protocol entered into force on 26 August 2009. However, Turkey is a party for which Party for which there is a specific COP and/or CMP decision; and although being an Annex I Country, it has no commitments under Kyoto Protocol. National focal point of Turkey for UNFCCC is the Ministry of Environment and Urban Planning. Regional Environmental Centre Country Office Turkey (REC Turkey) acts as the National Focal Point for UNFCCC Article 6 – Education, Training and Public Awareness. A.5. Public funding of project activity No public funding from Parties included in Annex 1 or Official Development Assistance (ODA) is involved for the project activity. SECTION B. Application of selected approved baseline and monitoring methodology B.1. Reference of methodology The approved baseline and monitoring methodology applied to the project activity is “ACM0002: Consolidated baseline methodology for grid-connected electricity generation from renewable sources --Version 13.0.0”. Tools referenced in this methodology: 1. Tool for the demonstration and assessment of additionality 2. Combined tool to identify the baseline scenario and demonstrate additionality 3. Tool to calculate project or leakage CO2 emissions from fossil fuel combustion 4. Tool to calculate the emission factor for an electricity system Only two of these tools, “Tool to calculate the emission factor for an electricity system (Version 03.0.0)” for baseline emission calculation and “Tool for the demonstration and assessment of additionality (Version 07.0.0)“ for the assessment of additionality are used. Since no project emission or leakage is in question regarding the project activity, “Tool to calculate project or leakage CO2 emissions from fossil fuel combustion” is not used. “Combined tool to identify the baseline scenario and demonstrate additionality” is also not used since it is not applicable to the project according to the scope and rules defined therein. UNFCCC/CCNUCC CDM – Executive Board Page 10 B.2. Applicability of methodology The choice of methodology ACM0002 and related tools are justified based on the fact that the proposed project activity meets the relevant applicability conditions of the chosen methodology and tools: The project is a greenfield project. No power plant or a similar facility had been present in the project site when the project activity began. The project is a grid-connected renewable power generation project. The project activity does not involve any capacity addition or any retrofit or replacement of an existing power plant. The project activity is the installation of a wind power plant. There is no project emission or leakage related with the project activity. B.3. Project boundary The project utilises wind as the primary energy source to generate electricity. During normal operation when enough wind is present to generate wind, the project activity draws no energy from the grid to meet its auxiliary electricity consumption need. The project meets its auxiliary electricity consumption need from its own generated electricity. When there is not sufficient wind to generate electricity, the project will draw some electricity from the grid to use for auxiliary electricity consumption. There is a backup power generator using diesel fuel to be used only when power cannot be supplied from the grid due to a connection loss, grid maintenance, or a power outage in the grid. Under only very such rare occasions will the backup power generator operate and produce emissions. These emissions are expected to be very low and can be neglected; so assumed to be zero. Apart from the backup diesel power generator, there is no equipment or machinery related with the project activity that can produce any emissions. Table 4. Emission sources and GHGs included or excluded in the project boundary Project scenario Baseline scenario Source Electricity generation mix of national grid displaced by project activity Activities during constructional and operational phases of the project GHG s CO2 Yes CH4 N2O Other No No No CO2 CH4 N2O Other No No No No Included? Justification/Explanation Major GHG emission from the power plants in the fossil-fuel dominated national grid in the absence of the project activity is CO2. The amount of other gases and pollutants are very low compared to CO 2. So, CO2 is included in the baseline emission calculation. Although there may be CH4 or N2O emissions from the power plants in the grid during electricity generation in the absence of the project activity, these emissions would be very low and trivial as compared to CO2. As a result, CH4 or N2O emissions in the baseline emission calculations are neglected and assumed as zero. Under normal conditions, no CO 2, CH4 or N2O emissions will occur apart from normal domestic activities of the personnel like heating and cooking. And those emissions resulting from these domestic activities will be very low to be taken into account in the calculations. So, these are neglected and not UNFCCC/CCNUCC CDM – Executive Board Page 11 included. The wind turbines in the project activity are divided into two groups for which there are separate power transformers and metering systems. There are 21 turbines in Group 1, namely Turbines no. 4, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, 15, 16, 17, 19, 20, 21, 22, 23, 33 and 36. There are 15 turbines in Group 2, namely Turbines no. 1, 2, 3, 18, 24, 25, 26, 27, 28, 29, 30, 31, 32, 34 and 35. The flow diagram of the project boundary with its connections to the national grid is shown in the following figure. The monitoring variable used for emission reduction calculations is the net amount of generated electricity measured by two monitoring systems consisting of main and backup electricity meters for each group. UNFCCC/CCNUCC CDM – Executive Board Page 12 Figure 2. Schematic diagram showing the flow diagram of the project boundary, its connection to national grid, and emission sources and gases included in the project boundary and monitoring variables. UNFCCC/CCNUCC CDM – Executive Board Page 13 B.4. Establishment and description of baseline scenario The selected baseline methodology for the development of PDD is “ACM0002: Consolidated baseline methodology for grid-connected electricity generation from renewable sources --- Version 13.0.0”. So, the most plausible baseline scenario is identified in accordance with this methodology. Baseline methodology procedure explained on pages 4 – 5 of this methodology proposes three alternatives for identification of the baseline scenario. Since the project activity is the installation of a new grid-connected wind power plant with 36 turbines and is not a capacity addition to or the retrofit or replacement for an existing grid-connected renewable power plant, the first alternative is the most suitable one for the project for identification of the baseline scenario; which is explained as follows9: “If the project activity is the installation of a new grid-connected renewable power plant/unit, the baseline scenario is the following: “Electricity delivered to the grid by the project activity would have otherwise been generated by the operation of grid-connected power plants and by the addition of new generation sources, as reflected in the combined margin (CM) calculations described in the “Tool to calculate the emission factor for an electricity system”.” Since the project activity has nothing to do with a capacity addition or the retrofit or replacement of an existing grid-connected renewable power plant/unit(s) at the project site, the other two alternative scenarios and respective step-wise procedures are not applicable. This assumption of baseline scenario can also be justified and supported by data, statistics and studies performed by TEIAS (Turkish Electricity Transmission Corporation). The following two tables summarize the situation of Turkish Electricity Generation sector as at the end of 2011: Table 5. Distribution of Total Installed Capacity of Turkey by Fuel / Energy Source Types as at the end of 20112, 4. THE END OF 2011 FUEL TYPES FUEL-OIL + ASPHALTITE + NAPHTA + DIESEL OIL IMPORTED COAL + HARD COAL + LIGNITE NATURAL GAS + LNG RENEWABLE + WASTE MULTI-FUEL SOLID + LIQUID MULTI-FUEL LIQUID + N. GAS GEOTHERMAL HYDRAULIC DAMMED 9 INSTALLED CAPACITY (MW) CONTRIBUTION (%) NUMBER OF POWER PLANTS 1,362.3 2.6 23 12,355.7 16,004.9 115.4 556.5 3,536.4 114.2 13,529.3 23.4 30.2 0.2 1.1 6.7 0.2 25.6 24 155 18 8 52 7 58 ACM0002: Consolidated baseline methodology for grid-connected electricity generation from renewable sources --- Version 13.0.0, page 4. (http://cdm.unfccc.int/UserManagement/FileStorage/DYPFI935XBG274NWH6O8CM1KEZR0VU) UNFCCC/CCNUCC CDM – Executive Board Page 14 3,607.7 1,728.7 6.8 3.3 251 47 52,911.1 100.0 643 HYDRAULIC RUN-OF-RIVER WIND TOTAL Table 6. Distribution of Gross Electricity Generation of Turkey by Fuel / Energy Source Types in 201110 THE DISTRIBUTION OF GROSS ELECTRICITY GENERATION BY PRIMARY ENERGY RESOURCES IN TURKEY 2011 Energy (GWh) PRIMARY ENERGY RESOURCES COAL Hard coal+Imported Coal+Asphaltite Lignite COAL TOTAL Fuel Oil Diesel Oil LPG Naphtha LIQUID TOTAL LIQUID FUELS 27,347.5 38,870.4 66,217.9 900.5 3.1 0.0 0.0 903.6 104,047.6 469.2 171,638.3 52,338.6 694.3 4,723.9 229,395.1 Natural Gas Renewables and Wastes THERMAL TOTAL HYDRO GEOTHERMAL WIND GENERAL TOTAL Share (%) 11.92 16.94 28.87 0.39 0.00 0.00 0.00 0.39 45.36 0.205 74.82 22.82 0.30 2.06 100.00 TEIAS publishes annual capacity projection reports to forecast the future possible situation of Turkish Electricity Sector based on current available data. These projections are performed assuming two different scenarios, one with a high demand assumption, and the other with a low demand assumption. The development of total firm energy generation capacity of Turkish grid for a 10 year period (2012 – 2021) for these two scenarios according to the latest Capacity Projection Report (2012) are as follows: Table 7. Development of Total Firm Generation Capacity by Energy Resource Types11 (Scenario 1 – High Demand) (Operational, with State Owned Power Plants Under Construction and Private Sector Owned Power Plants Under Construction Granted by Licence and Expected to be in Service on Proposed Date) (Projects Granted by Licence with an Indefinite Date of Commissioning Excluded) (a) Generation (GWh) YEARS LİGNITE HARD COAL + 10 11 2011 34973 3738 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 34984 3738 44118 3857 48600 3857 52676 4829 56651 5801 56748 5801 57260 5801 57260 5801 57260 5801 57260 5801 http://www.teias.gov.tr/TürkiyeElektrikİstatistikleri/istatistik2011/uretim%20tuketim(22-45)/44.xls Turkish Electrical Energy 10-Year Generation Capacity Projection Report (2012-2021), p. 53. (http://www.teias.gov.tr/KapasiteProjeksiyonuARALIK2012.pdf) UNFCCC/CCNUCC CDM – Executive Board Page 15 ASPHALTİTE IMPORTED COAL NATURAL GAS GEOTHERMAL FUEL OIL DIESEL OIL NUCLEAR OTHERS THERMAL TOTAL BIOGAS + WASTE HYDRAULIC WIND 25461 134625 802 6805 148 0 1408 207959 804 53317 5002 25461 141708 802 6805 148 0 1408 215053 945 56661 5180 25426 145475 912 9034 148 0 1408 230376 1111 44940 5764 25002 150184 1212 9034 148 0 1408 239443 1166 48717 6907 29474 162289 1402 9034 148 0 1408 261259 1196 54932 7644 36481 167216 1402 9034 148 0 1408 278139 1196 62536 7644 38272 167848 1402 9034 148 0 1408 280659 1196 67210 7644 38311 168184 1402 9034 148 0 1408 281547 1196 68946 7644 38311 168184 1402 9034 148 4200 1408 285747 1196 69386 7644 38311 168184 1402 9034 148 12600 1408 294147 1196 69386 7644 38311 168184 1402 9034 148 21000 1408 302547 1196 69386 7644 TOTAL 267081 277840 282192 296234 325031 349516 356709 359334 363974 372374 380774 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 (b) Percentage (%) YEARS 2011 LİGNITE HARD COAL + ASPHALTİTE IMPORTED COAL NATURAL GAS GEOTHERMAL FUEL OIL DIESEL OIL NUCLEAR OTHERS BIOGAS + WASTE HYDRAULIC WIND 13,1 12,6 15,6 16,4 16,2 16,2 15,9 15,9 15,7 15,4 15,0 1,4 1,3 1,4 1,3 1,5 1,7 1,6 1,6 1,6 1,6 1,5 9,5 50,4 0,3 2,5 0,1 0,0 0,5 0,3 20,0 1,9 9,2 51,0 0,3 2,4 0,1 0,0 0,5 0,3 20,4 1,9 9,0 51,6 0,3 3,2 0,1 0,0 0,5 0,4 15,9 2,0 8,4 50,7 0,4 3,0 0,0 0,0 0,5 0,4 16,4 2,3 9,1 49,9 0,4 2,8 0,0 0,0 0,4 0,4 16,9 2,4 10,4 47,8 0,4 2,6 0,0 0,0 0,4 0,3 17,9 2,2 10,7 47,1 0,4 2,5 0,0 0,0 0,4 0,3 18,8 2,1 10,7 46,8 0,4 2,5 0,0 0,0 0,4 0,3 19,2 2,1 10,5 46,2 0,4 2,5 0,0 1,2 0,4 0,3 19,1 2,1 10,3 45,2 0,4 2,4 0,0 3,4 0,4 0,3 18,6 2,1 10,1 44,2 0,4 2,4 0,0 5,5 0,4 0,3 18,2 2,0 TOTAL 100 100 100 100 100 100 100 100 100 100 100 Table 8. Development of Total Firm Generation Capacity by Energy Resource Types 12 (Scenario 2 – Low Demand) (Operational, with State Owned Power Plants Under Construction and Private Sector Owned Power Plants Under Construction Granted by Licence and Expected to be in Service on Proposed Date) (Projects Granted by Licence with an Indefinite Date of Commissioning Excluded) (a) Generation (GWh) YEARS LİGNITE HARD COAL + ASPHALTİTE IMPORTED COAL NATURAL GAS GEOTHERMAL FUEL OIL DIESEL OIL NUCLEAR OTHERS THERMAL TOTAL 12 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 34973 34976 44109 48600 49714 51964 53298 53810 53810 53810 53810 3738 3738 3857 3857 4829 5801 5801 5801 5801 5801 5801 25461 134625 802 6805 148 0 1408 207959 25461 140423 802 6805 148 0 1408 213760 25426 143243 912 9034 148 0 1408 228137 25002 148138 1057 9034 148 0 1408 237243 25214 160616 1247 9034 148 0 1408 252208 27961 166641 1402 9034 148 0 1408 264357 29752 167848 1402 9034 148 0 1408 268689 34051 168184 1402 9034 148 0 1408 273837 38311 168184 1402 9034 148 4200 1408 282297 38311 168184 1402 9034 148 12600 1408 290697 38311 168184 1402 9034 148 21000 1408 299097 Turkish Electrical Energy 10-Year Generation Capacity Projection Report (2012-2021), p. 60. (http://www.teias.gov.tr/KapasiteProjeksiyonuARALIK2012.pdf) UNFCCC/CCNUCC CDM – Executive Board BIOGAS + WASTE HYDRAULIC WIND TOTAL Page 16 804 53317 5002 872 55923 5108 1038 43676 5602 1166 46966 6462 1196 51459 7288 1196 58052 7644 1196 63771 7644 1196 67744 7644 1196 69386 7644 1196 69386 7644 1196 69386 7644 267081 275663 278453 291837 312151 331249 341300 350421 360524 368924 377324 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 (b) Percentage (%) YEARS 2011 LİGNITE HARD COAL + ASPHALTİTE IMPORTED COAL NATURAL GAS GEOTHERMAL FUEL OIL DIESEL OIL NUCLEAR OTHERS BIOGAS + WASTE HYDRAULIC WIND 13,1 12,7 15,8 16,7 15,9 15,7 15,6 15,4 14,9 14,6 14,3 1,4 1,4 1,4 1,3 1,5 1,8 1,7 1,7 1,6 1,6 1,5 9,5 50,4 0,3 2,5 0,1 0,0 0,5 0,3 20,0 1,9 9,2 50,9 0,3 2,5 0,1 0,0 0,5 0,3 20,3 1,9 9,1 51,4 0,3 3,2 0,1 0,0 0,5 0,4 15,7 2,0 8,6 50,8 0,4 3,1 0,1 0,0 0,5 0,4 16,1 2,2 8,1 51,5 0,4 2,9 0,0 0,0 0,5 0,4 16,5 2,3 8,4 50,3 0,4 2,7 0,0 0,0 0,4 0,4 17,5 2,3 8,7 49,2 0,4 2,6 0,0 0,0 0,4 0,4 18,7 2,2 9,7 48,0 0,4 2,6 0,0 0,0 0,4 0,3 19,3 2,2 10,6 46,7 0,4 2,5 0,0 1,2 0,4 0,3 19,2 2,1 10,4 45,6 0,4 2,4 0,0 3,4 0,4 0,3 18,8 2,1 10,2 44,6 0,4 2,4 0,0 5,6 0,4 0,3 18,4 2,0 TOTAL 100 100 100 100 100 100 100 100 100 100 100 As can be seen from the data depicted in the tables, the current thermal dominated nature of Turkish Electricity Generation Sector is not expected to change within the next ten years significantly. This conclusion justifies the assumption that the baseline scenario is the case in which the electricity delivered to the grid by the project activity would have otherwise been generated by the operation of newly added grid-connected power plants and would correspond to the continuation of current energy resource distribution situation of the national grid. Although a special feed-in-tariff and incentives are given to power plants using renewable energy sources according to Law on Utilization of Renewable Energy Resources for the Purpose of Generating Electrical Energy13 (Law No: 5346, Issuance Date: 18.05.2005), this supportive mechanism does not seem to change the future probable situation of electricity generation sector in a distinguishable way. So, the assumption of baseline scenario is still valid in the presence of the feed-in-tariff and incentives included in this law. B.5. Demonstration of additionality B.5.1. Implementation Timeline of the Project Activity An overview of Implementation timeline of the project activity can be found in the table below: Table 9. Implementation timeline of the project activity Activity Initial Issuance of Generation Licence EIA not required certificate Transfer of majority shares (70 %) to Ayen Enerji A. S. 13 Date 29/11/2007 03/11/2009 14/01/2011 http://www.enerji.gov.tr/mevzuat/5346/5346_Sayili_Yenilenebilir_Enerji_Kaynaklarinin_Elektrik_Enerjisi_Uretimi_Amacli_Kullani mina_Iliskin_Kanun.pdf http://www.epdk.gov.tr/documents/elektrik/mevzuat/kanun/Elk_Kanun_Yek_Kanun.doc UNFCCC/CCNUCC CDM – Executive Board Approval of transfer of shares by EMRA (Energy Market Regulatory Authority) Submission of Financial Feasibility Report and EIA Report to creditor bank (TSKB=Turkish Industrial Development Bank), both including and providing evidence that the incentive from CDM (Gold Standard VER) was seriously considered in the decision to proceed with the project activity. Turbine purchase and service agreement with turbine supplier (Vestas) Credit agreement with creditor bank (TSKB=Turkish Industrial Development Bank) Local Stakeholder Meeting Start of construction works First Partial Commissioning (18 Turbines) (Turbines No. 1, 2, 3, 4, 5, 6, 7, 9, 10, 11, 12, 13, 14, 15, 16, 17, 33, 36) Second Partial Commissioning (15 Turbines) (Turbines No. 18, 19, 22, 23, 24, 25, 26, 27, 28, 29, 30, 31, 32, 34, 35) Third and the Last Partial Commissioning (3 Turbines) (Turbines No. 8, 20, 21) Page 17 09/02/2011 07/04/2011 02/05/2011 27/05/2011 16/06/2011 19/07/2011 16/03/2012 05/04/2012 09/06/2012 As can be seen from the implementation timeline of the project, the revenues from VER credits had been taken into account before electromechanical equipment order agreement and credit agreement. VER revenues are considered in the financial analysis performed for investment. Financial Feasibility Report submitted to the creditor bank for credit assessment included VER revenues and the creditor bank took VER revenues into account when giving the credit. Environmental Impact Assessment Report also mentioned VER revenues. B.5.2. Assessment and Demonstration of Additionality The selected baseline methodology for the development of PDD, “ACM0002: Consolidated baseline methodology for grid-connected electricity generation from renewable sources --- Version 13.0.0” refers to the latest version of the “Tool for the demonstration and assessment of additionality” (Version 07.0.0) (referred to as “The Tool” hereafter in this section) for the demonstration and assessment of the additionality. The methodology procedure of this tool defines a step-wise approach to be applied for the project activity. The application of this step-wise approach to the proposed project activity is as follows: Step 1: Identification of alternatives to the project activity consistent with current laws and regulations Realistic and credible alternatives to the project activity are defined through the following sub-steps as per the Tool: Sub-step 1a: Define alternatives to the project activity: Probable realistic and credible alternatives that may be available to the Project Proponent are assessed in the following alternate scenarios: a) The proposed project activity undertaken without being registered as a CDM (GS VER) project activity This alternative would be realistic and credible if the project proponent had found the project financially feasible as a result of investment analysis. But the investment analysis showed that the project is not UNFCCC/CCNUCC CDM – Executive Board Page 18 financially feasible without the incentive coming from the GS VER revenues. So the project is not considered as credible and feasible by the project proponent although it may be realistic without being registered as a CDM (GS VER) project activity. (b) Other realistic and credible alternative scenario(s) to the proposed CDM project activity scenario that deliver outputs services (e.g., cement) or services (e.g. electricity, heat) with comparable quality, properties and application areas, taking into account, where relevant, examples of scenarios identified in the underlying methodology; The project activity is a power plant using renewable energy sources to generate electricity without emitting any greenhouse gases. So, any other realistic and credible alternative scenario to the proposed project activity scenario that delivers services (electricity) with comparable quality would be another power plant utilising another renewable energy source to generate electricity without emitting any greenhouse gases. But, in the project area there are no other available renewable or non-renewable energy sources to be used for electricity generation. Hence, there are no other realistic and credible alternative scenarios to the proposed project activity that delivers electricity with comparable quality. Therefore, this alternative is not realistic or credible. (c) If applicable, continuation of the current situation (no project activity or other alternatives undertaken). The investment decision for the project activity depends on financial feasibility analysis and risk assessment performed by the project proponent. If the financial feasibility analysis and risk assessment had not been positive, the project would not have been realized. Hence, this scenario in which there would be no project activity is a realistic and credible alternative scenario. This scenario is the continuation of the current situation and corresponds to the case in which the same amount of electricity would be generated by the existing national grid which is composed of a generation mix largely depending on fossil fuels. This alternative is the same as baseline scenario in which the same amount of electricity that would be delivered to the national grid by the project activity would have otherwise been generated by the power plants connected to the national grid whose current composition is mainly dependent on fossil fuels. Outcome of Step 1a: As a result, the above alternatives (a) and (c) are identified as realistic alternative scenarios, but only alternative (c) is found to be the credible alternative scenario to the project activity. Sub-step 1b: Consistency with mandatory laws and regulations: Both the above identified alternatives, whether they are realistic and credible or not are in compliance with all mandatory applicable legal and regulatory requirements, among which the following are the most important ones: Table 10. Important mandatory laws and regulations that the project is consistent with (a) Legislation about electricity generation and marketing: Law / Regulation / Communiqué / Protocol Electricity Market Law Law on Utilization of Renewable Number / Enforcement Date 4628 / 03.03.2001 5346 / 18.05.2005 UNFCCC/CCNUCC CDM – Executive Board Energy Resources for the Purpose of Generating Electrical Energy Energy Efficiency Law Electricity Market Licence Regulation Electricity Market Grid Regulation Electricity Market Distribution Regulation Regulation on Procedures and Principles as to Giving Renewable Energy Source Certificate Regulation on Certification and Support of Renewable Energy Sources Electricity Transmission System Supply Reliability and Quality Regulation Electrical Installations Project Regulation Regulation on Technical Evaluation of Licence Applications based on Wind Energy Competition Regulation as to Licence Applications to Install Generation Facility Based On Wind Energy Protocol as to Establishment of Permission Procedures about Effects of Wind Energy Power Plant Installation on Communication, Navigation and Radar Systems Regulation on Domestic Manufacturing of the Equipment Used in Facilities Generating Electrical Energy from Renewable Energy Sources Regulation on Electrical Energy Demand Forecasts Electricity Market Balancing and Settlement Regulation Electricity Market Tariffs Regulation Electricity Market Import and Export Regulation Electricity Market Customer Services Regulation Electricity Market Eligible Consumer Regulation Electricity Market Ancillary Services Regulation Communiqué on Connection to Transmission and Distribution Systems and System Usage in the Electricity Market Communiqué on Arrangement of Retail Contract in the Electricity Market Communiqué on Meters to be used in the Electricity Market Communiqué on Wind and Solar Measurements Communiqué on Procedures and Principles of Making Financial Settlement in the Electricity Market Page 19 5627 / 02.05.2007 - / 04.08.2002 - / 22.01.2003 - / 19.02.2003 - / 04.10.2005 - / 21.07.2011 - / 10.11.2004 - / 16.12.2009 - / 09.11.2008 - / 22.09.2010 - / 27.12.2010 - / 19.06.2011 - / 04.04.2006 - / 25.09.2002 - / 25.09.2002 - / 04.09.2002 - / 27.12.2008 - / 27.03.2003 - / 31.08.2003 - / 22.03.2003 - / 11.10.2002 - / 30.03.2003 (b) Legislation about environment, forestry, labour and social security: Law / Regulation / Communiqué / Protocol Environmental Law Forestry Law Labour Law Construction Law Law on Soil Conservation and Land Use National Parks Law Cultural and Natural Heritage Preservation Law Animal Protection Law Number / Enforcement Date 2872 / 11.08.1983 6831 / 08.09.1956 4857 / 22.05.2003 3194 / 09.05.1985 5403 / 19.07.2005 2873 / 11.08.1983 2863 / 23.07.1983 5199 / 01.07.2004 UNFCCC/CCNUCC CDM – Executive Board Environmental Impact Assessment Regulation Regulation on Environmental Planning Regulation on Permissions and Licences that have to be taken according to Environmental Law Air Quality Assessment and Management Regulation Environmental Auditing Regulation Regulation on Environmental Agents and Environmental Consulting Firms Regulation on Assessment and Management of Environmental Noise Regulation on Control of Waste Oils Regulation on Amendment in the Regulation on Control of Waste Oils Regulation on diggings that will be done where it is not possible to construct a sewage course Regulation on Occupational Health and Safety Noise Regulation Vibration Regulation Regulation on Machine Safety Page 20 - / 17.07.2008 - / 11.11.2008 - / 29.04.2009 - / 06.06.2008 - / 22.09.2010 - / 12.11.2010 - / 04.06.2010 - / 30.07.2008 - / 30.03.2010 - / 19.03.1971 - / 09.12.2003 - / 23.12.2003 - / 23.12.2003 - / 05.06.2002 Outcome of Step 1b: All the alternatives to the project whether they are realistic and credible or not are in compliance with all mandatory applicable and regulatory requirements. Step 2: Investment analysis The purpose of investment analysis is to determine whether the proposed project activity is not (a) The most economically or financially attractive; or (b) Economically or financially feasible, without the revenue from the sale of emission reductions. To conduct the investment analysis, “Guidelines on the assessment of investment analysis” (Version 05.0) (referred to as “The Guidelines” hereafter in this section) has also been used apart from The Tool. To conduct the investment analysis, stepwise approach of the Tool has been used. Sub-step 2a: Determine appropriate analysis method The Tool offers three alternative methods to conduct the investment analysis: Option I Option II Option III : Simple Cost Analysis : Investment Comparison Analysis : Benchmark Analysis Since the project activity and the alternatives identified in Step 1 generate financial or economic benefits by electricity sales, Option I (Simple Cost Analysis) cannot be applied. To decide between Option II (Investment Comparison Analysis) and Option III (Benchmark Analysis), Paragraph 19 of the Guidance (page 5) has been used. According to this clause, since the alternative to the project activity is the supply of the electricity from the existing grid, Benchmark Analysis (Option III) is considered appropriate. UNFCCC/CCNUCC CDM – Executive Board Page 21 Sub-step 2b: Option III. Apply benchmark analysis IRR (Internal Rate of Return) is identified as the most suitable financial/economic indicator for the demonstration and assessment of additionality. Equity IRR is selected as the IRR type to be used in the benchmark analysis. According to the Guidelines, Required/expected returns on equity are appropriate benchmarks for an equity IRR. When applying the benchmark analysis, the parameters that are standard in the market are used, according to the Paragraph 37 of the Tool. Sub-step 2c: Calculation and comparison of financial indicators (only applicable to Options II and III): A) Benchmark Rate Calculation To find the benchmark rate, option (a) of the Paragraph 38 of the Tool is used: “38. Discount rates and benchmarks shall be derived from: (a) Government bond rates, increased by a suitable risk premium to reflect private investment and/or the project type, as substantiated by an independent (financial) expert or documented by official publicly available financial data;” The benchmark rate is specified as the expected returns on equity (expected return on the capital asset / cost of equity); and calculated using the Capital Asset Pricing Model (CAPM), as follows: E(Ri) = Rf + βi (E(Rm) – Rf) where: E(Ri) Rf βi : Expected returns on equity (Cost of Equity) : Risk Free Return Rate in the Market (e.g. government bond yield) : Beta Coefficient – Sensitivity of the Expected Returns to Market Returns where Rm E(Rm) – Rf i Cov(Ri , Rm ) Var ( Rm ) : Expected Return of the Market : Market Risk Premium (the difference between the expected market rate of return and the risk-free rate of return) The assumptions and references for the calculation of the rates and coefficients above are explained below: i) Risk Free Rate (Rf) As the representative of the risk free rate, Turkish Eurobond interest rates with the longest maturity (10 years) is chosen. EUROSTAT data for Turkey14 has been used to calculate this rate. The 5-year period of 14 http://epp.eurostat.ec.europa.eu/tgm/table.do?tab=table&init=1&plugin=1&language=en&pcode=tec00036 UNFCCC/CCNUCC CDM – Executive Board Page 22 [2007-2011] was assumed as the reference period. The arithmetic average of the annual averages for these years was accepted as the government bond yield rate; hence the risk free rate. This value was calculated as 13.51 %. ii) Beta Coefficient (βi) Beta Coefficient was calculated using the data available form Istanbul Stock Exchange15. Price Indices for XU100-BIST100 (General) and XELKT-BIST ELECTRICITY (Electricity Generating and Trading Companies) were collected and put into the relevant formula to calculate the Beta Coefficient. The value of the Beta Coefficient was found to be 0.798. The details of the calculation can be found in the separate spreadsheet file for the investment analysis supplied as an annex to PDD. iii) Market Risk Premium (E(Rm) – Rf) To assess the market risk premium of Turkey, the studies of Aswoth Damodaran, a well-known independent researcher and an academician at the Stern School of Business at New York University, were used 16. Country Risk Premiums for Turkey for the same 5-year reference period above ([20072011]) were taken and their arithmetic average was accepted as the market risk premium of Turkey as at the end of 2011. The market risk premium value was found to be 10.09 %. iv) Expected Returns on Equity (Cost of Equity) (E(Ri)) The expected returns on equity, the benchmark rate that would be used, was found, using the calculations above, as: E(Ri) = Rf + βi (E(Rm) – Rf) = 13.51 % + 0.798 * 10.09 % = 21.57 % So, the benchmark discount rate to be used in the investment analysis is 21.57 %. This rate can be assumed as reliable and conservative since it takes a period long enough (a five year period of [20072011]) as the reference and the beta coefficient takes all the companies in the electricity generation and trading sector that are quoted in Istanbul Stock Exchange (the number was 5 at the end of 2011) into account. The beta coefficient, hence the risk, for a single project of a single company is expected to be higher than that of a value calculated for 5 companies for a period of 5 years. A) Equity IRR Calculation for the Project The following assumptions were made in calculating the Equity IRR for the project: 1) The VER revenues were calculated assuming a GS-VER credit unit price of 8.00 USD/tCO2-eq, the average market value indicated for Turkey in the Ecosystem Marketplace State of the Voluntary Carbon Markets 2012 Report17. This can be assumed as a fairly conservative price for Turkish Wind Energy Projects, since it also takes all other projects, mostly hydro, and projects developed under different standards, the price of which are generally lower than that of GS-VER Wind Energy Projects. 15 http://borsaistanbul.com/en/-nbsp-data-nbsp-/data/equity-market-data/index-data http://pages.stern.nyu.edu/~adamodar/New_Home_Page/data.html 17 Ecosystem Marketplace State of the Voluntary Carbon Markets 2012 Report, page 56. (http://www.forest-trends.org/documents/files/doc_3164.pdf) 16 UNFCCC/CCNUCC CDM – Executive Board Page 23 2) The Energy Sales Unit Price was accepted as the guaranteed feed-in-tariff specified in the Law on Utilization of Renewable Energy Resources for the Purpose of Generating Electrical Energy (Law No: 5346, Issuance Date: 18.05.2005)13, which is 7.3 USDcent/kWh. This price can be accepted as conservative, since it represents the minimum guaranteed price for electricity originating from wind energy projects. The price in the free electricity trade market is generally higher than that. 3) EUR/TRY Exchange Rate is calculated using the Turkish Central Bank data 18 . This can be accepted as reliable and conservative since it assumes a period long enough (a five year period of [2007-2011]) as the reference. 4) EUR/USD Exchange Cross Rate is calculated using the Turkish Central Bank data19. This can also be accepted as reliable and conservative since it assumes a period long enough (a five year period of [2007-2011]) as the reference. 5) The Average Expected Annual Electricity Generation Amount is calculated by multiplying the project generation of the project activity indicated in the licence by the ratio found by dividing the total firm generations of CDM-VER Wind Projects in Turkey by their total project generations for 2011, receiving the data from 2012 Capacity Projection Report of TEIAS4. The firm energy generation capacity values in this report are based on actual generations of the power plants. By this way, the annual estimated firm energy generation capacity for the project is found. This can also be assumed as reliable and conservative, since it uses the official value from a government source, and takes all the wind farms similar to the project activity into account for a one-year period, a duration that is generally accepted long enough (minimum) for wind power feasibility studies. 6) To find the net amount of electricity generated by the project activity, the electricity drawn from the grid by the project should also be taken into account and subtracted from the amount of electricity fed into the grid. However, no reliable and official data could be found regarding the energy drawn from the grid by power plants. Hence, this estimated amount of energy drawn from the grid was simply ignored. This can also be assumed as acceptable since this drawn energy is small enough to be included in the error range of estimated energy fed into the grid. 7) The Euribor values used in the calculation for loan repayment and interests in the investment analysis were also received from a reliable source20, and calculated for the same 5-year reference period ([2007-2011]), as in the other parameters. 8) The values for Service, Operation and Maintenance Costs were calculated taking the Aksu Wind Power Project Service and Availability Agreement with Wind Turbine Provider. 9) The values for credit were taken from the Credit Loan Agreement made between the Creditor Bank and the Project Proponent. 10) The project lifetime period was accepted as 20 years. A summary of the benchmark analysis and the relevant parameters can be found in the following table: 18 http://evds.tcmb.gov.tr/cgi-bin/famecgi?cgi=$ozetweb&DIL=UK&ARAVERIGRUP=bie_dkdovizgn.db http://evds.tcmb.gov.tr/cgi-bin/famecgi?cgi=$ozetweb&DIL=UK&ARAVERIGRUP=bie_dkdovizgn.db 20 http://www.euribor-ebf.eu/euribor-org/euribor-rates.html 19 UNFCCC/CCNUCC CDM – Executive Board Page 24 Table 11. Summary of Benchmark Analysis and Financial Data Parameter Unit Value Installed Capacity MW Expected Annual Firm Energy Generation MWh Carbon Credit Unit Price USD/tCO2-eq 8.00 Energy Unit Price USDcent/kWh 7.30 Emission Factor tCO2/MWh 0.611 Risk Free Rate (Rf) % 13.50 Beta Coefficient (βi) - 0.798 Market Risk Premium (E(Rm) – Rf) % 10.09 Benchmark Discount Rate (Expected Returns on Equity) % 21.57 EUR/TRY Exchange Rate - 2.0276 - 1.3916 EUR/USD Exchange Cross Rate Total Investment Cost Total Operation and Maintenance Costs Equity / Total Investment Cost Ratio Debt / Total Investment Cost Ratio Project Lifetime Equity IRR 72 194,003 EUR 79,882,500 EUR 29,083,252 Reference / Source / Justification Project Activity Electricity Generation Licence Project Activity Electricity Generation Licence, Firm/Project Generation Capacity Data of CDM-VER Wind Projects from 2012 Capacity Projection Report of TEIAS Ecosystem Marketplace State of the Voluntary Carbon Markets 2012 Report Law on Utilization of Renewable Energy Resources for the Purpose of Generating Electrical Energy (Law No: 5346, Issuance Date: 18.05.2005) Emission Factor Calculation, made according to “Tool to calculate the emission factor for an electricity system-Version 03.0.0” EUROSTAT Data for Turkey for the 5-year period of [2007-2011] Istanbul Stock Exchange Data for the 5-year period of [2007-2011] Data for Turkey for the 5-year period of [2007-2011] from Studies of Prof. Aswath Damodaran. Calculated using the relevant parameters according to the Capital Asset Pricing Model (CAPM). Turkish Central Bank Data for the 5-year period of [2007-2011] Turkish Central Bank Data for the 5-year period of [2007-2011] Investment Analysis Aksu Wind Power Project Service and Availability Agreement with Wind Turbine Provider % 23 Investment Analysis % 77 Investment Analysis Years % 20 Assumption 9.38 Investment Analysis Cash Flow Comparison results of financial indicators can be summarized and depicted in the table below: Table 12. Comparison results of financial indicators Indicator Value Benchmark Discount Rate 21.57 % UNFCCC/CCNUCC CDM – Executive Board Page 25 Equity IRR with Carbon Revenues Equity IRR without Carbon Revenues 9.38 % 7.16 % The results of the comparison show that without the extra income of carbon revenues, the Equity IRR of the project activity is equal to 7.16 % and lower than the benchmark discount rate, which is 21.57 %. This clearly indicates that the project activity cannot be considered as financially attractive. With carbon revenues, Equity IRR value is 9.38 %, which is also lower than the benchmark discount rate of 21.57 %. But carbon revenues give extra financial support to the project development and alleviate the financial hardships. Taking the VER Carbon Revenues into account brings some extra co-benefits to the project developer like fulfilling the Social Corporate Responsibility in an environment-friendly way, helping promote the image of the project developer, and increasing the chance of getting future incentives. Most importantly, additional financial income, extra detailed financial and environmental feasibility and documentation studies, and extra care taken in by developing the project as a CDM-VER Project greatly increases the probability of finding debt from a credit institution. Sub-step 2d: Sensitivity analysis (only applicable to Options II and III) A Sensitivity Analysis was made in order to show whether the conclusion regarding the financial/economic attractiveness is robust to reasonable variations in the critical assumptions. For this purpose, the sensitivity analysis is applied to following parameters: 1) 2) 3) 4) Total Project Cost Operational, Service and Maintenance Costs Electrical Energy Generation Electrical Energy Sales Price The sensitivity analysis was applied to these parameters for two cases, one with carbon revenues, and the other without carbon revenues; and for a range of ± 20 %, with increments of 5 %. The results are summarized in the table below: Table 13. Parameters and Variances Used in Sensitivity Analysis Variable Variance Amount (EUR) IRR (with VER Revenues) IRR (without VER Revenues) Total Project Cost -20% -15% Total Amount (EUR) IRR (with VER Revenues) IRR (without VER Revenues) -5% 0% 5% 10% 15% 20% 61,882,737 65,750,408 69,618,079 73,485,750 77,353,421 81,221,092 85,088,763 88,956,434 92,824,105 16.78% 14.50% 12.56% 10.86% 9.38% 8.07% 6.86% 5.80% 4.91% 13.78% 11.76% 10.02% 8.50% 7.16% 5.98% 4.92% 4.02% 3.25% 10% 15% 20% Variable Variance -10% Operational, Service & Maintenance Costs -20% -15% -10% -5% 0% 5% 36,775,865 39,074,357 41,372,848 43,671,340 45,969,832 48,268,323 50,566,815 52,865,306 55,163,798 10.75% 10.41% 10.07% 9.73% 9.38% 9.04% 8.69% 8.34% 7.99% 8.55% 8.21% 7.86% 7.51% 7.16% 6.81% 6.46% 6.10% 5.74% UNFCCC/CCNUCC CDM – Executive Board Page 26 Variable Electrical Energy Generation Variance Amount (MWh) IRR (with VER Revenues) IRR (without VER Revenues) -20% -15% -10% -5% 0% 5% 10% 15% 20% 155,202 164,902 174,602 184,302 194,003 203,703 213,403 223,103 232,803 2.26% 4.09% 5.85% 7.61% 9.38% 11.16% 12.97% 14.79% 16.65% 0.33% 2.13% 3.86% 5.52% 7.16% 8.82% 10.49% 12.17% 13.87% Variable Electrical Energy Sales Price Variance Amount (EURcent/kWh) IRR (with VER Revenues) IRR (without VER Revenues) -20% -15% -10% -5% 0% 5% 10% 15% 20% 4.20 4.46 4.72 4.98 5.25 5.51 5.77 6.03 6.30 2.72% 4.42% 6.07% 7.72% 9.38% 11.05% 12.74% 14.45% 16.18% 0.33% 2.13% 3.86% 5.52% 7.16% 8.82% 10.49% 12.17% 13.87% The same results are also illustrated in the following figure: Figure 3. Sensitivity Analysis Results Sensitivity Analysis Benchmark Rate 25% Project Costs with VER 20% Project Costs without VER Operational Service & Maintenance Costs with VER 15% IRR (%) Operational Service & Maintenance Costs without VER 10% Electrical Energy Generation with VER Electrical Energy Generation without VER 5% Electrical Energy Sales Price with VER 0% -20% -15% -10% -5% 0% Sensitivity (%) 5% 10% 15% 20% Electrical Energy Sales Price without VER The results found in the sensitivity analysis indicated that under all alternative scenarios for all the parameters selected with different variances, the Equity IRR value could not reach the Benchmark Discount Rate of 21.57 %. UNFCCC/CCNUCC CDM – Executive Board Page 27 Hence, the sensitivity analysis showed that the conclusion regarding financial/economic attractiveness of the project is robust to reasonable variations in the critical assumptions. The details of investment analysis can be found in the separate spreadsheet file supplied as an annex to this PDD. Outcome of Step 2: The project activity is unlikely to be financially/economically attractive. Step 3: Barrier analysis This step is not applied. Step 4: Common practice analysis According to “Tool for the demonstration and assessment of additionality-Version 07.0.0” (Hereafter referred to as “The Tool” in this section regarding the Common Practice Analysis) and “Guidelines on common practice-Version 02.0”, (Hereafter referred to as “The Guidelines” in this section regarding the Common Practice Analysis), the Common Practice Analysis procedure was applied for the project activity. The project activity is a wind farm realizing power generation based on renewable energy. Hence, it falls under the category defined in the sub-clause (ii) in the “Measure” definition of the Tool (page 5) and sub-clause (b) in the “Measure” definition of the Guidelines (page 1): “Switch of technology with or without change of energy source including energy efficiency improvement as well as use of renewable energies (example: energy efficiency improvements, power generation based on renewable energy); “ As a result, sub-step 4a was applied. Sub-step 4a: The proposed CDM project activity(ies) applies measure(s) that are listed in the definitions section above According the rules of the Guideline, the applicable geographical area is Turkey, and the output of the project activity is electricity. The stepwise approach for common practice described in the second section of the Guidelines was applied. For Step 1 of this stepwise approach, the calculation of the output range is done based on the installed capacity of the project. Since the installed capacity of the project is 72 MW, the output range will be 72 +/- 50 % = [36 – 108] MW. For Step2, firstly, identification of the similar projects was done according to the sub-paragraphs (a), (b), (c), (d) and (f) of paragraph 6 of the stepwise approach, as described on page 2 - 3 of the Guidelines. The result of this first phase is operational wind farms in Turkey at the date when the project activity is first commissioned. The below table shows these power plants: UNFCCC/CCNUCC CDM – Executive Board Page 28 Table 14. Operational Wind Power Plants in Turkey as at the Date of Commissioning of the Project Wind Projects in Turkey (As at the Commissioning of the Project) Legal Status Power Plant Name Installed Location Capacity (Province) MW 1 2 3 4 5 6 7 BOT ARES (ALAÇATI) BOT BORES (BOZCAADA) AP SUNJÜT 1.2 Istanbul IPP ALİZE ENERJİ (DELTA PLASTİK) 1.5 Izmir IPP ERTÜRK ELEKT. (TEPE) IPP ALİZE ENERJİ (ÇAMSEKİ) 20.8 Canakkale IPP 8 IPP 9 IPP ALİZE ENERJİ (KELTEPE) ALİZE ENERJİ (SARIKAYA ŞARKÖY) AK ENERJİ AYYILDIZ (BANDIRMA) IPP 1 0 1 1 1 2 1 3 1 4 1 5 1 6 1 7 1 8 1 9 2 0 2 1 2 2 2 3 2 4 2 5 2 6 Commissioning Date VER Standard VER Standard Code / Number / Project ID 7.2 Izmir 10.2 Canakkale 0.9 Istanbul 2005-04-22 20.7 Balikesir 2006-12-22 2009-06-24 GS 2010-04-28 GS GS399 GS437 28.8 Tekirdag 2009-10-19 GS GS577 15.0 Balikesir 2009-07-23 GS GS634 AKDENİZ ELEK. MERSİN RES 33.0 Mersin 2010-03-19 GS GS753 IPP AKRES (AKHİSAR RÜZGAR) 43.8 Manisa 2011-09-23 GS GS955 IPP ANEMON ENERJİ (İNTEPE) 30.4 Canakkale 2007-11-22 GS GS347 IPP ASMAKİNSAN (BANDIRMA-3 RES) 24.0 Balikesir 2010-03-26 GS GS683 IPP AYEN ENERJİ (AKBÜK) 31.5 Aydin 2009-04-03 GS GS436 IPP AYVACIK (AYRES) 2011-10-23 GS GS956 IPP BAKRAS ELEK.ŞENBÜK RES 15.0 Hatay 2010-04-22 GS GS733 IPP BARES (BANDIRMA) 30.0 Balikesir 2011-08-11 IPP BELEN HATAY 36.0 Hatay 2010-09-02 GS GS390 IPP BERGAMA RES (ALİAĞA RES) 90.0 Izmir 2010-06-16 GS GS735 IPP BORASKO BANDIRMA 60.0 Balikesir 2010-06-30 GS GS744 IPP BOREAS EN.(ENEZ RES) 15.0 Edirne 2010-04-09 GS GS702 IPP ÇANAKKALE RES (ENERJİ-SA) 29.9 Canakkale 2011-05-06 GS GS906 IPP ÇATALTEPE (ALİZE EN.) 16.0 Balikesir 2011-04-19 GS GS574 IPP DOĞAL ENERJİ (BURGAZ) 14.9 Canakkale 2008-05-08 GS GS439 IPP DENİZLİ ELEKT. (KarakurtAkhisar) 10.8 Manisa 2007-05-28 IPP MARE MANASTIR 39.2 Izmir 2007-04-13 GS 5.0 Canakkale GS, VER+ VCS, VER+ GS1072, 52-1 66 GS368 UNFCCC/CCNUCC CDM – Executive Board 2 7 2 8 2 9 3 0 3 1 3 2 3 3 3 4 3 5 3 6 3 7 3 8 3 9 4 0 4 1 4 2 4 3 4 4 4 5 4 6 4 7 4 8 4 9 5 0 5 1 Page 29 IPP MAZI 3 30.0 Izmir 2010-06-18 GS GS388 IPP KİLLİK RES (PEM EN.) 40.0 Tokat 2011-12-17 GS GS947 IPP KORES KOCADAĞ 15.0 Izmir 2009-12-23 GS GS601 IPP KUYUCAK (ALİZE ENER.) 25.6 Manisa 2010-12-09 GS GS576 IPP ROTOR (OSMANİYE RESGÖKÇEDAĞ RES) 135.0 Osmaniye 2010-10-15 GS GS474 IPP BAKİ ELEKTRİK ŞAMLI RÜZGAR 114.0 Balikesir 2011-11-13 GS GS351 IPP DATÇA RES 29.6 Mugla 2009-12-24 GS GS438 IPP ERTÜRK ELEKT. (ÇATALCA) 60.0 Istanbul 2008-12-27 GS GS367 IPP İNNORES ELEK. YUNTDAĞ 52.5 Izmir 2011-09-27 GS GS352 IPP LODOS RES (TAŞOLUK)KEMERBURGAZ 24.0 Istanbul 2008-08-20 GS GS503 IPP SARES (GARET ENER.) 22.5 Canakkale 2011-03-10 GS GS963 IPP SAYALAR RÜZGAR (DOĞAL ENERJİ) 34.2 Manisa 2009-09-06 GS GS369 IPP SEBENOBA (DENİZ ELEK.)SAMANDAĞ 30.0 Hatay 2010-03-12 IPP SEYİTALİ RES (DORUK EN.) 30.0 Izmir 2011-07-22 GS GS578 IPP SOMA RES 116.1 Manisa 2011-12-09 GS GS398 IPP SOMA RES (BİLGİN ELEK.) 90.0 Manisa 2010-11-11 GS GS655 IPP SUSURLUK (ALANTEK EN.) 45.0 Balikesir 2011-05-20 GS GS854 IPP ŞAH RES (GALATA WIND) 93.0 Balikesir 2011-07-29 GS GS905 IPP TURGUTTEPE RES (SABAŞ ELEK.) 24.0 Aydin 2011-03-04 GS GS610 IPP ÜTOPYA ELEKTRİK 30.0 Izmir 2010-09-03 GS GS672 IPP ZİYARET RES 57.5 Hatay 2011-11-24 GS GS617 IPP SÖKE-ÇATALBÜK RES 30.0 Aydin 2012-01-08 GS GS653 VCS, VER+ 553 IPP BOZYAKA RES 12.0 Izmir 2012-03-12 GS Markit GS Registry ID: 103000000 001624 IPP METRİSTEPE RES 27.5 Bilecik 2012-03-12 GS GS1067 IPP KAYADÜZÜ RES 2012-03-16 GS GS950 7.5 Amasya Abbreviations: BOT: Build-Operate-Transfer, AP: Autoproducer, IPP: Independent Power Producer, VER: Verified Emission Reduction, GS: Gold Standard, VCS: Verified Carbon Standard UNFCCC/CCNUCC CDM – Executive Board Page 30 47 wind farms were operational at the end of 201121. Four more wind farms had become operational in 2012 when the project activity was commissioned 22. As can be seen from the table, most of the wind farms (46 of 51) have been developed as CDM project activities. Only 5 wind farms are non-CDM projects. The reasons for their being non-CDM wind power projects is due to their legal status (BOT or Autoproducer), their early commissioning before the applicability of VER scheme or their small installed capacity size. If we apply the output range criterion for the identification of similar projects, as indicated in subparagraph (e) of paragraph 6 of the stepwise approach, all these 5 non-CDM projects will be eliminated, along with some of the CDM projects. If we further proceed with Steps (3), (4) and (5) of the same stepwise approach, as explained in the paragraphs, (7), (8) and (9) of the stepwise approach of the Guideline, we will see that no projects can be identified as similar to the project. Hence Nall = 0, Ndiff = 0, and the formula F = 1- Ndiff /Nall becomes not applicable. Also, as per the paragraph (10), F is indefinite and Nall - Ndiff = 0 is less than 3. So, the proposed project activity is not a “common practice”. Hence, no similar projects could be found according to the Common Practice Analysis made according to the Tool and the Guidelines, the project activity is not common practice. Outcome of Step 4: The outcome of Step 4 is that the proposed project activity is not regarded as “common practice”, hence, the proposed project activity is additional. B.6. Emission reductions B.6.1. Explanation of methodological choices To establish the baseline scenario for the project, and to calculate the baseline emissions, project emissions, leakage and emission reductions, the latest version of the official methodology, “ACM0002: Consolidated baseline methodology for grid-connected electricity generation from renewable sources --Version 13.0.0” (Hereafter referred to as “The Methodology” in this section regarding the Emission reductions) and the latest version of the official tool “Tool to calculate the emission factor for an electricity system – Version 03.0.0” (Hereafter referred to as “The Tool” in this section regarding the Emission reductions) were used. The applicability of “ACM0002: Consolidated baseline methodology for grid-connected electricity generation from renewable sources --- Version 13.0.0” (The Methodology) is justified according to the explanation given under the heading of “Applicability” on pages 2 and 3 of the Methodology, as follows: “Applicability This methodology is applicable to grid-connected renewable power generation project activities that: (a) install a new power plant at a site where no renewable power plant was operated prior to the 21 Turkish Electrical Energy 10-Year Generation Capacity Projection Report (2012-2021), Annex-1: Current System (As at the end of 2011) pp 109 - 123. (http://www.teias.gov.tr/KapasiteProjeksiyonuARALIK2012.pdf) 22 http://www.enerji.gov.tr/yayinlar_raporlar/2012_Yili_Enerji_Yatirimlari.xls UNFCCC/CCNUCC CDM – Executive Board Page 31 implementation of the project activity (greenfield plant); (b) involve a capacity addition; (c) involve a retrofit of (an) existing plant(s); or (d) involve a replacement of (an) existing plant(s). The methodology is applicable under the following conditions: The project activity is the installation, capacity addition, retrofit or replacement of a power plant/unit of one of the following types: hydro power plant/unit (either with a run-of-river reservoir or an accumulation reservoir), wind power plant/unit, geothermal power plant/unit, solar power plant/unit, wave power plant/unit or tidal power plant/unit;” Since the project is wind power greenfield plant, the Methodology is applicable. Baseline Scenario is also identified according to the rules under the heading of “Baseline Methodology Procedure” on page 4 of the Methodology: “Identification of the baseline scenario If the project activity is the installation of a new grid-connected renewable power plant/unit, the baseline scenario is the following: Electricity delivered to the grid by the project activity would have otherwise been generated by the operation of grid-connected power plants and by the addition of new generation sources, as reflected in the combined margin (CM) calculations described in the “Tool to calculate the emission factor for an electricity system.” Since the project activity is a wind power plant, project emissions are accepted as zero, PEy = 0. The project activity involves no emissions, except from a diesel generator used for emergency backup purposes. The possible emissions from the use of fossil fuels for the back up or emergency purposes by the operation of this diesel generator are neglected according to the methodology. Leakage emissions are also neglected as per the Methodology. Baseline emissions are considered according to the following explanations and formulas included in the Methodology: “Baseline emissions Baseline emissions include only CO2 emissions from electricity generation in fossil fuel fired power plants that are displaced due to the project activity. The methodology assumes that all project electricity generation above baseline levels would have been generated by existing grid-connected power plants and the addition of new grid-connected power plants. The baseline emissions are to be calculated as follows: BE y EGPJ , y * EFgrid,CM , y (1) Where: BE y = Baseline emissions in year y (tCO2/yr) EGPJ , y = EFgrid ,CM , y = Quantity of net electricity generation that is produced and fed into the grid as a result of the implementation of the CDM project activity in year y (MWh/yr) Combined margin CO2 emission factor for grid connected power generation in year y calculated using the latest version of the “Tool to calculate the emission factor for an electricity system” (tCO2/MWh) Calculation of EGPJ,y UNFCCC/CCNUCC CDM – Executive Board Page 32 The calculation of EGPJ,y is different for: (a) greenfield plants, (b) retrofits and replacements; and (c) capacity additions. These cases are described next. (a) Greenfield renewable energy power plants If the project activity is the installation of a new grid-connected renewable power plant/unit at a site where no renewable power plant was operated prior to the implementation of the project activity, then: EG PJ,y EG facility, y (2)” Emission reduction calculations are similarly based on the relevant section of the Methodology: “Emission reductions Emission reductions are calculated as follows: ERy BE y PE y (3) Where: ERy = Emission reductions in year y (tCO2e/yr) BE y = Baseline emissions in year y (tCO2/yr) PE y = Project emissions in year y (tCO2e/yr) Estimation of emissions reductions prior to validation Project participants should prepare as part of the CDM-PDD an estimate of likely emission reductions for the proposed crediting period. This estimate should, in principle, employ the same methodology as selected above. Where the grid emission factor (EFCM,grid,y) is determined ex post during monitoring, project participants may use models or other tools to estimate the emission reductions prior to validation.” Since PEy = 0, ERy = BEy. So, in order to calculate the emission reductions for the project, it will suffice to calculate the baseline emissions. Calculation of the baseline emissions was done according to the Tool as indicated in the Methodology. Six-steps in the stepwise baseline methodology procedure in the Tool were followed to calculate the baseline emissions: “Baseline methodology procedure 13. Project participants shall apply the following six steps: (a) STEP 1: identify the relevant electricity systems; (b) STEP 2: choose whether to include off-grid power plants in the project electricity system (optional); (c) STEP 3: select a method to determine the operating margin (OM); (d) STEP 4: calculate the operating margin emission factor according to the selected method; (e) STEP 5: calculate the build margin (BM) emission factor; UNFCCC/CCNUCC CDM – Executive Board Page 33 (f) STEP 6: calculate the combined margin (CM) emission factor.” Step 1: Identify the relevant electricity systems In the Tool, on page 5 - 6, the project electricity system is defined as: “A grid/project electricity system - is defined by the spatial extent of the power plants that are physically connected through transmission and distribution lines to the project activity (e.g. the renewable power plant location or the consumers where electricity is being saved) and that can be dispatched without significant transmission constraints;” Also, on page 6 of the Tool, connected electricity system is defined as: “Connected electricity system - is an electricity system that is connected by transmission lines to the project electricity system. Power plants within the connected electricity system can be dispatched without significant transmission constraints but transmission to the project electricity system has significant transmission constraint, and/or the transmission capacity of the transmission line(s) that is connecting electricity systems is less than 10 per cent of the installed capacity either of the project electricity system or of the connected electricity system, whichever is smaller;” The project activity is connected to the national grid of Turkey. There is no DNA in Turkey which has published a delinaeation of the project electricity system and the connected electricity systems. Since such information is not available, the criteria for the transmission constraints suggested on page 7 of the Tool were used to clarify the definitions of the project electricity system and the connected electricity systems. There are no available spot electricity markets in Turkey at the time of writing of this report. Also, there are no official data on availability or operational time of transmission lines in Turkey. Hence, these two criteria are not applicable. There are interconnections between Turkey and all its neighbouring countries. However, these lines are in limited capacity and have significant transmission constraints as compared to national transmission lines in Turkey.23,24 In addition, international electricity trade through these transboundary transmission lines has legal restrictions and is subject to permission of EMRA (Republic of Turkey Energy Market Regulatory Authority).25,26,27 The Turkish National Grid is operated by the responsible authority of TEIAS (Turkish Electricity Transmission Corporation). All the power plants in this system can be dispatched without significant transmission constraints. There are no layered dispatch systems (e.g. provincial/regional/national) within this national system.28,29,30 So, there are no independent separate grids in the national grid. In the light of above information and the paragraphs (17) and (18) on the page 7 of the Tool, the project electricity system is defined as Turkish National Grid, and the connected electricity systems are defined 23 http://www.teias.gov.tr/Dosyalar/NetTransferKapasiteleri.doc http://212.175.131.171/makaleler/ENTSOE%20Bağlantısı%20ICCI%20v3.pdf 25 http://www.epdk.gov.tr/documents/elektrik/mevzuat/yonetmelik/elektrik/ithalat_ihracat/Elk_Ynt_ithalat_ihracat_SonHali.doc 26 http://www.epdk.gov.tr/documents/elektrik/mevzuat/yonetmelik/elektrik/ithalat_ihracat/iliskili_mevzuat/KapasiteTahsisiEsaslar.doc 27 http://www.epdk.gov.tr/index.php/elektrik-piyasasi/lisans?id=818 28 http://www.teias.gov.tr/Hakkimizda.aspx 29 http://212.175.131.171/Faaliyet2011/ING_Teias.pdf 30 http://geni.org/globalenergy/library/national_energy_grid/turkey/ 24 UNFCCC/CCNUCC CDM – Executive Board Page 34 as the neighbouring countries of Turkey, all of which are connected to Turkish national grid by transboundary transmission lines. As per the paragraphs (19), (20), (21), (22) and (23) on page 8 of the Tool, electricity imports and exports and their usage in the emission calculations are defined. For the purpose of determining the operating margin emission factor, the CO 2 emission factor for net electricity imports from the connected electricity systems is accepted as 0 t CO2/MWh according to paragraph (21), sub-paragraph (a) of the Tool, and the electricity exports are not subtracted from electricity generation data used for calculating and monitoring the electricity emission factors according to paragraph (23) of the Tool. Step 2: Choose whether to include off-grid power plants in the project electricity system (optional) The Tool suggests two options between which the project participants may choose to calculate the operating margin and build margin emission factor: Option I : Only grid power plants are included in the calculation. Option II : Both grid power plants and off-grid power plants are included in the calculation. The rationale behind Option II is explained in the Tool as “Option II provides the option to include offgrid power generation in the grid emission factor. Option II aims to reflect that in some countries offgrid power generation is significant and can partially be displaced by CDM project activities, that is if off-grid power plants are operated due to an unreliable and unstable electricity grid.” This is not the case for the National Grid of Turkey, the selected project system. The contribution of the off-grid power plants to Turkish grid is negligible and no official or reliable data regarding the off-grid power plants in Turkey could be found. So, Option II is not appropriate. Hence, Option I is selected and only grid power plants are included in the calculation of the operating margin and build margin emission factors. Step 3: Select a method to determine the operating margin (OM) The Tool gives four following method options for the calculation of the operating margin emission factor (EFgrid,OM,y): (a) Simple OM, or (b) Simple adjusted OM, or (c) Dispatch data analysis OM, or (d) Average OM Since power plant specific data for generation, emission or emission factor are not available, “Simple adjusted OM” and “Dispatch data analysis OM” methods are not applicable. This also renders Option A of “Simple OM” method not applicable. The remaining two methods are Option B of “Simple OM” and “Average OM” methods. To decide between these two alternative methods, we have to take the situation of low-cost/must-run power plants into account. Following table summarizes the generation amounts and percentage of low-cost/must-run power plants for the five most recent years available at the time of writing of this report, that is, the period of [2007 – 2011]. Table 15. The Contribution of Low-Cost/Must-Run Power Plants to the Gross Generation of Turkey for the 5-year period of [2007 – 2011] UNFCCC/CCNUCC CDM – Executive Board Page 35 Gross Generations and Percentages by Fuel Types and Primary Energy Resources of Low-Cost/Must-Run Power Units in Turkey (Unit: GWh) Years Primary Energy Resource or Fuel Type 5-Year Total 5-Year Percentage 2007 2008 2009 2010 2011 Hard Coal + Imported Coal + Asphaltite 15,136.2 15,857.5 16,595.6 19,104.3 27,347.5 94,041.1 9.17% Lignite 38,294.7 41,858.1 39,089.5 35,942.1 38,870.4 194,054.8 18.92% Total Coal 53,430.9 57,715.6 55,685.1 55,046.4 66,217.9 288,095.8 28.10% 6,469.6 7,208.6 4,439.8 2,143.8 900.5 21,162.3 2.06% 13.3 266.3 345.8 4.3 3.1 632.8 0.06% 0.0 0.0 0.4 0.0 0.0 0.4 0.00% 43.9 43.6 17.6 31.9 0.0 137.0 0.01% 6,526.8 7,518.5 4,803.5 2,180.0 903.6 21,932.4 2.14% 95,024.8 98,685.3 96,094.7 98,143.7 104,047. 6 491,996.1 47.98% 213.7 219.9 340.1 457.5 469.2 1,700.5 0.17% Thermal 155,196. 2 164,139. 3 156,923. 4 155,827. 6 171,638. 3 803,724.8 78.38% Hydro + Geothermal + Wind Total 36,361.9 34,278.7 37,889.5 55,380.1 57,756.8 221,667.0 21.62% Hydro 35,850.8 33,269.8 35,958.4 51,795.5 52,338.6 209,213.1 20.40% 511.1 1,008.9 1,931.1 3,584.6 5,418.2 12,453.9 1.21% General Total (Gross) 191,558. 1 198,418. 0 194,812. 9 211,207. 7 229,395. 1 1,025,391. 8 100.00% Gross - Low-Cost/Must-Run 36,361.9 34,278.7 37,889.5 55,380.1 57,756.8 221,667.0 21.62% Gross Excluding Low-Cost/Must-Run (Thermal) 155,196. 2 164,139. 3 156,923. 4 155,827. 6 171,638. 3 803,724.8 78.38% Fuel-Oil Diesel Oil LPG Naphtha Total Oil (Liquid Total) Natural Gas Renewables and Wastes Geothermal + Wind The selection of the low-cost/must run power plants was done according to the definition on page 6 of the Tool: “Low-cost/must-run resources - are defined as power plants with low marginal generation costs or dispatched independently of the daily or seasonal load of the grid. They include hydro, geothermal, wind, low-cost biomass, nuclear and solar generation. If a fossil fuel plant is dispatched independently of the daily or seasonal load of the grid and if this can be demonstrated based on the publicly available data, it should be considered as a low-cost/must-run;” Hence, the selection in the table which assumes the total of hydro, geothermal and wind as the lowcost/must-run resources is justified. Since there are no nuclear power plants and also no grid-connected solar power plants in Turkey at the time of writing of this report, these resource types are automatically excluded. As can be seen from the table, low-cost/must-run resources constitute less than 50 per cent of total grid generation (excluding electricity generated by off-grid power plants) in average of the five most recent years [2007 – 2011], which is in line with the relevant rule, paragraph 34 on page 9 – 10 of the Tool: UNFCCC/CCNUCC CDM – Executive Board Page 36 “The simple OM method (Option a) can only be used if low-cost/must-run resources constitute less than 50 per cent of total grid generation (excluding electricity generated by off-grid power plants) in: 1) average of the five most recent years, or 2) based on long-term averages for hydroelectricity production.” The rules for the usability of Simple OM method Option, which was stated in paragraph 42, on page 11 of the Tool, as below, are also met: “42. Option B can only be used if: (a) The necessary data for Option A is not available; and (b) Only nuclear and renewable power generation are considered as low-cost/must-run power sources and the quantity of electricity supplied to the grid by these sources is known; and (c) Off-grid power plants are not included in the calculation (i.e. if Option I has been chosen in Step 2).” As a result, Option B of Simple OM method was selected as the method to determine the operating margin. Ex ante option was preferred to calculate the emissions factor, and the reference period was selected as the three-year period of [2009 – 2011], as per the requirements stated in paragraph 36, sub-paragraph (a) on page 10 of the Tool: “36. For the simple OM, the simple adjusted OM and the average OM, the emissions factor can be calculated using either of the two following data vintages: (a) Ex ante option: if the ex ante option is chosen, the emission factor is determined once at the validation stage, thus no monitoring and recalculation of the emissions factor during the crediting period is required. For grid power plants, use a 3-year generation-weighted average, based on the most recent data available at the time of submission of the CDM-PDD to the DOE for validation. For off-grid power plants, use a single calendar year within the five most recent calendar years prior to the time of submission of the CDM-PDD for validation;” Step 4: Calculate the operating margin emission factor according to the selected method Operating Margin Emission Factor was calculated using the formulation and procedure described in the paragraphs (49) and (50) in sub-section 6.4.1.2., on pages 14 – 15 of the Tool: “6.4.1.2. Option B: Calculation based on total fuel consumption and electricity generation of the system 49. Under this option, the simple OM emission factor is calculated based on the net electricity supplied to the grid by all power plants serving the system, not including low-cost/must-run power plants/units, and based on the fuel type(s) and total fuel consumption of the project electricity system, as follows: EFgrid,OMsimple, y FC i i, y NCVi , y EFCO2 ,i , y EG y Equation (7) UNFCCC/CCNUCC CDM – Executive Board Page 37 Where: EFgrid,OMsimple, y FCi,y NCVi,y EFCO2,i,y EGy i y 50. = Simple operating margin CO2 emission factor in year y (t CO2/MWh) = Amount of fuel type i consumed in the project electricity system in year y (mass or volume unit) = Net calorific value (energy content) of fuel type i in year y (GJ/mass or volume unit) = CO2 emission factor of fuel type i in year y (t CO2/GJ) = Net electricity generated and delivered to the grid by all power sources serving the system, not including low-cost/must-run power plants/units, in year y (MWh) = All fuel types combusted in power sources in the project electricity system in year y = The relevant year as per the data vintage chosen in Step 3 For this approach (simple OM) to calculate the operating margin, the subscript m refers to the power plants/units delivering electricity to the grid, not including low-cost/must-run power plants/units, and including electricity imports5 to the grid. Electricity imports should be treated as one power plant m.” Fossil fuel types and their amounts were taken from the official data of Electricity Generation & Transmission Statistics of Turkey, published by TEIAS (Turkish Electricity Transmission Company, the state authority responsible for the national transmission system of Turkey), as indicated in the table below1: Table 16. Fuel Consumption in Electricity Generation in Turkey for the 3-year period of [2009 – 2011] Fuel Consumption in Electricity Generation Excluding LowCost/Must-Run (Unit: Ton (solid and liquid) /103 m3 (gas)) Years 2007 2008 2009 2010 2011 Hard Coal+Imported 6,029,143.0 6,270,008.0 6,621,177.0 7,419,703.0 10,574,434.0 Coal+Asphaltite Lignite 61,223,821.0 66,374,120.0 63,620,518.0 56,689,392.0 61,507,310.0 Fuel Oil 2,250,686.0 2,173,371.0 1,594,321.0 891,782.0 531,608.0 Diesel oil 50,233.0 131,206.0 180,857.0 20,354.0 15,047.0 LPG 0.0 0.0 111.0 0.0 0.0 Naphtha 11,441.0 10,606.0 8,077.0 13,140.0 0.0 Natural Gas 20,457,793.0 21,607,635.0 20,978,040.0 21,783,414.0 22,804,587.0 Renewables and Wastes* * Since heating values and fuel amounts of renewable and waste materials are not included in TEIAS Statistics, these are also ignored here. To calculate the Net Calorific Values, data on heating values of fuels consumed in thermal power plants in Turkey by the electric utilities31 along with the fuel amounts mentioned above were used. 31 http://www.teias.gov.tr/TürkiyeElektrikİstatistikleri/istatistik2011/yakıt46-49/49.xls UNFCCC/CCNUCC CDM – Executive Board Page 38 Table 17. Heating Values of Fuels Consumed in Thermal Power Plants in Turkey by the Electric Utilities [2006 – 2011] Years Heating Values of Fuels Consumed in Thermal Power Plants (Unit: Tcal) 2007 2008 2009 2010 2011 Hard Coal+Imported Coal+Asphaltite 32,115.0 33,310.0 35,129.8 39,546.5 57,567.3 Lignite 100,320.0 108,227.0 97,651.6 96,551.0 107,209.5 Fuel Oil 21,434.0 20,607.0 15,159.9 8,569.1 5,279.9 Diesel oil 517.0 1,328.0 1,830.2 209.5 155.1 LPG 0.0 0.0 1.2 0.0 0.0 Naphtha 118.0 113.0 84.2 105.1 0.0 Natural Gas 179,634.0 189,057.0 186,265.8 194,487.3 202,064.1 Renewables and Wastes* Turkey's Thermal Total 334,138.0 352,642.0 336,122.7 339,468.5 372,275.9 * Since heating values and fuel amounts of renewable and waste materials are not included in TEIAS Statistics, these are also ignored here. Since there are no plant-specific or fuel-type specific emission factor data officially available in Turkey, we have to use the emission factors published by IPCC.32 The related emission factors are indicated in the following table: Table 18. IPCC Default Emission Factor Values by Different Fuel Types Table 1.4 Default CO2 Emission Factors for Combustion Fuel Type Effective CO2 Emission Factor (kg/TJ) Default Lower Upper Anthracite 98,300 94,600 101,000 Coking Coal 94,600 87,300 101,000 Other Bituminous Coal 94,600 89,500 99,700 Sub-Bituminous Coal 96,100 92,800 100,000 Lignite 101,000 90,900 115,000 Fuel Oil 77,400 75,500 78,800 Diesel Oil 74,100 72,600 74,800 LPG 63,100 61,600 65,600 Naphtha 73,300 69,300 76,300 Natural Gas 56,100 54,300 58,300 For the sake of conservativeness, the lower limits of the 95 percent confidence intervals were used in the calculation of Operating Margin Emission Factor. Since the emission factors of IPCC are based on mass-units, and the fuel consumption amounts for natural gas is given in volume units in TEIAS statistics, we should convert the amount of natural gas from volume units to mass units. For this purpose, the density of natural gas must be specified. Natural 32 http://www.ipcc-nggip.iges.or.jp/public/2006gl/pdf/2_Volume2/V2_1_Ch1_Introduction.pdf UNFCCC/CCNUCC CDM – Executive Board Page 39 Gas Density of Turkey for Electricity Generation was calculated using the data for Turkey in International Energy Agency’s (IEA) Natural Gas Information (2010 Edition)33, IEA Key World Energy Statistics 201134, and IEA Energy Statistics Manual35. Turkey’s main natural gas supplier is Russian Federation, along with its neighbouring countries 36. This fact is also confirmed by IEA Natural Gas Information 33 by comparing average gross calorific value of natural gas of Turkey for consumption and that of Russian Federation for production. So, natural gas produced and exported by Russian Federation and imported and consumed by Turkey was accepted as the representative of natural gas used as fuel in electricity generation in Turkish National Grid. To calculate the density of natural gas, the following table33 was used: Table 19. Conversion Factors from Mass or Volume to Heat (Gross Calorific Value) for Natural Gas Supplied by Russian Federation GAS Russia To: From: cm* MJ Btu multiply by: 38.23 Kg 55.25 * Standard Cubic Meters 36,235 52,363 This gives us a natural gas density of 0.692 kg/m3, which we used to calculate the mass of natural gas used as fuel in power plants in Turkey for electricity generation. As a result, the Fuel Consumption in Electricity Generation in Turkey can be shown again with all the amounts in mass units as in the following table: Table 20. Fuel Consumption in Electricity Generation in Turkey for the 3-year period of [2009 – 2011] (in mass units) Fuel Consumption in Electricity Generation Excluding LowCost/Must-Run (Unit: Ton) Hard Coal+Imported Coal+Asphaltite Lignite Fuel Oil Diesel oil LPG Naphtha 33 Years 2007 2008 2009 2010 2011 6,029,143.0 6,270,008.0 6,621,177.0 7,419,703.0 10,574,434.0 61,223,821.0 2,250,686.0 50,233.0 0.0 11,441.0 66,374,120.0 2,173,371.0 131,206.0 0.0 10,606.0 63,620,518.0 1,594,321.0 180,857.0 111.0 8,077.0 56,689,392.0 891,782.0 20,354.0 0.0 13,140.0 61,507,310.0 531,608.0 15,047.0 0.0 0.0 IEA Statistics, Natural Gas Information 2010, International Energy Agency - Introductory Information, Section 7, Abbreviations and conversion factors, pp. xxvii - xxx. 34 http://www.iea.org/publications/freepublications/publication/key_world_energy_stats-1.pdf, Conversion Factors, pp. 58 – 60. 35 http://www.iea.org/publications/freepublications/publication/statistics_manual.pdf, Annex 3 Units and Conversion Equivalents – Natural Gas – pp. 182 – 183. 36 BOTAS (Petroleum Pipeline Corporation) Natural Gas Purchase Agreements Information (http://www.botas.gov.tr/) UNFCCC/CCNUCC CDM – Executive Board Page 40 Natural Gas 14,155,681.9 14,951,310.2 14,515,664.6 15,072,939.7 15,779,535.9 Renewables and Wastes* Turkey's Thermal Total 83,721,005.9 89,910,621.2 86,540,725.6 80,107,310.7 88,407,934.9 * Since heating values and fuel amounts of renewable and waste materials are not included in TEIAS Statistics, these are also ignored here. Net Calorific Values can be calculated using the heating values and the fuel amounts: Table 21. Net Calorific Values calculated for fuel types in Electricity Generation in Turkey for the 3-year period of [2009 – 2011] Net Calorific Values of Fuels Consumed in Thermal Power Plants (Unit: TJ/Gg) Hard Coal+Imported Coal+Asphaltite Lignite Years 2007 2008 2009 2010 2011 22.3 22.2 22.2 22.3 22.8 6.9 6.8 6.4 7.1 7.3 Fuel Oil 39.9 39.7 39.8 40.2 41.6 Diesel oil 43.1 42.4 42.4 43.1 43.2 0.0 0.0 46.5 0.0 0.0 Naphtha 43.2 44.6 43.6 33.5 0.0 Natural Gas 53.1 52.9 53.7 54.0 53.6 0.0 0.0 LPG 0.0 0.0 0.0 Renewables and Wastes* * Assumed as zero due to unavailability of data and conservativeness It is not very clear whether the heating values given in TEIAS statisitics31 are lower heating values (Net Calorific Values = NCV) or higher heating values (Gross Calorific Values = GCV). However, some other sources of state, academic and NGO (chamber of engineers) origin confirm that these are lower heating values (net calorific values) by giving values in the same range as the calculated NCV values37,38,39,40,41,42. Moreover, these data is compliant with the value given in National Inventory Reports and Common Report Formats of Turkey submitted to UNFCCC, in which it was also stated that the heating values given are NCV values43,44. As a result, these values are assumed to be the net calorific values of thermal power plants in Turkey for the relevant period. Turkey’s Net Electricity Generation by primary energy resources was not given in the TEIAS Turkish Electricity Generation – Transmission Statistics 45 . Instead, Gross Electricity Generation by primary 37 http://enver.eie.gov.tr/DocObjects/Download/60094/TepHesap.xls http://www.hkad.org/makaleler/cilt1/sayi1/HKAD-12-004.pdf 39 http://www.enerji.gov.tr/yayinlar_raporlar/Sektor_Raporu_TKI_2011.pdf 40 http://www.mmo.org.tr/resimler/dosya_ekler/a9393ba5ea45a12_ek.pdf 41 http://www.mmo.org.tr/resimler/dosya_ekler/b4d09fdaf9131ab_ek.pdf?dergi=1148 42 http://tez.sdu.edu.tr/Tezler/TF00997.pdf 43 http://unfccc.int/files/national_reports/annex_i_ghg_inventories/national_inventories_submissions/application/zip/tur-2013-nir15apr.zip 44 http://unfccc.int/files/national_reports/annex_i_ghg_inventories/national_inventories_submissions/application/zip/tur-2013-crf12apr.zip 45 http://www.teias.gov.tr/istatistikler.aspx, http://www.teias.gov.tr/Eng/StatisticalReports.aspx 38 UNFCCC/CCNUCC CDM – Executive Board Page 41 energy resources46, net generation amount and percentages for the whole national grid regardless of the primary energy resources are available47. As a result, it becomes necessary to calculate the net generation by primary energy resources by using these two data sets available. For this purpose, the net/gross electricity generation ratio was assumed to be the same for all primary energy resources. According to some studies made on this subject, the net/gross electricity generation ratio of renewable energy power plants is slightly higher than that of thermal power plants 48,49. Since the gross generation percentage of renewable energy power plants is lower than the percentage of thermal power plants, using the same average net/gross electricity generation ratio for all power plants would result in a slightly lower share for renewable energy power plants in the total net electricity generation than it would be if we used the actual net/gross electricity generation ratios. Likewise, the net generation share of thermal power plants will be slightly higher than that it would normally be. This would cause a slightly higher operational margin emission factor value for the whole system, if we used all the power plants including renewable ones, in the emission factor calculation. This would still be acceptable since the difference between net/gross electricity generation ratio of renewable and non-renewable power plants is very low (about 1 – 2 %), and could be assumed in the allowed error range. However, by choosing Option B of Simple OM method for operating margin emission factor calculation, we excluded all the low-cost/must-run power plants, that is, renewable ones. So, the impact of net/gross electricity generation ratio for renewable power plants is automatically eliminated. Since the corresponding ratio for different thermal plants is almost the same, using the same average net/gross electricity generation ratio for all thermal power plants is acceptable. The following table summarizes the calculation of net electricity generation from gross electricity generation distribution by primary energy resources and net/gross electricity generation ratio for all system. Table 22. Net Electricity Generation Calculation by Primary Energy Resources for Turkey for the 5-year period of [2007 – 2011] Gross & Net Generations and Percentages of Fuel Types and Primary Energy Resources (Unit: GWh) Years Primary Energy Resource or Fuel Type 5-Year Percentag e 94,041.1 9.17% 5-Year Total 2007 2008 2009 2010 2011 Hard Coal + Imported Coal + Asphaltite 15,136.2 15,857.5 16,595.6 19,104.3 27,347.5 Lignite 38,294.7 41,858.1 39,089.5 35,942.1 38,870.4 194,054.8 18.92% Total Coal 53,430.9 57,715.6 55,685.1 55,046.4 66,217.9 288,095.8 28.10% 6,469.6 7,208.6 4,439.8 2,143.8 900.5 21,162.3 2.06% 13.3 266.3 345.8 4.3 3.1 632.8 0.06% 0.0 0.0 0.4 0.0 0.0 0.4 0.00% 43.9 43.6 17.6 31.9 0.0 137.0 0.01% 6,526.8 7,518.5 4,803.5 2,180.0 21,932.4 2.14% 95,024.8 98,685.3 96,094.7 98,143.7 491,996.1 47.98% 213.7 219.9 340.1 457.5 903.6 104,047. 6 469.2 1,700.5 0.17% Fuel-Oil Diesel Oil LPG Naphtha Total Oil (Liquid Total) Natural Gas Renewables and Wastes 46 http://www.teias.gov.tr/TürkiyeElektrikİstatistikleri/istatistik2011/uretim%20tuketim(22-45)/40(06-11).xls http://www.teias.gov.tr/TürkiyeElektrikİstatistikleri/istatistik2011/uretim%20tuketim(22-45)/33(84-11).xls 48 http://www.pserc.wisc.edu/documents/publications/special_interest_publications/EPRI_Electricity_Use_Report_Final_1024651. pdf, pp. 2-6 – 2-14. 49 ftp://ftp.eia.doe.gov/electricity/epatech.pdf, pp 2 – 4. 47 UNFCCC/CCNUCC CDM – Executive Board Page 42 Hydro + Geothermal + Wind Total 155,196. 2 36,361.9 164,139. 3 34,278.7 156,923. 4 37,889.5 155,827. 6 55,380.1 171,638. 3 57,756.8 Hydro 35,850.8 33,269.8 35,958.4 51,795.5 511.1 1,008.9 1,931.1 162.4 191,558. 1 183,339. 7 95.71% 36,361.9 155,196. 2 34,801.9 148,537. 8 Thermal Geothermal + Wind Geothermal Wind General Total (Gross) General Total (Net) Net / Gross Ratio Gross - Low-Cost/Must-Run Gross Excluding Low-Cost/Must-Run (Thermal) Net - Low-Cost/Must-Run Net Excluding Low-Cost/Must-Run (Thermal) 803,724.8 78.38% 221,667.0 21.62% 52,338.6 209,213.1 20.40% 3,584.6 5,418.2 12,453.9 1.21% 435.7 668.2 694.3 1,960.7 0.19% 846.5 198,418. 0 189,761. 9 95.64% 1,495.4 194,812. 9 186,619. 3 95.79% 2,916.4 211,207. 7 203,046. 1 96.14% 4,723.9 9,982.1 229,395. 1,025,391.8 1 217,557. 980,324.7 7 94.84% 95.60% 0.97% 34,278.7 164,139. 3 32,783.3 156,978. 6 37,889.5 156,923. 4 36,295.9 150,323. 4 55,380.1 155,827. 6 53,240.1 149,806. 0 57,756.8 171,638. 3 54,776.4 162,781. 3 100.00% 95.60% 221,667.0 21.62% 803,724.8 78.38% 211,897.5 768,427.2 The operating margin emission factor was calculated using the above assumptions, data and formulations. The details are in the Section “B.6.3. Ex ante calculation of emission reductions”. Step 5: Calculate the build margin (BM) emission factor For this step, Option I indicated in paragraph 68 of the Tool was chosen and the build margin emission factor is calculated ex ante based on the most recent information available at the time of writing this report. Power plant based generation data is unavailable for Turkish National Grid. However, plant based generation capacity data is available in annually published Capacity Projection Reports of TEIAS 50. The latest of these reports, “Turkish Electrical Energy 10-Year Generation Capacity Projection Report 2012 – 2021 (with definitive values of year 2011)”4 was used as the reference for build margin emission calculation. In this report, there are “Project Generation Capacity” and “Firm Generation Capacity” for each power plant. Project Generation Capacity is the value written on the generation licence given by EMRA for each power plant, and indicates the generation that could be achieved under ideal conditions. Firm Generation Capacity reflects the real generation capacity, taking into account various parameters that could affect the generation, and mostly based on the actual generations of the previous years. Hence, firm generation capacities of power plants indicated in this report were selected as the reference generation data for the build margin emission calculation. The total firm generation capacity in 2011 is calculated as 266,380.9 GWh 21, a figure higher than total gross generation of 229,395.1 GWh in 201146,47. This is expected, since the full annual firm generation capacities of power plants commissioned in 2011 have been taken into account. Since the real contribution of firm generation capacities of power plants commissioned in 2011 to real gross generation in 2011 is very hard to calculate, the firm generation capacities of all power plants at the end of 2011 is assumed as their gross generation in 2011, to calculate the build margin emission factor calculation. This is also in line with the logic behind the build margin emission factor calculation, that is, this assumption reflects the impact of power plants that started to supply electricity to the grid most recently better. 50 http://www.teias.gov.tr/KapasiteProjeksiyonu.aspx UNFCCC/CCNUCC CDM – Executive Board Page 43 The “Turkish Electrical Energy 10-Year Generation Capacity Projection Report 2012 – 2021 (with definitive values of year 2011)” gives the definitive situation of the Turkish Energy Generation System as at the end of 2011. At this date, there were 643 power plants in Turkey2,3,4. 618 of these were listed namely, 25 of them under the categorisation of “Others” in 5 different places in the Annex 1 of the report21. So, since it is impossible to specify the names and commissioning dates of the power plants in the “Others” category, these were excluded in the build margin emission factor calculation. Capacity additions of retrofits of power plants were selected by comparing the installed capacity values and fuel types given in the capacity projection reports for different years50, and explanations given in energy investment data of Ministry of Energy and Natural Resources of Turkey 51 , which includes commissioning dates of all power plants in Turkey beginning from 2003. CDM-VER project activities in Turkey at the end of 2011 were specified by using the registry web sites of emission reduction standards used in Turkey, i.e. Gold Standard (GS), Verified Carbon Standard (VCS), and VER+ standards 52,53,54,55. A total of 125 power plants have been specified as CDM-VER Projects in Turkey listed in the registry sites of these standards. The commissioning of power plants in Turkey are often made in multiple stages, as allowed in the “Electrical Installations Acceptance Bylaw”56. The rationale of this procedure is mostly to commission the part or group of the power plant that has been completed and ready to be commissioned without having to wait for all the power plant to be completed; and not to lose revenues from electricity sales in this period. These single stages of commissionings are called “provisional acceptance” and represents the date on which the electricity generated by the power plant started to be sold. As a result, these partial commissionings, which are the individual stages of commissioning process indicated by provisional acceptances, have to be taken into account to calculate the build margin emission factor correctly. For this reason, each single partial commissioning of a power plant was considered as a separate power unit. The project and firm generation of each power unit was found by multiplying the total project and firm generation of the power plant by the ratio found by dividing the installed capacity of the power unit by that of the whole power plant. The dates of commissionings, or power units, were taken from Capacity Projection Reports of TEIAS50 and Energy Investment Data of Ministry of Energy51. The commissionings were sorted by their dates beginning from the newest to the oldest to identify the two sets of power units SET5-units, and SET20 per cent, according to paragraph 71 on the page 20 of the Tool. The calculation of build margin emission factor calculation is done according to the paragraph 73 and 73, on pages 22 – 23 of the Tool: 51 http://www.enerji.gov.tr/index.php?dil=tr&sf=webpages&b=yayinlar_raporlar&bn=550&hn=&id=3273 http://goldstandard.apx.com/ 53 http://www.markit.com/sites/en/products/environmental/markit-environmental-registry-public-view.page 54 https://vcsprojectdatabase2.apx.com/myModule/Interactive.asp?Tab=Projects&a=1 55 http://www.netinform.de/KE/Wegweiser/Ebene1_Projekte2.aspx?Ebene1_ID=49&mode=4 56 http://www.resmigazete.gov.tr/arsiv/22280.pdf, pp. 2 – 37. 52 UNFCCC/CCNUCC CDM – Executive Board “73. Page 44 The build margin emissions factor is the generation-weighted average emission factor (t CO2/MWh) of all power units m during the most recent year y for which electricity generation data is available, calculated as follows: EFgrid ,BM , y m EG m , y EFEL ,m, y m EG m, y Equation (13) Where: EFgrid,BM,y = Build margin CO2 emission factor in year y (t CO2/MWh) EGm,y = Net quantity of electricity generated and delivered to the grid by power unit m in year y (MWh) = CO2 emission factor of power unit m in year y (t CO2/MWh) = Power units included in the build margin = Most recent historical year for which electricity generation data is available EFEL,m,y m y 74. The CO2 emission factor of each power unit m (EFEL,m,y)should be determined as per the guidance in Step 4 section 6.4.1 for the simple OM, using Options A1, A2 or A3, using for y the most recent historical year for which electricity generation data is available, and using for m the power units included in the build margin.” Since the power plant based data of emission factors and consumed fuels are not available, but generations and fuel types are available for the sample group of power units m used to calculate the build margin, only Option A2 of the Simple OM method is convenient for a calculation. So, emission factor for power plants for each fuel is calculated as indicated in the following sub-paragraph (b) of paragraph 44 on page 12 of the Tool: “(b) Option A2 - If for a power unit m only data on electricity generation and the fuel types used is available, the emission factor should be determined based on the CO2 emission factor of the fuel type used and the efficiency of the power unit, as follows: EFEL ,m, y EFCO2 ,m ,i , y 3.6 m, y Equation (3) Where: EFEL,m,y EFCO2,m,i,y ηm,y m y = CO2 emission factor of power unit m in year y (t CO2/MWh) = Average CO2 emission factor of fuel type i used in power unit m in year y (t CO2/GJ) = Average net energy conversion efficiency of power unit m in year y (ratio) = All power units serving the grid in year y except low-cost/must-run power units = The relevant year as per the data vintage chosen in Step 3 For the average emission factor of fuel types, the emission factors published by IPCC32 were taken as reference, and the lower limits of the 95 percent confidence intervals were used, as in the calculation of Operating Margin Emission Factor. UNFCCC/CCNUCC CDM – Executive Board Page 45 For the average net energy conversion efficiency of the power units for each fuel type, Table 1 in Appendix 1 on page 33 of the Tool was taken as reference, as indicated in the table below. Table 23. IPCC Default Efficiency Factors for Grid Power Plants Appendix 1. Default efficiency factors for power plants - Table 1. Grid power plants Grid Power Plant Old Units (before Generation Technology and in 2000) Coal Subcritical 37.0% Supercritical Ultra-Supercriticial IGCC FBS 35.5% CFBS 36.5% PFBS Oil Steam turbine 37.5% Open cycle 30.0% Combined cycle 46.0% Natural gas Steam turbine 37.5% Open cycle 30.0% Combined cycle 46.0% New Units (after 2000) 39.0% 45.0% 50.0% 50.0% 40.0% 41.5% 39.0% 39.5% 46.0% 37.5% 39.5% 60.0% For most of the power plants included in the build margin emission factor calculation, power-plant specific data could not be found. For these, the data in the above table was used and maximum applicable values considering conservativeness were taken. The values for new units (after 2000) were used. However, for the thermal power plants using imported coal that were in the build margin emission calculation set, the efficiency data had been able to be found 57. For these, generation-weighted average efficiency was calculated and this value is used in the build margin emission factor calculation, as indicated in the following table: Table 24. Efficiency Factors for Power Plants Using Imported Coal as the Fuel in the Sample Group used in the Build Margin Emission Calculation 57 Panel about “Coal-Fired Power Plants and Investment Models”, Middle East Technical University Alumni Association Visnelik Facility, 23 February 2013 / Saturday / 13:30, Presentation given by Muzaffer BASARAN, http://www.odtumd.org.tr/dosyaArsivi/Etkinlik/muzaffer_basaran_odtu_komur_santral_230213.pptx, slides 31 – 40. UNFCCC/CCNUCC CDM – Executive Board Fuel / Legal Energy POWER PLANT NAME Status Source IPP IC IPP IC IPP IC IPP IC IPP IC IPP BEKİRLİ TES (İÇDAŞ ELEKT.) EREN ENERJİ ELEK.ÜR.A.Ş. EREN ENERJİ ELEK.ÜR.A.Ş. EREN ENERJİ ELEK.ÜR.A.Ş. Page 46 Firm Installed Generation Capacity Capacity MW (year 2012) GWh Commissioning Date Location (Province) Efficiency Firm Generation x Efficiency 600.000 4,320.0 2011-12-15 Canakkale 41.5% 1,792.80 600.000 4,005.9 2010-12-29 Zonguldak 42.0% 1,682.47 600.000 4,005.9 2010-11-01 Zonguldak 42.0% 1,682.47 160.000 1,068.2 2010-07-15 Zonguldak 41.0% 437.98 İÇDAŞ ÇELİK 135.000 961.7 2009-10-13 Canakkale 35.0% 336.58 IC İÇDAŞ ÇELİK 135.000 961.7 2009-07-24 Canakkale 35.0% 336.58 IC TOTAL 2,230.0 40.9% 6,268.9 15,323.3 Average Efficiency This result is compatible with the information given by IEA (International Energy Agency), in which it was stated that supercritical pulverised (SCPC) is the dominant option for new coal fired power plants and maximum value for generating efficiency of SCPC plants is 46% (lower heating value, LHV), as of 201058. For the power plants using other types of solid fuels (hard coal, lignite, asphaltite, and waste materials incinerated), since there are no specific data that could be found, the efficiency factor is assumed as equal to that of imported coal, and the value that is nearest to the efficiency calculated for power plants using imported coal in the IPCC Default Efficiency Factors Table (Table 23), that is 41.5 %, was accepted as the efficiency factor. This is in line with the rule of conservativeness, since generally efficiency of other types of coal and other solid fuels is expected to be lower than that of imported coal, which is of higher quality. Also, since the share of other types of solid wastes are very small as compared to that of imported coal, their effect is minimal. For natural gas, the maximum value (60.0 %) was. For naphta, biogas, and liquefied petroleum gas (LPG) The efficiency factor is accepted as equal to natural gas. For liquid fuels except naphta, that is fuel oil and diesel oil, the efficiency factor is accepted as the maximum value in the table, 46 %, according to the rule of conservativeness. The results were put into the Equation (13) on page 22 of the Tool to calculate the Build Margin Emission Factor. Step 6: Calculate the combined margin emissions factor The calculation of the combined margin (CM) emission factor (EFgrid,CM,y) is done preferring the Weighted Average CM method, as indicated in paragraphs 77, 78, and 79 in the sub-section 6.6 on page 23 of the Tool. The weighted average combined margin emission factor calculation is done according to paragraphs 80 and 81 on pages 23 – 24 of the Tool, as follows: “80. 58 The combined margin emissions factor is calculated as follows: http://www.iea-etsap.org/web/E-TechDS/PDF/E01-coal-fired-power-GS-AD-gct.pdf, p. 1. UNFCCC/CCNUCC CDM – Executive Board Page 47 EFgrid ,CM , y EFgrid ,OM , y wOM EFgrid ,BM , y wBM Equation (14) Where: EFgrid,BM,y EFgrid,OM,y wOM wBM 81. = = = = Build margin CO2 emission factor in year y (t CO2/MWh) Operating margin CO2 emission factor in year y (t CO2/MWh) Weighting of operating margin emissions factor (per cent) Weighting of build margin emissions factor (per cent) The following default values should be used for wOM and wBM: (a) Wind and solar power generation project activities: wOM = 0.75 and wBM = 0.25 (owing to their intermittent and non-dispatchable nature) for the first crediting period and for subsequent crediting periods; (b) All other projects: wOM = 0.5 and wBM = 0.5 for the first crediting period, and wOM = 0.25 and wBM = 0.75 for the second and third crediting period,6 unless otherwise specified in the approved methodology which refers to this tool.” The details are in the Section “B.6.3. Ex ante calculation of emission reductions”. B.6.2. Data and parameters fixed ex ante Data / Parameter EGgross,y Unit GWh Description Total quantity of gross electricity generation of power plants connected to the grid including low-cost/must-run power plants in year y for years in the 5-year period of [2007 – 2011]. Source of data Official data from TEIAS (Turkish Electricity Transmission Company), the responsible authority for the operation of Turkish National Grid. Value(s) applied See Section B.6.3 and/or Appendix 4 for details. Choice of data or Measurement methods and procedures Official data. According to the regulations regarding the Turkish Statistical Institute, the state organization responsible for the statistical affairs in the Republic of Turkey, TEIAS is the official source of data for energy59,60. Purpose of data Calculation of baseline emissions. Additional comment 59 http://www.turkstat.gov.tr/rip/rip.pdf http://www.tuik.gov.tr/rip/temalar/4_3.html 60 UNFCCC/CCNUCC CDM – Executive Board Page 48 Data / Parameter EGgross,i,y Unit GWh Description Quantity of gross electricity generation of power plants using fuel type / utilizing primary energy source i connected to the grid including lowcost/must-run power plants in year y for years in the 5-year period of [2007 – 2011]. Source of data Official data from TEIAS (Turkish Electricity Transmission Company), the responsible authority for the operation of Turkish National Grid. Value(s) applied See Section B.6.3 and/or Appendix 4 for details Choice of data or Measurement methods and procedures Official data. According to the regulations regarding the Turkish Statistical Institute, the state organization responsible for the statistical affairs in the Republic of Turkey, TEIAS is the official source of data for energy59,60. Since power plant based data is unavailable, the amounts of generation for group of power plants using the same fuel type / utilizing the same primary energy source i were used. Purpose of data Calculation of baseline emissions. Additional comment Data / Parameter EG,y Unit GWh Description Total net quantity of electricity generation of power plants connected to the grid, not including low-cost/must-run power plants in year y for years in the 5-year period of [2007 – 2011]. Source of data Official data from TEIAS (Turkish Electricity Transmission Company), the responsible authority for the operation of Turkish National Grid. Value(s) applied See Section B.6.3 and/or Appendix 4 for details Choice of data or Measurement methods and procedures Official data. According to the regulations regarding the Turkish Statistical Institute, the state organization responsible for the statistical affairs in the Republic of Turkey, TEIAS is the official source of data for energy59,60. Purpose of data Calculation of baseline emissions. Additional comment - UNFCCC/CCNUCC CDM – Executive Board Page 49 Data / Parameter EGi,y Unit GWh Description Net quantity of electricity generation of power plants using fuel type i connected to the grid, not including low-cost/must-run power plants in year y for years in the 5-year period of [2007 – 2011]. Source of data Official data from TEIAS (Turkish Electricity Transmission Company), the responsible authority for the operation of Turkish National Grid. Value(s) applied See Section B.6.3 and/or Appendix 4 for details Choice of data or Measurement methods and procedures Official data. According to the regulations regarding the Turkish Statistical Institute, the state organization responsible for the statistical affairs in the Republic of Turkey, TEIAS is the official source of data for energy59,60. Since power plant based and fuel/primary energy source specific data is not available, net electricity generation of each group of power plants using the same fuel i for that year y was calculated applying the same net/gross electricity generation ratio for that year y to gross generation of each group of power plants using the same fuel i in that year y. Purpose of data Calculation of baseline emissions. Additional comment - Data / Parameter EGimport,y Unit GWh Description Quantity of electricity imports in year y for years in the 5-year period of [2007 – 2011]. Source of data Official data from TEIAS (Turkish Electricity Transmission Company), the responsible authority for the operation of Turkish National Grid. Value(s) applied See Section B.6.3 and/or Appendix 4 for details Choice of data or Measurement methods and procedures Official data. According to the regulations regarding the Turkish Statistical Institute, the state organization responsible for the statistical affairs in the Republic of Turkey, TEIAS is the official source of data for energy59,60. Purpose of data Calculation of baseline emissions. Additional comment - UNFCCC/CCNUCC CDM – Executive Board Page 50 Data / Parameter FCi,y Unit ton (liquid and solid fuels) / 103 m3 (gaseous fuels) Description Amount of fuels consumed in thermal power plants in Turkey by fuel type i in year y for years in the 5-year period of [2007 – 2011]. Source of data Official data from TEIAS (Turkish Electricity Transmission Company), the responsible authority for the operation of Turkish National Grid. Value(s) applied See Section B.6.3 and/or Appendix 4 for details Choice of data or Measurement methods and procedures Official data. According to the regulations regarding the Turkish Statistical Institute, the state organization responsible for the statistical affairs in the Republic of Turkey, TEIAS is the official source of data for energy59,60. Purpose of data Calculation of baseline emissions. Additional comment - Data / Parameter NCVi,y Unit TJ/Gg, GJ/ton Description Net calorific value of fuel type i consumed by thermal power plants in year y in the 5-year period of [2007 – 2011] Source of data Official data from TEIAS (Turkish Electricity Transmission Company), the responsible authority for the operation of Turkish National Grid. Value(s) applied See Section B.6.3 and/or Appendix 4 for details Choice of data or Measurement methods and procedures Official data. According to the regulations regarding the Turkish Statistical Institute, the state organization responsible for the statistical affairs in the Republic of Turkey, TEIAS is the official source of data for energy59,60. The net calorific values are calculated using the amount of fuels used1 and the heating values of the fuels31. Purpose of data Calculation of baseline emissions. Additional comment In order for all the units of consumed fuels to be compatible with each other, the unit of natural gas consumed should be converted to mass units. Also, heating values given by TEIAS, which are expressed in [cal], must be converted into [J]. For this purpose, conversion factors given in International Energy Agency were used 33,34,35. Natural gas density was accepted as 0.692 kg/m3, and 1 cal was assumed to be equal to 4.1868 J. UNFCCC/CCNUCC CDM – Executive Board 61 Page 51 Data / Parameter EFCO2,i,y Unit kg/TJ Description Default CO2 emission factors of fossil fuel type i for combustion. Source of data IPCC default values at the lower limit of the uncertainty at a 95 per cent confidence interval as provided in table 1.4 of Chapter1 of Vol. 2 (Energy) of the 2006 IPCC Guidelines on National GHG Inventories, pages 1.23 – 1.2432. Value(s) applied See Section B.6.1, B.6.3 and/or Appendix 4 for details. Choice of data or Measurement methods and procedures Country or project specific data are not available for power plants using fossil fuels in Turkey. Hence, IPCC default emission factors have been used according to the Tool (Section 7, page 29) and the UNFCCC CDM “Guidance on IPCC Default Values”61. Purpose of data Calculation of baseline emissions. Additional comment - Data / Parameter ηi,y Unit Dimensionless (% ratio) Description Average net energy conversion efficiency of power units using fuel i in year y. Source of data For power plants using imported coal as fuel, the data given in presentation by Muzaffer Basaran in Panel about “Coal-Fired Power Plants and Investment Models”, in Middle East Technical University Alumni Association Visnelik Facility, on 23 February 201357 were used. For other types of fuels, the values in Table 1 in Appendix 1 of the Tool were applied. Value(s) applied See Section B.6.1, B.6.3 and/or Appendix 4 for details. Choice of data or Measurement methods and procedures Power plant and/or fuel type specific of net energy conversion efficiencies are impossible or very hard to find. Hence, the data available for imported coal using power plants from a panel conducted at the alumni association of a technical university (Middle East Technical University) were used. For the other fuel types, default efficiency factors for power plants in Appendix 1 of the Tool were selected taking the conservativeness rule into account. Purpose of data Calculation of baseline emissions. Additional comment - http://cdm.unfccc.int/Reference/Guidclarif/meth/meth_guid16_v01.pdf UNFCCC/CCNUCC CDM – Executive Board Page 52 Data / Parameter CAPBM Unit Power Plant Name, Installed Capacity [MW], Electricity Generation [GWh], Commissioning Date [YYYY-MM-DD] Description Capacity additions forming the sample group of power units used to calculate the build margin. Source of data TEIAS (Turkish Electricity Transmission Company) Capacity Projection Reports and Ministry of Energy and Natural Resources of Republic of Turkey Energy Investment Data50,51. Operational power plants at the end of 2011 were selected as the reference group 21. Value(s) applied See Section B.6.3 and Appendix 4. Choice of data or Measurement methods and procedures Annual electricity generation of the project electricity system AEGtotal was determined excluding power units registered as CDM project activities and capacity additions from retrofits of power plants. Since generation data for individual power plants are not available, but firm generation capacities of individual power plants are available, firm generation capacities were used as the actual generations21. Every single commissioning of each power plant is assumed as a power unit. These power units are sorted by date from the newest to the oldest. The newest 5 power units, SET5-units, their electricity generation AEGSET-5-units, and the group of power units that started to supply electricity to the grid most recently and that comprise 20 per cent of AEGtotal, SET20 per cent, and their electricity generation AEGSET-20 per cent were identified. Purpose of data Calculation of baseline emissions. Additional comment - B.6.3. Ex ante calculation of emission reductions a) Operating Margin Emission Factor Calculation: The calculation was performed according to the Option B of the Simple OM method of the Tool. Only grid connected power plants were included in the project electricity system. Ex-ante option was chosen, and a 3-year generation-weighted average, based on the most recent data available at the time of submission, was taken. The relevant reference period corresponds to the 3 year period of [2009 – 2011]. The gross electricity generations of these years by primary energy sources are as follows 62,63,64: 62 http://www.teias.gov.tr/TürkiyeElektrikİstatistikleri/istatistik2011/uretim%20tuketim(22-45)/44.xls http://www.teias.gov.tr/TürkiyeElektrikİstatistikleri/istatistik2010/front%20page%202010-çiçek%20kitap/uretim%20tuketim(2245)/44.xls 64 http://www.teias.gov.tr/TürkiyeElektrikİstatistikleri/istatistik2009/41.xls 63 UNFCCC/CCNUCC CDM – Executive Board Page 53 Table 25. Gross Electricity Generations of Turkish Electricity System by Primary Energy Sources in Years [2009 – 2011] Gross Generations by Fuel Types and Primary Energy Resources in [2009 - 2011] (Unit: GWh) Primary Energy Resource or Fuel Type Hard Coal + Imported Coal + Asphaltite Lignite Total Coal Fuel-Oil Diesel Oil LPG Naphtha Total Oil (Liquid Total) Natural Gas Renewables and Wastes Thermal Hydro + Geothermal + Wind Total Hydro Geothermal + Wind Geothermal Wind General Total (Gross) Years 2009 2010 2011 16,595.6 19,104.3 27,347.5 39,089.5 35,942.1 38,870.4 55,685.1 55,046.4 66,217.9 4,439.8 2,143.8 900.5 345.8 4.3 3.1 0.4 0.0 0.0 17.6 31.9 0.0 4,803.5 2,180.0 903.6 96,094.7 98,143.7 104,047.6 340.1 457.5 469.2 156,923.4 155,827.6 171,638.3 37,889.5 55,380.1 57,756.8 35,958.4 51,795.5 52,338.6 1,931.1 3,584.6 5,418.2 435.7 668.2 694.3 1,495.4 2,916.4 4,723.9 194,812.9 211,207.7 229,395.1 3-Year Total 63,047.4 113,901.9 176,949.3 7,484.1 353.2 0.4 49.5 7,887.2 298,286.0 1,266.9 484,389.4 151,026.4 140,092.5 10,933.9 1,798.3 9,135.6 635,415.7 Net electricity generation is only available for the whole project electricity system, not for each fuel type or primary energy source47: Table 26. Gross and Net Electricity Generations of Turkish Electricity System in Years [2009 – 2011] Gross and Net Generations in [2009 - 2011] (Unit: GWh) Primary Energy Resource or Fuel Type General Total (Gross) General Total (Net) Net / Gross Ratio Years 2009 2010 2011 194,812.9 211,207.7 229,395.1 186,619.3 203,046.1 217,557.7 95.79% 96.14% 94.84% 3-Year Total 635,415.7 607,223.1 95.56% The corresponding net/gross ratio of each year was applied to gross generations of each primary energy source to find the net generation of group of power plants utilizing that primary energy source, with low-cost/must-run power plants excluded: Table 27. Net Electricity Generations of Turkish Electricity System by Primary Energy Sources, Excluding Low-Cost/Must-Run Power Plants, (Thermal Power Plants) in Years [2009 – 2011] Net Electricity Generation Excluding Low-Cost/Must-Run (Thermal Power Plants) (Unit: GWh) Years 2009 2010 2011 3-Year Total UNFCCC/CCNUCC CDM – Executive Board Hard Coal+Imported Coal+Asphaltite Lignite Fuel Oil Diesel oil LPG Naphtha Natural Gas Renewables and Wastes Turkey's Thermal Total Page 54 15,897.6 37,445.4 4,253.0 331.3 0.4 16.8 92,053.1 325.8 150,323.4 18,366.0 34,553.2 2,061.0 4.1 0.0 30.7 94,351.2 439.8 149,806.0 25,936.3 36,864.6 854.0 2.9 0.0 0.0 98,678.5 445.0 162,781.3 60,199.9 108,863.2 7,168.1 338.3 0.4 47.5 285,082.7 1,210.7 462,910.7 Fuel consumptions of thermal power plants were also taken from TEIAS statistics 1. The amount of natural gas was converted from volume to mass units using the density value of 0.692 kg/m 3, as explained in section B.6.1. Table 28. Fuel Consumption of Thermal Power Plants by Fuel Type, in Years [2009 – 2011] Fuel Consumption in Electricity Generation Excluding Low-Cost/MustRun (Unit: Ton) Hard Coal+Imported Coal+Asphaltite Lignite Fuel Oil Diesel oil LPG Naphtha Natural Gas Turkey's Thermal Total Years 3-Year Total 2009 6,621,177.0 63,620,518.0 1,594,321.0 180,857.0 111.0 8,077.0 14,515,664.6 86,540,725.6 2010 7,419,703.0 56,689,392.0 891,782.0 20,354.0 0.0 13,140.0 15,072,939.7 80,107,310.7 2011 10,574,434.0 61,507,310.0 531,608.0 15,047.0 0.0 0.0 15,779,535.9 88,407,934.9 24,615,314.0 181,817,220.0 3,017,711.0 216,258.0 111.0 21,217.0 45,368,140.2 255,055,971.2 Heating values of fuels consumed in power plants were also taken from the TEIAS statistics 31. These values were in [Tcal] units, and were converted into [TJ], using the ratio 1 cal = 4.1868 J, given by IEA33,34,35. Table 29. Heating Values of Fuels Consumed in Thermal Power Plants in Turkey, in Years [2009 – 2011] Heating Values of Fuels Consumed in Thermal Power Plants (Unit: TJ) Hard Coal+Imported Coal+Asphaltite Lignite Fuel Oil Diesel oil LPG Naphtha Natural Gas Turkey's Thermal Total Years 2009 147,081.2 408,847.5 63,471.5 7,662.8 5.2 352.5 779,857.7 1,407,278.4 2010 165,573.3 404,239.7 35,877.2 877.1 0.0 440.2 814,279.2 1,421,286.7 The corresponding net calorific values (NCV) were found as follows: 2011 241,022.6 448,864.9 22,105.8 649.3 0.0 0.0 846,002.0 1,558,644.5 3-Year Total 553,677.2 1,261,952.1 121,454.5 9,189.1 5.2 792.7 2,440,138.9 4,387,209.6 UNFCCC/CCNUCC CDM – Executive Board Page 55 Table 30. Net Calorific Values of Fuels Consumed in Thermal Power Plants in Turkey, in Years [2009 – 2011] Net Calorific Values of Fuels Consumed in Thermal Power Plants (Unit: TJ/Gg) Years 2009 2010 22.2 6.4 39.8 42.4 46.5 43.6 53.7 16.3 Hard Coal+Imported Coal+Asphaltite Lignite Fuel Oil Diesel oil LPG Naphtha Natural Gas Turkey's Thermal Total 2011 22.3 7.1 40.2 43.1 0.0 33.5 54.0 17.7 22.8 7.3 41.6 43.2 0.0 0.0 53.6 17.6 Due to the absence of power-plant based or fuel based emission factor data, the lower limit of the 95 percent confidence intervals of IPCC default emission factor values were applied 32, and the emission factor for electricity imports were assumed as zero: Table 31. Emission Factors used in the Operating Margin Emission Factor Calculation. Table 1.4 Emission Factors by Fuel Type (IPCC Values) (kg/TJ) Default CO2 Emission Factors for Combustion (kg/TJ) Default Lower Upper 94,600 89,500 99,700 Lignite 101,000 90,900 115,000 Fuel Oil 77,400 75,500 78,800 Diesel oil 74,100 72,600 74,800 LPG 63,100 61,600 65,600 Naphtha 73,300 69,300 76,300 Natural Gas 56,100 54,300 58,300 0 0 0 Hard Coal+Imported Coal+Asphaltite Import The corresponding emissions and Operating Margin Emission Factors were calculated using the above values: Table 32. Operating Margin Emission Factor Calculation. UNFCCC/CCNUCC CDM – Executive Board Page 56 Operating Margin Emission Factor Calculation CO2 Emissions (ton) Hard Coal+Imported Coal+Asphaltite Lignite Fuel Oil Diesel oil LPG Naphtha Natural Gas Import Total Emission [ton] Total Net Electricity Generation, excluding low-cost/must-run [GWh] Yearly Emission Factor [tCO2/MWh] 2009-2011 Total Emissions [ton] 2009-2011 Total Net Electricity Gen. [GWh] 2009-2011 OMEF Calculation [tCO2/MWh] 2009 13,163,770.74 37,164,240.90 4,792,096.57 556,318.57 317.74 24,429.94 42,346,272.06 0.00 98,047,446.52 Years 2010 14,818,807.99 36,745,389.26 2,708,730.18 63,674.50 0.00 30,502.68 44,215,362.69 0.00 98,582,467.30 2011 21,571,526.82 40,801,815.79 1,668,984.86 47,138.38 0.00 0.00 45,937,907.18 0.00 110,027,373.03 149,997.58 149,366.19 162,336.32 0.654 0.660 0.678 306,657,286.85 461,700.1 0.664 As a result, the Operating Margin Emission Factor for the selected period was found to be EFgrid,OM, simple = 0.664 tCO2/MWh. b) Build Margin Emission Factor Calculation: Option 1, ex ante based build margin emission factor calculation, was selected. Capacity additions from retrofits of power plants that could be identified are as follows: Table 33. Capacity additions from retrofits of power plants that could be identified in commissioned power units. Capacity Additions from Retrofit of Power Plants (As at the end 2011) Fuel / No Energy Source 1 2 3 4 5 6 7 8 NG NG NG NG NG NG NG NG POWER PLANT NAME AKBAŞLAR AMYLUM NİŞASTA (Adana) DENİZLİ ÇİMENTO ISPARTA MENSUCAT PAKGIDA (Düzce-Köseköy) PAKMAYA (Köseköy) PAKMAYA (Köseköy) KAREGE ARGES Installed Capacity MW 3.960 6.200 14.000 4.300 4.800 4.800 2.100 26.280 Firm Generation Capacity (year 2012) GWh 30.06 34.69 113.00 33.00 38.26 38.26 16.74 209.09 Commissioning Date Location (Province) 2003-09-13 Bursa Adana 2006-05-04 Denizli Isparta Duzce Kocaeli 2003-07-02 Kocaeli 2003-07-30 Izmir GENERAL TOTAL 66.4 513.1 Abbreviations: FS: Fuel Switch, NG: Natural Gas, FO: Fuel Oil, LPG: Liquefied Petroleum Gas Retrofit Type FS from FO to NG FS from FO to NG FS from FO to NG FS from FO to NG FS from LPG to NG FS from LPG to NG FS from LPG to NG FS from FO to NG UNFCCC/CCNUCC CDM – Executive Board Page 57 CDM project activities are identified as follows21,52,53,54,55: Table 34. CDM VER Projects in Turkey as at the end of 2011 No Fuel / Energy Source Power Plant Name Installed Capacity (MW) Location (Province) Commissioning Date (First) Standard Code / Number / Project ID 1 WS ITC-KA ENERJİ MAMAK 25.4 Ankara 2011-10-14 GS GS440 2 WS ITC-KA ENERJİ SİNCAN 5.7 Ankara 2011-04-08 GS GS675 3 WS ITC-KA ENERJİ KONYA (ASLIM BİYOKÜTLE) 5.7 Konya 2011-10-21 GS GS1016 4 WS ITC-KA ENERJİ ADANA (BİYOKÜTLE) 11.3 Adana 2011-10-06 GS GS715 5 WS ORTADOĞU ENERJİ (KÖMÜRCÜODA) 5.8 Istanbul 2009-07-15 GS GS707 6 WS BOLU BEL.ÇÖP (CEV MARMARA) 1.1 Bolu 2011-08-26 GS GS764 7 WS KAYSERİ KATI ATIK (HER EN.) 1.6 Kayseri 2011-11-01 GS GS1061 8 HE AKIM (CEVİZLİK HES) 91.4 Giresun 2010-05-28 VCS 753 9 HE ANADOLU ÇAKIRLAR 16.2 Artvin 2009-08-13 GS GS917 10 HE ASA EN.(KALE REG.) 9.6 Rize 2010-02-19 GS GS637 11 HE AYRANCILAR (MURADİYE ELEK.) 32.1 Van 2011-08-25 GS, VCS GS729, 577 12 HE CEYKAR BAĞIŞLI 29.6 Hakkari 2009-05-07 VCS 657 13 HE BEREKET (KOYULHİSAR) 42.0 Sivas 2009-06-12 VCS 713 14 HE BEYOBASI (SIRMA) 5.9 Aydin 2009-05-23 VCS 603 15 HE BEYTEK(ÇATALOLUK HES) 9.5 K.Maras 2010-04-07 GS GS872 16 HE BULAM 7.0 Adiyaman 2010-08-10 GS GS642 17 HE BURÇBENDİ (AKKUR EN.) 27.3 Adiyaman 2010-11-04 VCS 419 18 HE CEVHER (ÖZCEVHER) 16.4 Trabzon 2011-01-17 GS GS688 19 HE CEYHAN HES (BERKMAN HES-ENOVA) 25.2 Osmaniye 2010-08-28 VCS 810 20 HE CEYHAN HES (OŞKAN HES-ENOVA) 23.9 Osmaniye 2010-06-03 VCS 810 21 HE ÇAKIT HES 20.2 Adana 2010-06-01 VCS 685 22 HE ÇALDERE ELEKTRİK DALAMAN MUĞLA 8.7 Mugla 2008-04-02 VCS 363 23 HE ÇAMLICA 27.6 Kayseri 2011-04-01 VCS 759 24 HE DAMLAPINAR(CENAY ELEK.) 16.4 Karaman 2010-07-08 VER+ 25 HE DARCA HES (BÜKOR EL.) 2011-05-26 GS GS887 26 HE DEĞİRMENÜSTÜ (KAHRAMANMARAŞ) 38.6 K.Maras 2009-04-16 VCS 565 27 HE EGEMEN 1 HES (ENERSİS ELEK.) 19.9 Bursa 28 HE ELESTAŞ YAYLABEL 29 HE ELESTAŞ YAZI 30 HE ERİKLİ-AKOCAK REG.(AK EN.) 31 HE EŞEN-I (GÖLTAŞ) 32 HE 33 HE 34 HE GÜZELÇAY-I HES(İLK EN.) 35 HE HAMZALI HES (TURKON MNG ELEK.) 36 HE HASANLAR (DÜZCE) 37 HE HİDRO KONTROL (SELİMOĞLU HES) 38 HE KALE HES 39 HE KALEN ENER. (KALEN I-II) 8.9 Bilecik 2010-12-28 GS GS755 5.1 Isparta 2009-09-07 VCS 582 1.1 Cankiri 2009-10-02 VCS 583 82.5 Trabzon 2010-07-29 VCS 535 60.0 Mugla 2011-04-24 VER+ 97-1 FEKE 2 (AKKUR EN.) 69.3 Adana 2010-12-24 VCS 534 FİLYOS YALNIZCA HES 14.4 Karabük 2009-09-16 GS GS618 8.1 Sinop 2010-11-11 GS GS711 16.7 Kirikkale 2008-11-08 GS GS633 4.7 Duzce 2011-12-02 GS GS831 8.8 Trabzon 2010-01-07 GS GS635 34.1 K.Maras 2010-06-16 VCS 893 31.3 Giresun 2009-06-19 VCS 932 UNFCCC/CCNUCC CDM – Executive Board Page 58 40 HE KALKANDERE-YOKUŞLU HES(AKIM EN.) 41 HE KARASU I HES (İDEAL EN.) 37.9 Rize 2011-01-28 VCS 905 3.8 Erzurum 2011-05-19 GS GS927 42 HE 43 HE KARASU 4-2 HES (İDEAL EN.) 10.4 Erzincan 2011-11-24 GS GS928 KARASU 4-3 HES (İDEAL EN.) 4.6 Erzincan 2011-08-05 GS GS929 44 HE KARASU 5 HES (İDEAL EN.) 45 HE KAR-EN KARADENİZ ELEK.(ARALIK HES) 12.4 Artvin 4.1 Erzincan 2011-08-03 GS GS929 2010-04-30 GS 46 HE KAYABÜKÜ HES (ELİTE ELEK.) 14.6 Bolu GS663 2010-07-21 GS GS726 47 HE KIRAN HES (ARSAN EN.) 48 HE KOZDERE (ADO MAD.) 9.7 Giresun 2011-11-04 GS GS691 3.1 Antalya 2011-10-08 GS 49 HE KUMKÖY HES (KUMKÖY EN.) 17.5 Samsun 2011-02-23 VER+ G434 50 HE TGT EN. LAMAS III-IV 35.7 Mersin 2009-06-05 VCS 51 HE MARAŞ ENERJİ (FIRNIS) 52 HE MENGE (ENERJİ-SA) 44.7 Adana 2011-12-22 VCS 578 53 HE OTLUCA I HES (BEYOBASI) 37.5 Mersin 2011-04-07 VCS 755 54 HE OTLUCA II HES (BEYOBASI) 6.4 Mersin 2011-07-13 VCS 755 55 HE ÖZGÜR ELEKTR.AZMAK I 11.8 Mersin 2010-07-10 VCS 554 56 HE ÖZGÜR ELEKTR.AZMAK II 6.3 Mersin 2010-07-11 VCS 554 57 HE ÖZTAY GÜNAYŞE 8.3 Trabzon 2009-08-13 GS GS636 58 HE PAŞA HES(ÖZGÜR EL.) 8.7 Bolu 2010-06-11 GS GS681 59 HE REŞADİYE I HES(TURKON MNG EL. 15.7 Sivas 2010-11-26 GS GS643 60 HE REŞADİYE II HES(TURKON MNG EL. 26.1 Tokat 2010-09-17 GS GS644 61 HE REŞADİYE III HES(TURKON MNG EL. 22.3 Tokat 2009-11-11 GS GS645 62 HE SARAÇBENDİ (ÇAMLICA) 25.5 Sivas 2011-05-06 VCS 758 63 HE SAYAN (KAREL) 14.9 Osmaniye 2011-11-19 GS GS730 64 HE SEFAKÖY (PURE) 33.1 Kars 2011-10-12 VCS 747 65 HE SELEN EL.(KEPEZKAYA HES) 28.0 Karaman 2010-09-06 VER+ 66 HE SÖĞÜTLÜKAYA (POSOF HES) YENİGÜN EN. 67 HE TEKTUĞ-KARGILIK 68 HE TEKTUĞ-KALEALTI HES 69 HE TEKTUĞ-KEBENDERESİ 70 HE TEKTUĞ-ERKENEK 71 HE YAMAÇ HES (YAMAÇ ENERJİ ÜRETİM A.Ş.) 72 HE YEŞİLBAŞ 73 HE YAPISAN KARICA DARICA 74 HE 75 76 7.2 K.Maras 6.1 Ardahan 726 2008-06-05 VER+ 2011-01-20 GS GS891 23.9 K.Maras 2005-04-24 VCS 264 15.0 Osmaniye 2006-11-30 VCS 111 2007-05-09 VCS 598 2009-11-10 VCS 693 2011-07-20 GS GS926 5.0 Elazig 13.0 Adiyaman 5.5 Osmaniye 14.0 Sivas 2009-12-04 VCS 806 110.3 Ordu 2011-07-26 VCS 506 YPM ALTINTEPE SUŞEHRİ HES 4.0 Sivas 2007-06-07 VCS 914 HE YPM BEYPINAR HES 3.6 Sivas 2007-06-07 VCS 914 HE YPM KONAK HES (SUŞEHRİ/SİVAS) 4.0 Sivas 2007-07-20 VCS 914 77 HE YPM GÖLOVA 1.1 Sivas 2009-06-10 VCS 914 78 HE YPM SEVİNDİK 5.7 Sivas 2009-06-09 VCS 914 79 HE ULUBAT KUVVET TÜN.(AK EN.) 100.0 Bursa 2010-10-22 VCS 536 80 WD ALİZE ENERJİ (ÇAMSEKİ) 20.8 Canakkale 2009-06-24 GS GS399 81 WD ALİZE ENERJİ (KELTEPE) 20.7 Balikesir 2010-04-28 GS GS437 82 WD ALİZE ENERJİ (SARIKAYA ŞARKÖY) 28.8 Tekirdag 2009-10-19 GS GS577 83 WD AK ENERJİ AYYILDIZ (BANDIRMA) 15.0 Balikesir 2009-07-23 GS GS634 84 WD AKDENİZ ELEK. MERSİN RES 33.0 Mersin 2010-03-19 GS GS753 85 WD AKRES (AKHİSAR RÜZGAR) 43.8 Manisa 2011-09-23 GS GS955 86 WD ANEMON ENERJİ (İNTEPE) 30.4 Canakkale 2007-11-22 GS GS347 87 WD ASMAKİNSAN (BANDIRMA-3 RES) 24.0 Balikesir 2010-03-26 GS GS683 UNFCCC/CCNUCC CDM – Executive Board 88 WD AYEN ENERJİ (AKBÜK) 89 WD AYVACIK (AYRES) 90 WD BAKRAS ELEK.ŞENBÜK RES Page 59 31.5 Aydin 2009-04-03 GS GS436 2011-10-23 GS GS956 15.0 Hatay 2010-04-22 GS GS733 GS1072, 52-1 5.0 Canakkale 91 WD BARES (BANDIRMA) 30.0 Balikesir GS, 2011-08-11 VER+ 92 WD BELEN HATAY 36.0 Hatay 2010-09-02 GS GS390 93 WD BERGAMA RES (ALİAĞA RES) 90.0 Izmir 2010-06-16 GS GS735 94 WD BORASKO BANDIRMA 60.0 Balikesir 2010-06-30 GS GS744 95 WD BOREAS EN.(ENEZ RES) 15.0 Edirne 2010-04-09 GS GS702 96 WD ÇANAKKALE RES (ENERJİ-SA) 29.9 Canakkale 2011-05-06 GS GS906 97 WD ÇATALTEPE (ALİZE EN.) 16.0 Balikesir 2011-04-19 GS GS574 98 WD DOĞAL ENERJİ (BURGAZ) 14.9 Canakkale 2008-05-08 GS GS439 66 99 WD DENİZLİ ELEKT. (Karakurt-Akhisar) 10.8 Manisa VCS, 2007-05-28 VER+ 100 WD MARE MANASTIR 39.2 Izmir 2007-04-13 GS GS368 101 WD MAZI 3 30.0 Izmir 2010-06-18 GS GS388 102 WD KİLLİK RES (PEM EN.) 40.0 Tokat 2011-12-17 GS GS947 103 WD KORES KOCADAĞ 15.0 Izmir 2009-12-23 GS GS601 104 WD KUYUCAK (ALİZE ENER.) 25.6 Manisa 2010-12-09 GS GS576 105 WD ROTOR (OSMANİYE RES-GÖKÇEDAĞ RES) 135.0 Osmaniye 2010-10-15 GS GS474 106 WD BAKİ ELEKTRİK ŞAMLI RÜZGAR 114.0 Balikesir 2011-11-13 GS GS351 107 WD DATÇA RES 29.6 Mugla 2009-12-24 GS GS438 108 WD ERTÜRK ELEKT. (ÇATALCA) 60.0 Istanbul 2008-12-27 GS GS367 109 WD İNNORES ELEK. YUNTDAĞ 52.5 Izmir 2011-09-27 GS GS352 110 WD LODOS RES (TAŞOLUK)KEMERBURGAZ 24.0 Istanbul 2008-08-20 GS GS503 111 WD SARES (GARET ENER.) 22.5 Canakkale 2011-03-10 GS GS963 112 WD SAYALAR RÜZGAR (DOĞAL ENERJİ) 34.2 Manisa 2009-09-06 GS GS369 30.0 Hatay VCS, 2010-03-12 VER+ 553 113 WD SEBENOBA (DENİZ ELEK.)SAMANDAĞ 114 WD SEYİTALİ RES (DORUK EN.) 115 WD SOMA RES 116 WD 117 WD 118 30.0 Izmir 2011-07-22 GS GS578 116.1 Manisa 2011-12-09 GS GS398 SOMA RES (BİLGİN ELEK.) 90.0 Manisa 2010-11-11 GS GS655 SUSURLUK (ALANTEK EN.) 45.0 Balikesir 2011-05-20 GS GS854 WD ŞAH RES (GALATA WIND) 93.0 Balikesir 2011-07-29 GS GS905 119 WD TURGUTTEPE RES (SABAŞ ELEK.) 24.0 Aydin 2011-03-04 GS GS610 120 WD ÜTOPYA ELEKTRİK 30.0 Izmir 2010-09-03 GS GS672 121 WD ZİYARET RES 57.5 Hatay 2011-11-24 GS GS617 122 GT MENDERES JEOTERMAL 8.0 Aydin 2006-05-10 VCS 120 123 GT MENDERES JEOTERMAL DORA-2 9.5 Aydin 2010-03-26 GS GS445 124 GT TUZLA JEO. 7.5 Canakkale 2010-01-13 GS GS353 AYDIN GERMENCİK JEO.(MAREN 125 GT 20.0 Aydin 2011-11-11 GS GS861 MARAŞ) Abbreviations: WD: Wind, HE: Hydroelectric, WS: Waste, GT: Geothermal, GS: Gold Standard, VCS: Verified Carbon Standard The remaining power units constitute the sample group used to calculate the build margin emission calculation. There are 639 power units in this group. Complete list of this sample group is in the Appendix 4 of this report. These power units in the sample group were sorted by date from the newest to the oldest. The newest 5 power units, SET5-units, were identified as follows: UNFCCC/CCNUCC CDM – Executive Board Page 60 Table 35. The set of five power units, excluding power units registered as CDM project activities, that started to supply electricity to the grid most recently (SET5-units) Fuel / No Energy Source 1 NG 2 NG 3 NG 4 IC 5 HE POWER PLANT NAME TİRENDA TİRE AKSA AKRİLİK KİMYA (İTH.KÖM.+D.G) ALİAĞA Çakmaktepe Enerji BEKİRLİ TES (İÇDAŞ ELEKT.) SARIKAVAK (ESER) Firm Generatio Installed n Capacity Capacit (year y (MW) 2012) (GWh) 58.400 410.0 25.000 175.0 8.730 600.000 8.100 65.7 4,320.0 24.0 Commissionin Location g Date (Province) 2011-12-30 Izmir 2011-12-30 Yalova 2011-12-29 Izmir 2011-12-15 Canakkale 2011-11-25 Mersin Total 700.2 4,994.7 AEGSET-5-units 4,994,736 MWh Abbreviations: NG: Natural Gas, IC: Imported Coal, HE: Hydroelectric Hence, electricity generation of SET5-units is found to be AEGSET-5-units = 4,994,736 MWh. The total generation of the sample group of power units used to calculate is AEGtotal = 256,636,382 MWh. 20 % of this value is AEGSET-=20 per cent = 51,327,276 MWh. When sorted from the newest to the oldest, the cumulative firm generation amount up to and including the 204th power unit in the list, Aksa Enerji (Antalya) Natural Gas Power Plant, with an installed capacity of 46,7 MW and firm generation capacity of 324.9 GWh, which was commissioned on 29/12/2008, gives us an firm generation amount of 51,589,558 MWh, and satisfies the condition of SET20 per cent. Hence electricity generation of SET20 per cent is found to be AEGSET-20 per cent = 51,589,558 MWh. Since AEGSET-20 per cent > AEGSET-5-units, and none of the power units in the SET20 per cent started to supply electricity to the grid more than 10 years ago, it was assumed that SETsample = SET20 per cent. The generation distribution of SETsample by primary energy sources is as follows: Table 36. The distribution of sample group used to calculate the build margin (SETsample) by primary energy sources (fuels consumed) Energy Source / Fuel Asphaltite Biogas Diesel Oil Fuel Oil Geothermal Hard Coal Hydroelectric Imported Coal Lignite Installed Capacity (MW) 135.0 0.5 0.0 142.3 47.4 0.0 1,866.2 2,230.0 24.4 Firm Generation Capacity (year 2012) (GWh) 945.0 3.7 0.0 967.8 313.0 0.0 3,384.5 15,323.3 147.0 UNFCCC/CCNUCC CDM – Executive Board Page 61 Liquefied Petroleum Gas Natural Gas Naphta Wind Waste 0.0 4,053.7 49.0 0.0 19.8 0.0 30,079.7 277.9 0.0 147.7 Total 8,568.3 51,589.6 These generation values were put into the formulation as explained in the section B.6.1., and the Build margin emission factor was calculated as shown in the following table: Table 37. Build Margin Emission Factor Calculation Energy Source / Fuel Firm Assumed Generation Emission Capacity Factor (year 2012) (kg/TJ) (GWh) Assumed Calculated Default Emission Efficiency Factor (%) ((tCO2/MWh) Emission (ton) 945.0 89,500 41.5% 0.776 733,684.3 Biogas 3.7 46,200 60.0% 0.277 1,025.6 Diesel Oil 0.0 72,600 46.0% 0.568 0.0 Fuel Oil 967.8 75,500 46.0% 0.591 571,857.5 Geothermal 313.0 0 0.0% 0.000 0.0 0.0 92,800 41.5% 0.805 0.0 Hydroelectric 3,384.5 0 0.0% 0.000 0.0 Imported Coal 15,323.3 89,500 40.9% 0.788 12,071,339.9 147.0 90,900 41.5% 0.789 115,913.9 0.0 61,600 60.0% 0.370 0.0 30,079.7 54,300 60.0% 0.326 9,799,962.8 277.9 69,300 60.0% 0.416 115,545.0 0.0 0 0.0% 0.000 0.0 147.7 73,300 41.5% 0.636 93,894.7 0.456 23,503,223.7 Asphaltite Hard Coal Lignite Liquefied Petroleum Gas Natural Gas Naphta Wind Waste Total / Overall 51,589.6 The calculated Build Margin Emission Factor is EFgrid,BM,y = 0.456 tCO2/MWh. c) Combined Margin Emission Factor Calculation: Combined Margin Emission Factor calculation was done according to the tool as explained the section B.6.1., by using Weighted Average CM method, with weightings wOM = 0.75 and wBM = 0.25, since the project activity is a wind farm: EFgrid ,CM , y EFgrid ,OM , y wOM EFgrid ,BM , y wBM Equation (14) EFgrid,CM,y = 0.664 * 0.75 + 0.456 * 0.25 = 0.612 UNFCCC/CCNUCC CDM – Executive Board Page 62 The Combined Margin Emission Factor is found to be EFgrid,CM,y = 0.612 tCO2/MWh. d) Emission Reduction Calculation: Emission reduction calculation for the first crediting period was done according to the Methodology, as indicated in section B.6.1., as follows: ERy = BEy – PEy – LEy Where: ERy BEy PEy LEy = = = = Emission reductions in year y (t CO2/yr) Baseline emissions in year y (t CO2/yr) Project emissions in year y (t CO2/yr) Leakage emissions year y (t CO2/yr) Since no leakage emissions are considered by the Methodology, and the project emissions are assumed as zero as explained in the section B.6.1., we found that the emission reductions is equal to the baseline emissions. ERy = BEy Baseline emissions are calculated using the formulation indicated on page 8 of the Methodology: “Baseline emissions Baseline emissions include only CO2 emissions from electricity generation in fossil fuel fired power plants that are displaced due to the project activity. The methodology assumes that all project electricity generation above baseline levels would have been generated by existing grid-connected power plants and the addition of new grid-connected power plants. The baseline emissions are to be calculated as follows: BE y EGPJ , y * EFgrid,CM , y (4) Where: BE y = Baseline emissions in year y (tCO2/yr) EGPJ , y = EFgrid ,CM , y = Quantity of net electricity generation that is produced and fed into the grid as a result of the implementation of the CDM project activity in year y (MWh/yr) Combined margin CO2 emission factor for grid connected power generation in year y calculated using the latest version of the “Tool to calculate the emission factor for an electricity system” (tCO2/MWh) “ Since the project activity is a greenfield renewable energy power plant, the net electricity generation of the project activity is calculated according to the rule explained on page 8 – 9 of the Methodology: “Calculation of EGPJ,y The calculation of EGPJ,y is different for: (a) greenfield plants, (b) retrofits and replacements; and (c) capacity additions. These cases are described next. UNFCCC/CCNUCC CDM – Executive Board Page 63 (a) Greenfield renewable energy power plants If the project activity is the installation of a new grid-connected renewable power plant/unit at a site where no renewable power plant was operated prior to the implementation of the project activity, then: (5) EG PJ,y EG facility, y Where: EG PJ,y = EG facility, y = Quantity of net electricity generation that is produced and fed into the grid as a result of the implementation of the CDM project activity in year y (MWh/yr) Quantity of net electricity generation supplied by the project plant/unit to the grid in year y (MWh/yr) “ The net annual electricity generation of the project is calculated as EGfacility,y = 194,003 MWh, as explained in section B.5. The details of this calculation are in both Emission Reduction Calculation and Investment Analysis spreadsheets as annexes to PDD. The baseline emission is found as: BEy = EGPJ,y * EFgrid,CM,y = 194,003 * 0.612 = 118,737 tCO2/yr. Hence, the emission reductions is ERy = 118,737 tCO2/yr. For the first year of the crediting period (2012), the net average electricity generation is found to be 145,546 MWh. Hence for 2012, the emission reductions is ER2012 = 89,079 tCO2. For the last year of the crediting period (2019), the net average electricity generation is found to be 39,864 MWh. Hence for 2019, the emission reductions is ER2019 = 24,398 tCO2. Total amount of emission reductions for the first crediting period is 825,899 tCO 2. Annual average over the first crediting period is calculated as 117,986 tCO2/yr. This value is lower than the estimated amount of annual average GHG emission reductions, due to the partial commissionings in the first year, causing a lower amount of net electricity generation than the other years. The details of the emission factor and emission reduction calculations can be found in the emission reduction calculation spreadsheet as an annex to PDD. UNFCCC/CCNUCC CDM – Executive Board B.6.4. Summary of ex ante estimates of emission reductions Baseline Project Year emissions emissions (t CO2e) (t CO2e) 2012 89,079 0 0 2013 118,737 0 0 2014 118,737 0 0 2015 118,737 0 0 2016 118,737 0 0 2017 118,737 0 0 2018 118,737 0 0 2019 24,398 0 0 Total 825,899 0 0 Total number of 7 years crediting years Annual 117,986 0 0 average over the crediting period Page 64 Leakage (t CO2e) Emission reductions (t CO2e) 89,079 118,737 118,737 118,737 118,737 118,737 118,737 24,398 825,899 117,986 UNFCCC/CCNUCC CDM – Executive Board Page 65 B.7. Monitoring plan B.7.1. Data and parameters to be monitored Data / Parameter Unit Description Source of data EGfacility,y MWh/yr Quantity of net electricity generation supplied by the project plant/unit to the grid in year y. Main source is the data from the web site of PMUM (Market Financial Settlement Centre) or EPIAS (Energy Markets Operation Company, which will replace PMUM according to the new Electricity Market Law in Turkey)65 or any other equivalent state authority responsible for the operation of national electricity market in Turkey, in case it is enforced by the law before the end of the first crediting period. These data is based on the automatic meter reading from the electricity meters of the project activity, which is performed by TEIAS. This will be the preferred data. Auxiliary sources will be the monthly electricity protocols signed by TEIAS officials or electricity sales invoices. These will be used as confirmative and supportive documents, if necessary. Value(s) applied 194,003 MWh/yr Measurement methods There are two groups of electricity meters for two groups of turbines, as and procedures indicated in the Section B.3 about the project boundary. Each group of electricity meters consists of a main meter and a backup meter. The amount of net electricity generation supplied by the project to the grid will be calculated by subtracting the amount of electricity drawn from the grid from the amount fed into the grid for each main electricity meter, and then adding net electricity generation amount for two main meters. 65 http://www.resmigazete.gov.tr/eskiler/2013/03/20130330-14.htm UNFCCC/CCNUCC CDM – Executive Board Monitoring frequency QA/QC procedures Page 66 Unless otherwise enforced by the law, or stated in the monitoring reports, the monitoring will be done on a monthly basis. TEIAS is responsible for the electricity meter measurements and testing and control of electricity meters according to “Communiqué on Meters to be used in the Electricity Market”66, and other related legislation. TEIAS performs annual periodic tests on every electricity meter, and the meters are sealed after each test, according to the System Usage Agreement made between the project proponent and TEIAS67. These seals can only be broken and re-sealed only by TEIAS authorised personnel. Apart from the annual tests, the companies producing or importing the electricity meters are required to guarantee the accuracy and calibration of the meters66. The data of PMUM (EPIAS, etc.) uses the electricity measurement data of TEIAS. This data is reliable since it is only accessible to project owner apart from PMUM (EPIAS, etc.), and used for invoicing purposes. Purpose of data Additional comment The data of the SCADA system installed within the project activity can also be used to cross-check the measurements of the electricity meters. Calculation of baseline emissions The electricity measurements are used for billing and strictly checked by project owner and TEIAS. Also, according to the Section III about Monitoring Methodology of “ACM0002: Consolidated baseline methodology for grid-connected electricity generation from renewable sources --- Version 13.0.0”, all data collected as part of monitoring will be archived electronically and be kept at least two years after the end of the last crediting period. B.7.2. Sampling plan There will be no sampling procedures and all the data related with the electricity measurements will be used for monitoring purposes. B.7.3. Other elements of monitoring plan Operational and Management Structure Monitoring will be done according to “ACM0002: Consolidated baseline methodology for gridconnected electricity generation from renewable sources --- Version 13.0.0”. Electricity meters are located at the points indicated in the figure regarding the project boundary and simplified one-line single diagram of the project activity in the Section B.3 about the project boundary. At the end of each month, the data about the electricity measurements from PMUM (EPIAS, etc.) will be collected from the official web site after it has become definite. This data will be copied to spreadsheets 66 http://www.epdk.org.tr/documents/elektrik/mevzuat/teblig/elektrik/sayaclar_hakkinda/Elk_Tblg_Sayaclar.doc http://eud.teias.gov.tr/SKAM/SKAornek.pdf 67 UNFCCC/CCNUCC CDM – Executive Board Page 67 to make the calculations easier. The web pages containing the relevant data will be saved as screenshot s and/or in suitable file formats and be kept for future reference. The monthly electricity meter reading protocols signed by authorised TEIAS officials will also be kept, if these are available. This will be done monthly. The expected verification period is one year. At the end of each verification period, all the documents collected monthly will be compiled and an emission reduction calculation spreadsheet will be prepared to show the final results of the emission reductions of the corresponding verification period. This spreadsheet and documents about electricity generation and the electricity meter readings will be sent to verifying DOE along with the monitoring report of the corresponding verification period. Responsibilities and Institutional Arrangements for Data Collection and Archiving Data collection and archiving will be under the responsibility of the project proponent. Power plant personnel will send the monthly electricity meter reading protocols and other relevant supportive documents, if any, to project proponent company headquarters. Power plant personnel will also give support and help during the site visits of validation, verification and other similar related processes. The data collection, archiving and communication with the DOEs will be done by the responsible personnel in the project proponent company headquarters. SECTION C. Duration and crediting period C.1. Duration of project activity C.1.1. Start date of project activity According to the “Glossary of CDM terms”68 the start date of a project activity is defined as follows: “In the context of a CDM project activity or CPA, the earliest date at which either the implementation or construction or real action of a CDM project activity or CPA begins. In the context of a CDM PoA, the date on which the coordinating/managing entity officially notifies the secretariat and the DNA of their intention to seek the CDM status or the date of publication of the PoA-DD for global stakeholder consultation in accordance with the relevant CDM rules and requirements. “ Along with this explanation, the start date of the construction the date at which the building site was handed over to the contractor company, was assumed as the start date of the project activity. Therefore, the start date of the project activity is 19/07/2011. C.1.2. Expected operational lifetime of project activity 20 years C.2. Crediting period of project activity C.2.1. Type of crediting period Renewable, first crediting period. C.2.2. Start date of crediting period 16/03/2012 68 http://cdm.unfccc.int/Reference/Guidclarif/glos_CDM.pdf UNFCCC/CCNUCC CDM – Executive Board Page 68 C.2.3. Length of crediting period 7 years, 0 months. SECTION D. Environmental impacts D.1. Analysis of environmental impacts According to the “Environmental Impact Assessment Regulation”69 the project activity is exempt from the environmental impact assessment. This is also certified by the exemption decisions granted by the responsible state authorities70. However, considering that an environmental impact assessment study will ease the credit and emission reduction related affairs, the project proponent had an accredited consultant company prepare an environmental study. As a result, two environmental impact assessment reports, one for the project site, and one for the energy transmission line, have been prepared71. According to these reports, the project is found to be compatible with regulations related with the environmental impact assessment, and no harmful effects to the environment could be found. The details are in the referred EIA reports. D.2. Environmental impact assessment No environmental impact assessment is required. In addition, the results of the voluntary environmental impact assessment study indicate that the project activity has minimal, if any, effects on the environment. Further information regarding various aspects of environmental impact assessment study can be found in the EIA reports. SECTION E. Local stakeholder consultation E.1. Solicitation of comments from local stakeholders Since the project activity is intended to be developed as a Gold Standard project, a thorough and detailed local stakeholder consultation process has been conducted. A Local Stakeholder Consultation meeting was held on 16/06/2011 in Yahyalı district of Kayseri province, after a comprehensive invitation process. Detailed information can be found in the Local Stakeholder Consultation Report and the Gold Standard Passport of the project. E.2. Summary of comments received In general, the comments were positive. No significant concerns about the probable negative effects of the project were raised during the meeting. Detailed information can be found in the Local Stakeholder Consultation Report and the Gold Standard Passport of the project. E.3. Report on consideration of comments received Please refer to Local Stakeholder Consultation Report and the Gold Standard Passport of the project for detailed information about this issue. 69 http://mevzuat.basbakanlik.gov.tr/Metin.Aspx?MevzuatKod=7.5.12256&sourceXmlSearch=&MevzuatIliski=0 These decisions have been uploaded to the registry site and are available for the DOE. There are three decisions; two for the project site (a main and a revised one), and one for the energy transmission line. 71 Both of these two EIA reports have been uploaded to the registry site and are available for the DOE. 70 UNFCCC/CCNUCC CDM – Executive Board Page 69 SECTION F. Approval and authorization Not available. ----- UNFCCC/CCNUCC CDM – Executive Board Page 70 Appendix 1: Contact information of project participants Organization name Street/P.O. Box Building City State/Region Postcode Country Telephone Fax E-mail Website Contact person Title Salutation Last name Middle name First name Department Mobile Direct fax Direct tel. Personal e-mail Aksu Temiz Enerji Elektrik Uretim Sanayi ve Ticaret A.S. Hulya Sokak No: 37, G.O.P. Ankara 06700 Turkey +90 312 445 04 64 +90 312 445 05 02 ayen@ayen.com.tr http://www.ayen.com.tr Hakan Demir Mr. Demir Hakan +90 312 445 04 64 Extension: 306 hakand@ayen.com.tr Appendix 2: Affirmation regarding public funding The project does not obtain any public funding. Appendix 3: Applicability of selected methodology Not available. UNFCCC/CCNUCC CDM – Executive Board Page 71 Appendix 4: Further background information on ex ante calculation of emission reductions Power Plants Used to Calculate the Build Margin Emission Reduction Sorted by Commissioning Date from the Newest to the Oldest (The System at the End of 2011 with CDM-VER Projects and Capacity Additions from Retrofits of Power Plants Removed) No Fuel / Energy POWER PLANT NAME Source Installed Capacity (MW) Firm Generation Capacity (year 2012) (GWh) Commissioning Date Location (Province) 1 NG TİRENDA TİRE 58.400 410.0 2011-12-30 Izmir 2 NG AKSA AKRİLİK KİMYA (İTH.KÖM.+D.G) 25.000 175.0 3 NG ALİAĞA Çakmaktepe Enerji 8.730 65.7 2011-12-30 Yalova 2011-12-29 Izmir 4 IC BEKİRLİ TES (İÇDAŞ ELEKT.) 600.000 4,320.0 5 HE SARIKAVAK (ESER) 8.100 24.0 6 FO MARDİN-KIZILTEPE(AKSA EN.) 32.100 225.0 7 HE ÇUKURÇAYI HES (AYDEMİR) 1.800 4.0 8 NG ODAŞ DOĞAL GAZ 55.000 415.0 MURATLI HES (ARMAHES ELEK.) 26.700 55.0 21.0 9 HE 10 NG TEKİRDAĞ TEKS.(NİL ÖRME) 2.700 11 NG SARAY HALI A.Ş. 4.300 33.0 12 HE TEFEN HES (AKSU) 11.000 26.7 13 HE YEDİGÖL REG. VE HES (YEDİGÖL HES) 21.900 42.0 14 NG AKSA ENERJİ (Antalya) 190.000 1,321.7 15 NG GOREN-1 (GAZİANTEP ORG.SAN.) 48.700 277.0 16 HE ÇANAKÇI HES (CAN EN.) 4.633 11.0 17 NG AKSA ENERJİ (Antalya) 110.000 765.2 18 HE BOĞUNTU (BEYOBASI EN.ÜR.) 3.800 10.0 19 HE POYRAZ HES(YEŞİL EN.) 20 NG BOSEN (Bursa San.) 21 HE 22 23 24 2.700 6.0 93.000 698.0 ÇANAKÇI HES (CAN EN.) 4.633 11.0 WS CEV EN.(GAZİANTEP ÇÖP) 4.524 29.6 HE ÇAMLIKAYA 2.824 3.7 NG GORDİON AVM (REDEVCO ÜÇ ) 2.000 15.0 25 HE BALKONDU I HES (BTA ELEK.) 9.200 20.0 26 HE KORUKÖY HES (AKAR EN.) 3.000 13.0 27 NG LOKMAN HEKİM ENGÜRÜ(SİNCAN) 28 NG ŞANLIURFA OSB (RASA EN.) 29 NG HASIRCI TEKSTİL TİC. VE SAN. 30 NG KNAUF İNŞ. VE YAPI ELEMANLARI 31 NG MANİSA O.S.B. 32 HE TUZTAŞI HES (GÜRÜZ ELEK. ÜR. LTD.ŞTİ.) 33 NG ALİAĞA Çakmaktepe Enerji 34 HE 35 HE 36 2011-12-15 Canakkale 2011-11-25 2011-11-18 2011-11-03 2011-10-28 2011-10-27 2011-10-25 2011-10-15 2011-10-13 2011-10-13 2011-10-07 2011-09-30 2011-09-29 Mersin Mardin Isparta Sanliurfa Sivas Tekirdag Kayseri Zonguldak Erzurum Antalya Gaziantep Trabzon 2011-09-17 Antalya 2011-09-16 Mersin 2011-09-16 K.Maras 2011-09-10 2011-08-25 2011-08-24 2011-08-11 2011-08-05 Bursa Trabzon Trabzon Gaziantep Trabzon Ankara 1.600 12.0 43.500 347.8 1.600 6.0 130.950 986.0 KÖYOBASI HES (ŞİRİKOĞLU ELEK.) YAŞIL HES (YAŞIL ENERJİ EL. ÜRETİM A.Ş.) 1.100 3.0 2011-08-05 2011-08-05 2011-07-29 2011-07-26 2011-07-16 2011-07-15 2011-07-13 2011-07-04 2011-07-01 2011-06-30 2.276 4.8 2011-06-29 K.Maras NG POLYPLEX EUROPA 3.904 30.7 37 HE ÜZÜMLÜ HES (AKGÜN EN. ÜR. VE TİC. A.Ş.) 11.400 23.0 38 NG ALDAŞ ALTYAPI YÖN. 2.000 15.0 39 HE GÖKMEN REG. (SU-GÜCÜ ELEK.) 2.900 8.0 0.500 4.0 116.800 800.0 2.000 15.0 2011-06-24 2011-06-23 2011-06-15 2011-06-15 Adiyaman Ankara Sanliurfa Gaziantep Ankara Manisa Sivas Izmir K.Maras Tekirdag Erzincan Antalya Yozgat UNFCCC/CCNUCC CDM – Executive Board Page 72 40 HE 41 HE KARASU II HES (İDEAL EN.) 42 HE ÖREN REG.(ÇELİKLER) 43 HE 44 HE 45 NG 46 HE 47 HE 48 HE KESME REG.(KIVANÇ EN.) 49 HE ALKUMRU BARAJI VE HES(LİMAK) 50 NG GLOBAL ENERJİ (PELİTLİK) 51 HE KAZANKAYA REG.İNCESU HES(AKSA) 52 HE YAPRAK II HES (NİSAN EL. ENERJİ) 53 NG CENGİZ ENERJİ (Tekkeköy/SAMSUN) 54 NG BOYTEKS TEKS. 55 HE 56 HE 57 HE ALKUMRU BARAJI VE HES(LİMAK) 58 NG 59 HE KULP I HES (YILDIZLAR EN.) 60 HE 61 HE 62 NG TÜPRAŞ (Orta Anadolu-Kırıkkale) 12.000 84.8 63 HE HACININOĞLU HES (ENERJİ-SA) 71.140 102.0 64 NG İSTANBUL SABİHA GÖKÇEN HAV. 4.000 32.0 65 NG HG ENERJİ 66 HE YEDİGÖZE HES 67 NG FRAPORT İÇ İÇTAŞ ANTALYA HAV. 68 HE BAYRAMHACILI (SENERJİ EN.) 69 HE 70 HE 71 NG INTERNATIONAL HOSPITAL (İstanbul) 72 NG RASA ENERJİ (VAN) 73 IC EREN ENERJİ ELEK.ÜR.A.Ş. 74 NG ALARKO ALTEK 75 NG POLYPLEX EUROPA 76 FO 77 HE 78 NG SÖNMEZ ELEKTRİK 79 HE 80 BG 81 NG 82 NG 83 TEFEN HES (AKSU) 22.000 53.3 3.100 8.0 6.600 16.0 25.200 71.0 1.518 3.2 ZORLU ENERJİ (B.Karıştıran) 7.200 54.1 KESME REG.(KIVANÇ EN.) 2.305 4.5 YAPRAK II HES (NİSAN EL. ENERJİ) 5.400 10.5 İNCİRLİ REG.(LASKAR EN.) YAŞIL HES (YAŞIL ENERJİ EL. ÜRETİM A.Ş.) 2.305 4.5 87.090 156.0 4.000 29.9 15.000 27.0 5.400 10.5 35.000 281.3 8.600 67.0 HACININOĞLU HES (ENERJİ-SA) 71.140 102.0 NARİNKALE HES (EBD EN.) 30.400 55.4 174.180 312.0 3.904 18.0 22.900 44.0 DURU 2 REG.(DURUCASU EL.) 4.500 13.0 ÇAKIRMAN (YUSAKA EN.) 7.000 15.0 GÜLLE ENTEGRE (Çorlu) 52.400 366.0 155.330 134.0 8.000 64.0 47.000 95.0 AKSU REG.(KALEN EN.) 5.200 12.0 ÇEŞMEBAŞI (GİMAK) 8.200 17.0 0.800 6.0 10.124 64.4 600.000 4,005.9 21.890 151.4 7.808 61.3 TÜPRAŞ (İzmit-Yarımca) 40.000 258.8 UMUT III HES(NİSAN EL.) 12.000 15.0 2.564 19.8 YEDİGÖZE HES 155.330 134.0 FRİTOLEY GIDA 0.330 2.5 ALİAĞA Çakmaktepe Enerji 69.840 525.9 MARMARA PAMUK 26.190 203.6 HE MURGUL BAKIR 19.602 31.5 84 HE KARADENİZ ELEK.(UZUNDERE I HES) 85 IC EREN ENERJİ ELEK.ÜR.A.Ş. 86 HE SABUNSUYU II HES (ANG EN.) 87 HE KAHTA I HES(ERDEMYILDIZ ELEK.) 88 NG ENERJİ-SA (Bandırma) 31.076 46.5 600.000 4,005.9 7.400 12.0 7.100 20.0 930.800 7,540.0 2011-06-10 2011-06-03 2011-05-26 2011-05-25 Zonguldak Erzurum Giresun Rize 2011-05-20 K.Maras 2011-05-14 2011-04-22 2011-04-22 2011-04-14 2011-04-12 2011-04-08 2011-04-08 2011-04-03 2011-03-30 2011-03-19 2011-03-17 2011-03-17 2011-03-10 2011-03-04 2011-03-04 2011-02-25 2011-02-19 2011-02-04 2011-02-03 2011-01-31 2011-01-27 2011-01-26 2011-01-24 2011-01-20 2011-01-12 2011-01-12 2010-12-31 2010-12-29 2010-12-29 2010-12-18 2010-12-16 2010-12-15 2010-12-13 Kirklareli 2010-12-07 2010-12-02 2010-11-26 2010-11-26 2010-11-25 2010-11-11 2010-11-07 2010-11-01 2010-10-28 2010-10-14 2010-10-07 Usak K.Maras Amasya K.Maras Siirt Tekirdag Çorum Amasya Samsun Kayseri K.Maras Kars Siirt Tekirdag Diyarbakir Amasya Erzincan Kirikkale K.Maras Istanbul Kutahya Adana Antalya Nevsehir Giresun Ankara Istanbul Van Zonguldak Kirklareli Tekirdag Kocaeli Ordu Adana Kocaeli Izmir Tekirdag Artvin Rize Zonguldak Osmaniye Adiyaman Balikesir UNFCCC/CCNUCC CDM – Executive Board Page 73 89 NG UĞUR ENERJİ (TEKİRDAĞ) 12.000 100.9 90 HE ERENKÖY REG.(TÜRKERLER) 21.500 49.0 91 HE KAHRAMAN REG.(KATIRCIOĞLU ELEK.) 1.400 3.0 92 HE NARİNKALE HES (EBD EN.) 3.100 5.6 93 FO KIRKA BORAKS (Kırka) 10.000 65.9 94 HE KOZAN HES (SER-ER EN.) 4.000 5.0 95 HE TEKTUĞ-ANDIRIN 40.500 60.0 96 HE KARŞIYAKA HES (AKUA EN.) 97 NG SÖNMEZ ELEKTRİK 98 HE GÜDÜL I (YAŞAM EN.) 99 NG KURTOĞLU BAKIR KURŞUN 100 NG CAN ENERJİ ELEK. ÜR.AŞ.(TEKİRDAĞ) 101 NG BİNATOM ELEKTRİK ÜRT. A.Ş. 102 NG KESKİNOĞLU TAVUKÇULUK 103 HE GÖK HES 104 NG CENGİZ ENERJİ (Tekkeköy/SAMSUN) 105 NG 1.600 5.0 33.242 256.2 2.400 8.0 1.600 12.0 29.100 203.0 2.000 13.0 3.500 25.0 10.000 24.0 101.950 819.4 RB KARESİ TEKS. (BURSA) 8.600 65.0 106 NG FLOKSER TEKSTİL (ÇERKEZKÖY) 5.200 42.0 107 IC EREN ENERJİ ELEK.ÜR.A.Ş. 160.000 1,068.2 22.500 47.0 6.200 13.0 108 HE YAVUZ HES (MASAT EN.) 109 HE KİRPİLİK HES (ÖZGÜR ELEK.) 110 NG ALARKO ALTEK 60.100 415.6 111 HE DİM HES (DİLER ELEK.) 38.300 70.0 112 HE DİNAR HES (ELDA ELEK.) 113 NG AKSA ENERJİ (Antalya) 114 HE ÇAMLIKAYA 115 NG 4.400 9.0 25.000 173.9 5.648 7.3 UĞUR ENERJİ (TEKİRDAĞ) 48.200 405.1 116 HE ERENLER REG.(BME BİRLEŞİK EN.) 45.000 48.0 117 HE KARADENİZ ELEK.(UZUNDERE I HES) 31.076 46.5 118 NG CENGİZ ENERJİ (Tekkeköy/SAMSUN) 101.950 819.4 78.400 473.3 119 NG ERDEMİR 120 HE BİRİM (ERFELEK HES) 3.225 5.5 277.9 92.7 121 NT ATAER ENERJİ (EBSO) 49.000 122 NG YILDIZ ENTEGRE 12.368 123 BG FRİTOLEY GIDA 0.065 0.5 21.600 39.0 NİSAN EN.(BAŞAK HES) 6.900 12.0 BİRİM (ERFELEK HES) 3.225 5.5 127 HE NURYOL EN.(DEFNE HES) 7.200 13.0 128 NG AKSA ENERJİ (Antalya) 25.000 173.9 129 HE DOĞUBAY ELEK.(SARIMEHMET HES) 3.100 6.0 26.190 166.6 124 HE FIRTINA ELEK.(SÜMER HES) 125 HE 126 HE 130 NG RASA ENERJİ (VAN) 131 WS ORTADOĞU ENERJİ (Oda yeri) 4.245 33.2 132 HE HETAŞ HACISALİHOĞLU (YILDIZLI HES) 1.200 3.0 133 HE PETA EN. (MURSAL II HES) 4.500 11.0 134 NG AKBAŞLAR 1.540 11.69 135 WS CEV EN.(GAZİANTEP ÇÖP) 1.131 7.4 136 HE ALAKIR (YURT EN.) 2.100 4.0 ALTINMARKA 4.600 35.9 CAN TEKSTİL (Çorlu) 7.832 60.1 137 NG 138 NG 2010-10-07 2010-10-07 2010-09-30 2010-09-30 2010-09-29 2010-09-21 2010-09-03 2010-08-28 2010-08-26 2010-08-25 2010-08-19 2010-08-19 2010-08-17 2010-08-11 2010-08-06 2010-07-31 2010-07-23 2010-07-17 2010-07-15 Tekirdag 2010-07-14 2010-07-11 2010-07-10 2010-07-08 Amasya Artvin Giresun Kars Eskisehir Adana K.Maras Gaziantep Usak Malatya Tekirdag Tekirdag Kutahya Manisa Mersin Samsun Bursa Tekirdag Zonguldak Mersin Kirklareli Antalya 2010-07-03 Tunceli 2010-07-01 2010-06-30 2010-06-21 2010-06-04 Antalya 2010-05-27 2010-05-22 2010-05-21 2010-05-14 2010-05-05 2010-04-22 2010-04-21 2010-04-16 2010-04-09 2010-04-03 2010-03-26 2010-03-20 2010-03-11 2010-03-03 Rize Trabzon Tekirdag Artvin Samsun Zonguldak Sinop Izmir Kocaeli Kocaeli Giresun Kastamonu Sinop Duzce Antalya Van Van 2010-02-24 Istanbul 2010-02-23 Trabzon 2010-02-19 2010-02-18 2010-02-01 2010-01-29 2010-01-28 2010-01-28 Sivas Bursa Gaziantep Antalya Istanbul Tekirdag UNFCCC/CCNUCC CDM – Executive Board 139 HE Page 74 BAYBURT HES 14.600 24.0 140 HE UZUNÇAYIR 54.660 121.3 141 LN ETİ SODA 24.000 144.0 9.573 16.7 142 HE CİNDERE DENİZLİ 143 HE KULP IV HES (YILDIZLAR EN.) 12.300 23.0 144 NG TÜPRAŞ (Orta Anadolu-Kırıkkale) 34.000 240.2 2.450 4.5 145 HE SARITEPE HES DİNAMİK SİSTEMLER 146 NG AKSA ENERJİ (Manisa) 10.500 83.2 147 NG FALEZ ELEKTRİK 11.700 88.0 2.000 16.0 148 NG ÇELİKLER RİXOS ANKARA OTEL 149 NG TAV İSTANBUL 150 HE UZUNÇAYIR 3.260 27.3 27.330 60.7 4.5 151 HE SARITEPE HES DİNAMİK SİSTEMLER 2.450 152 HE ÖZYAKUT GÜNEŞLİ HES 0.600 1.3 SELKASAN 9.900 73.0 30.100 65.0 153 NG 154 HE TÜM EN. PINAR 155 HE ERVA KABACA HES 4.240 7.5 126.100 1,008.0 AKGIDA PAMUKOVA 7.500 61.0 2.7 54.1 156 NG CAM İŞ ELEKTRİK (Mersin) 157 NG 158 NG MAURİ MAYA 0.330 159 FO KIRKA BORAKS (Kırka) 8.200 160 NG DALSAN ALÇI 1.200 9.0 161 IC İÇDAŞ ÇELİK 135.000 961.7 162 HE ERVA KABACA HES 163 NG 4.240 7.5 101.2 364.0 DELTA ENERJİ 13.000 164 FO ALİAĞA PETKİM 52.000 165 HE DENİZLİ EGE 1 0.900 2.0 166 WS ORTADOĞU ENERJİ (Oda yeri) 5.660 44.3 167 HE AKÇAY 28.800 45.0 168 NG ENTEK (Köseköy) İztek 12.400 98.7 8.553 64.0 169 NG GLOBAL ENERJİ (PELİTLİK) 170 NG RASA ENERJİ (VAN) 78.570 499.9 171 HE OBRUK I-II 210.800 614.0 172 IC İÇDAŞ ÇELİK 135.000 961.7 173 HE KAYEN ALFA EN.KALETEPE HES (tortum) 10.200 17.0 ZORLU ENERJİ (B.Karıştıran) 49.530 371.9 5.800 20.0 300.000 2,087.0 4.400 7.0 33.3 174 NG 175 HE AKUA KAYALIK 176 NG AKSA ENERJİ (Antalya) 177 HE ŞİRİKÇİOĞLU KOZAK 178 HE CİNDERE DENİZLİ 19.146 179 NG MARMARA PAMUK 34.920 271.5 180 NG ANTALYA ENERJİ 41.820 302.2 181 NG AKSA ENERJİ (Antalya) 300.000 2,087.0 2.7 182 HE ÖZYAKUT GÜNEŞLİ HES 1.200 183 NG MAURİ MAYA 2.000 16.3 184 BG CARGİLL TARIM 0.100 0.7 TOCAK I HES (YURT ENERJİ ÜRETİM SAN.) 4.800 6.0 135.000 945.0 46.950 352.2 2.300 18.0 185 HE 186 AS SİLOPİ ASFALTİT 187 NG NUH ENERJİ (ENER SANT.2) 188 NG TESKO KİPA İZMİR 2010-01-28 2010-01-28 2010-01-22 2010-01-21 2010-01-13 2009-12-25 2009-12-24 2009-12-18 2009-12-16 2009-12-15 2009-12-12 2009-12-02 2009-11-19 2009-11-13 2009-11-11 2009-11-06 2009-10-29 Bayburt 2009-10-19 2009-10-17 2009-10-16 2009-10-15 2009-10-14 Mersin Tunceli Ankara Denizli Diyarbakir Kirikkale Adana Manisa Antalya Ankara Istanbul Tunceli Adana K.Maras Manisa Adiyaman Artvin Sakarya Balikesir Eskisehir Kocaeli 2009-10-13 Canakkale 2009-09-23 Artvin 2009-09-17 2009-08-28 2009-08-27 2009-08-14 2009-08-14 2009-08-06 2009-07-31 2009-07-31 2009-07-29 2009-07-24 2009-07-23 2009-07-17 2009-07-15 2009-07-10 2009-07-08 2009-07-02 2009-06-18 2009-06-05 2009-05-29 2009-05-29 Kirklareli 2009-05-28 2009-05-26 2009-05-08 2009-05-02 2009-04-30 2009-04-27 Balikesir Izmir Denizli Istanbul Aydın Kocaeli Tekirdag Van Corum Canakkale Erzurum Kirklareli Erzincan Antalya K.Maras Denizli Tekirdag Antalya Antalya K.Maras Bursa Antalya Sirnak Kocaeli Izmir UNFCCC/CCNUCC CDM – Executive Board 189 NG Page 75 KEN KİPAŞ (KAREN)ELEKTRİK 17.460 75.2 190 NG DELTA ENERJİ 47.000 365.8 191 NG K.Maras 201 NG AKSA ENERJİ (Manisa) 52.380 202 NG AKSA ENERJİ (Antalya) 46.700 324.9 2.830 22.1 KARKEY (SİLOPİ) SARMAŞIK I HES (FETAŞ FETHİYE ENERJİ) SARMAŞIK II HES (FETAŞ FETHİYE ENERJİ) 14.780 95.8 2009-04-23 2009-04-21 2009-04-17 2009-04-02 2009-03-27 2009-03-26 2009-03-06 2009-03-04 2009-02-26 2009-02-06 2009-01-30 2009-01-30 2009-01-15 2008-12-29 2008-12-29 2008-12-19 21.000 54.0 2008-11-28 Trabzon 21.600 61.0 2008-11-28 Trabzon AKKÖY ENERJİ (AKKÖY HES) 33.980 87.7 2008-11-26 2008-11-07 2008-10-17 2008-10-16 2008-10-10 2008-10-10 2008-09-25 2008-09-18 2008-09-17 2008-09-16 2008-09-04 2008-08-29 2008-08-08 2008-08-01 2008-07-31 2008-07-25 2008-07-19 2008-07-04 2008-07-03 2008-07-03 2008-05-22 2008-05-17 Gumushane 324.9 2008-04-02 2008-03-07 2008-02-23 2008-02-22 2008-02-21 2008-01-30 2008-01-29 2008-01-24 2008-01-04 Tekirdag AKSA ENERJİ (Antalya) 16.200 112.7 192 GT GÜRMAT EN. 47.400 313.0 193 NG SÖNMEZ ELEKTRİK 8.730 67.3 194 NG KASAR DUAL TEKS.ÇORLU 5.700 38.0 195 NG TAV İSTANBUL 6.520 54.7 196 WS ORTADOĞU ENERJİ (Oda yeri) 4.245 33.2 197 LN ALKİM (ALKALİ KİMYA) (Konya) 0.400 3.0 236.7 198 NG ERDEMİR 39.200 199 NG TÜPRAŞ ALİAĞA 24.700 170.0 2.000 6.0 414.9 200 HE 203 WS 204 FO 205 HE 206 HE 207 HE 208 NG TAŞOVA YENİDEREKÖY ORTADOĞU ENERJİ (Oda yeri) AKSA ENERJİ (Antalya) 46.700 209 NG AKSA ENERJİ (Antalya) 46.700 324.9 210 HE TORUL 103.200 264.0 17.460 138.3 0.800 4.0 211 NG AKSA ENERJİ (Manisa) 212 HE YEŞİL ENERJİ (TAYFUN HES) 213 HE DAREN HES (SEYRANTEPE BARAJI) 24.850 80.5 214 HE AKKÖY ENERJİ (AKKÖY HES) 67.960 175.3 215 HE DAREN HES (SEYRANTEPE BARAJI) 24.850 80.5 216 NG AKSA ENERJİ (Manisa) 34.920 276.6 217 NG AKSA ENERJİ (Antalya) 43.700 304.0 218 HE H.G.M.ENER.(KEKLİCEK HES) 219 NG ANTALYA ENERJİ 220 NG POLAT RÖNESANS 221 HE HİDRO KONTROL YUKARI MANAHOZ 222 NG 8.700 11.0 17.460 126.2 1.600 11.0 22.400 45.0 67.3 SÖNMEZ ELEKTRİK 8.730 223 HE CANSU ELEKTRİK (ARTVİN) 9.200 31.0 224 NG MODERN ENERJİ 9.520 66.9 225 NG BAHÇIVAN GIDA (LÜLEBURGAZ) 1.200 8.0 226 NG MELİKE TEKSTİL G.ANTEP 1.600 11.0 227 HE İÇ-EN ELEK. ÇALKIŞLA 7.700 11.0 228 NG FOUR SEASONS OTEL 1.200 7.0 229 NG CAN ENERJİ 34.920 202.9 CAN ENERJİ 17.460 101.4 0.060 0.4 22.600 146.3 14.0 230 NG 231 NG FRİTOLEY GIDA 232 NG YILDIZ SUNTA (Köseköy) 233 NG MİSİS APRE TEKSTİL ADANA 2.000 234 NG ATAÇ İNŞSAN. ANTALYA 5.400 37.0 235 HE TEMSA ELEKTRİK (GÖZEDE HES) 2.400 6.0 236 HE ALP ELEKTRİK (TINAZTEPE) 7.700 17.0 237 NG KESKİN KILIÇ SULTANHANI 8.800 60.0 Kirklareli Antalya Aydin Usak Tekirdag Istanbul Istanbul Konya Zonguldak Izmir Amasya Manisa Antalya Istanbul Sirnak Antalya Antalya Gumushane Manisa K.Maras Elazig Gumushane Elazig Manisa Antalya Malatya Antalya Istanbul Trabzon Usak Artvin Tekirdag Kirklareli Gaziantep Erzincan Istanbul Tekirdag Kocaeli Kocaeli Adana Antalya Bursa Antalya Aksaray UNFCCC/CCNUCC CDM – Executive Board 238 GT Page 76 SARAYKÖY JEOTERMAL 6.900 50.0 239 HE MERCAN ZORLU 1.275 3.0 240 FO KARKEY (SİLOPİ) 29.560 191.6 241 NG SÜPERBOY BOYA 1.000 8.0 242 NG FLOKSER TEKSTİL (Poliser) 2.100 17.0 243 HE KURTEKS (Karasu Andırın HES) 2.400 19.0 244 NG ACIBADEM Kadıköy 2 0.600 5.0 245 NG TAV Esenboğa 3.900 33.0 246 NG ALİAĞA Çakmaktepe Enerji 34.840 262.3 247 NG BİS ENERJİ (Bursa San.) 28.300 233.5 248 NG BİS ENERJİ (Bursa San.) 48.000 396.1 11.0 249 NG ACIBADEM Bursa 1.300 250 NG SWISS OTEL (İstanbul) 1.600 11.0 251 NG AKATEKS Çorlu 1.800 14.0 47.0 4.0 252 NG SAYENERJİ (Kayseri OSB) 5.900 253 NG ACIBADEM Kadıköy 1 0.500 254 NG ENTEK (Demirtaş) 10.750 81.1 255 NG BİS ENERJİ (Bursa San.) 43.000 354.8 256 HE ÖZGÜR ELEKTR.K.Maraş Tahta HES 6.250 27.0 257 HE ÖZGÜR ELEKTR.K.Maraş Tahta HES 6.250 27.0 23.000 184.0 258 NG HABAŞ (Aliağa) 259 NG T. ENERJİ TURCAS 1.600 13.0 260 FO ORS (Polatlı) 7.400 51.5 261 NG KIVANÇ TEKSTİL 3.900 33.0 262 HE BORÇKA 300.600 927.2 25.0 263 NG KİL-SAN 3.200 264 NG FRİTOLEY GIDA 0.540 3.6 265 NG BOSEN (Bursa San.) 11.800 88.6 266 NG AKMAYA (Lüleburgaz) 6.900 48.0 267 NG BURGAZ ELEKTRİK 6.900 55.0 268 WD ERTÜRK ELEKT. (TEPE) 0.900 2.0 13.300 46.7 269 HE BEREKET (MENTAŞ) 270 NG ÇIRAĞAN SARAYI 271 HE ENERJİ-SA-AKSU-ŞAHMALLAR 1.300 11.0 14.000 7.0 360.000 1,306.5 272 LN ELBİSTAN B 1-4 273 NG ENTEK (Köseköy) İztek 37.000 294.6 ÇERKEZKÖY ENERJİ 49.200 403.0 46.3 274 NG 275 NG YILDIZ ENTEGRE 6.184 276 LN ELBİSTAN B 1-4 360.000 1,306.5 CAM İŞ ELEKTRİK (Mersin) 126.100 1,008.0 8.0 277 NG 278 HE ENERJİ SA-SUGÖZÜ-KIZILDÜZ 15.400 279 HE EKİN ENERJİ (BAŞARAN HES) 0.600 0.0 280 NG EROĞLU GİYİM 1.200 9.0 281 WS EKOLOJİK ENERJİ (Kemerburgaz) 1.000 8.0 282 HE BEREKET (MENTAŞ) 26.600 93.3 283 NG HAYAT TEMİZLİK 15.000 94.0 284 NG ANTALYA ENERJİ 34.920 252.4 4.600 4.0 360.000 1,306.5 1.600 13.0 285 HE SU ENERJİ (ÇAYGÖREN HES) 286 LN ELBİSTAN B 1-4 287 NG ŞIK MAKAS 2008-01-04 2008-01-01 2007-12-13 2007-12-06 2007-12-04 2007-11-29 2007-10-24 2007-09-20 2007-09-14 2007-09-11 2007-08-31 2007-08-29 2007-08-02 2007-07-31 2007-07-12 2007-06-20 2007-06-15 2007-05-31 2007-05-25 2007-05-04 2007-05-03 2007-04-05 2007-03-23 2007-03-21 2007-02-28 2007-02-20 2007-01-24 2007-01-19 2006-12-23 2006-12-23 2006-12-22 2006-12-13 2006-12-01 2006-11-16 2006-11-13 2006-11-03 2006-10-06 2006-09-21 2006-09-17 2006-09-13 2006-09-08 2006-08-11 2006-08-01 2006-07-31 2006-07-31 2006-06-30 Denizli 2006-06-29 2006-06-27 2006-06-23 2006-06-22 Antalya Tunceli Sirnak Istanbul Istanbul K.Maras Istanbul Ankara Izmir Bursa Bursa Bursa Istanbul Tekirdag Kayseri Istanbul Bursa Bursa K.Maras K.Maras Izmir Istanbul Ankara Adana Artvin Istanbul Kocaeli Bursa Kirklareli Kirklareli Istanbul Adana Istanbul Antalya K.Maras Kocaeli Tekirdag Kocaeli K.Maras Mersin Antalya Aydin Tekirdag Istanbul Adana Kocaeli Balikesir K.Maras Tekirdag UNFCCC/CCNUCC CDM – Executive Board 288 NG Page 77 AMYLUM NİŞASTA (Adana) 8.100 45.31 289 BG ADANA ATIK 0.800 6.0 290 HE MOLU ENERJİ (BAHÇELİK HES) 4.200 30.0 291 NG KASTAMONU ENTEGRE 7.500 48.0 292 HE BEREKET (GÖKYAR) 11.600 23.0 293 NG SÖNMEZ ELEKTRİK 17.460 134.6 3.200 25.0 47.620 379.2 8.730 67.9 195.6 294 NG ELSE TEKSTİL 295 NG ENTEK (Köseköy) İztek 296 NG MARMARA PAMUK 297 NG NUH ENERJİ (ENER SANT.2) 26.080 298 HE ŞANLI URFA 51.000 145.0 AYDIN ÖRME 7.500 60.0 21.890 151.4 299 NG 300 NG ALARKO ALTEK 301 NG ERAK GİYİM 1.400 12.0 EKOTEN TEKSTİL 1.900 15.0 51.020 382.9 302 NG 303 NG BOSEN (Bursa San.) 304 FO KARKEY (SİLOPİ) 6.750 43.8 305 NT MENDERES TEKS. (AKÇA ENERJİ) 8.730 63.9 306 IC KAHRAMANMARAŞ KAĞIT 6.000 45.0 43.0 307 NG PAKGIDA (Kemalpaşa) 5.700 308 NG KORUMA KLOR 9.600 77.0 309 IC İÇDAŞ ÇELİK 135.000 961.7 64.0 2006-06-09 2006-06-09 2006-05-31 2006-05-24 2006-05-05 2006-05-03 2006-04-15 2006-04-14 2006-04-13 2006-03-02 2006-03-01 2006-02-25 2006-02-23 2006-02-22 2006-02-16 2005-12-30 2005-12-23 2005-12-14 2005-12-08 2005-12-07 Adana Kocaeli Adana Kayseri Balikesir Mugla Usak Tekirdag Kocaeli Tekirdag Kocaeli Sanliurfa Sakarya Kirklareli Tekirdag Izmir Bursa Sirnak Denizli K.Maras Izmir MANİSA O.S.B. 84.834 678.2 315 NG AK ENERJİ (Kemalpaşa) 40.000 328.3 2005-12-03 2005-11-30 2005-11-27 2005-11-26 2005-11-24 2005-11-14 2005-11-11 2005-11-09 316 NG ZORLU ENERJİ (Kayseri) 38.630 294.9 2005-10-26 Kayseri 317 NG ALARKO ALTEK 60.100 415.6 2005-10-14 Kirklareli 318 NG AYKA TEKSTİL 5.500 41.0 319 NG HABAŞ (Aliağa) 44.615 357.0 5.100 30.0 164.8 310 NG KÜÇÜKÇALIK TEKSTİL 8.000 311 NG ZORLU ENERJİ (Yalova) 15.900 122.3 312 NG HABAŞ (Aliağa) 23.000 184.0 5.500 42.0 313 NG GRANİSER GRANİT 314 NG 320 NG EVYAP 321 NG ÇEBİ ENERJİ 21.000 322 NG CAN ENERJİ 3.900 22.7 323 NG NOREN ENERJİ 8.700 70.0 324 NG ÇEBİ ENERJİ 43.366 340.2 325 HE YAMULA 100.000 422.0 326 NG ZORLU ENERJİ (Kayseri) 149.871 1,144.1 327 BG BANDIRMA ASİT(ETİ MADEN) 11.500 88.0 328 HE BEREKET (DALAMAN) 7.500 35.8 329 NG ZEYNEP GİYİM 1.200 9.0 330 FO KARKEY (SİLOPİ) 6.150 39.9 AKBAŞLAR 5.040 38.25 10.240 72.0 115.000 460.5 44.615 357.0 28.0 331 NG 332 NG MODERN ENERJİ 333 HE MURATLI 334 NG HABAŞ (Aliağa) 335 NG TEZCAN GALVANİZ GR I-II 3.500 336 NG HAYAT KAĞIT SAN. 7.200 56.3 YONGAPAN (Kastamonu) 5.200 30.5 337 NG 2005-09-24 2005-09-21 2005-08-27 2005-08-27 2005-08-25 2005-08-24 2005-08-23 2005-07-30 2005-07-22 2005-07-15 2005-07-15 2005-07-07 2005-06-30 2005-06-24 2005-06-13 2005-06-02 2005-06-02 2005-05-27 2005-05-27 2005-05-25 Canakkale Bursa Yalova Izmir Manisa Manisa Izmir Tekirdag Izmir Istanbul Tekirdag Tekirdag Nigde Tekirdag Kayseri Kayseri Balikesir Mugla Tekirdag Sirnak Bursa Tekirdag Artvin Izmir Kocaeli Corum Kocaeli UNFCCC/CCNUCC CDM – Executive Board 338 NG Page 78 NUH ENERJİ (ENER SANT.2) 46.950 352.2 339 HE İÇTAŞ YUKARI MERCAN 14.200 20.0 340 NG AK ENERJİ (Kemalpaşa) 87.200 715.7 1.200 2.0 341 WD SUNJÜT 342 NG KAREGE ARGES 17.460 138.9 343 NG BİS ENERJİ (Bursa San.) 43.700 360.6 976.5 344 LN ÇAN 1-2 160.000 345 LN ÇAN 1-2 160.000 976.5 346 LN ELBİSTAN B 1-4 360.000 1,306.5 19.0 347 NG ENTEK (KOÇ Üniversite) 2.300 348 NG BAYDEMİRLER (Beylikdüzü) 6.210 51.5 MERCEDES BENZ 8.300 68.0 11.748 87.8 349 NG 350 NG GLOBAL ENERJİ (PELİTLİK) 351 NG GLOBAL ENERJİ (HACIŞİRAHMET) 7.800 58.0 10.5 7.0 352 FO TÜPRAŞ (Batman) 1.500 353 NG BAHARİYE MENSUCAT 1.000 354 NG ALTINMARKA 355 FO KARKEY (SİLOPİ) 356 NG STANDARD PROFİL 357 NG HABAŞ (Aliağa) 3.596 28.1 54.300 351.9 6.700 49.0 89.230 714.0 84.0 358 NG AYEN OSTİM 9.890 359 NG KOMBASSAN AMBALAJ (Konya) 5.500 40.0 360 HE BEREKET (FESLEK) 9.500 25.0 361 NG ÇELİK ENERJİ (Uzunçiftlik) 2.400 19.0 362 NG BERK ENERJİ (BESLER -KURTKÖY) 4.400 30.9 ŞAHİNLER ENERJİ(ÇORLU/TEKİRDAĞ) 3.200 22.8 325.0 363 NG 364 NG ENERJİ-SA (Adana) 49.770 365 NG BİS ENERJİ (Bursa San.) 73.000 602.3 366 NG AYEN OSTİM 31.077 264.0 367 NG KOMBASSAN AMBALAJ (Tekirdağ) 5.500 38.0 368 NG TEKBOY TEKSTİL 2.200 16.0 45.000 337.5 369 IC ÇOLAKOĞLU-2 370 HE İŞKUR (SÜLEYMANLI HES) 4.600 4.0 371 HE ELTA (DODURGA) 4.100 12.0 10.400 82.0 372 LPG ETİ BOR (EMET) 373 NG TANRIVERDİ 374 HE ENERJİ-SA BİRKAPILI 375 NG ATATEKS TEKSTİL 376 NG ENTEK (Demirtaş) 377 NG ANKARA 378 NG ECZACIBAŞI BAXTER 379 NG SÖNMEZ FLAMENT 380 IC İSKENDERUN 381 NG ENERJİ-SA (Mersin) 382 HE BATMAN 4.700 39.0 48.500 17.0 5.600 45.0 31.132 234.7 798.000 5,209.0 1.000 6.0 4.100 29.0 1,320.000 7,706.0 21.575 177.4 198.500 450.0 175.0 383 NG ENERJİ-SA (Çanakkale) 21.575 384 NG BATIÇİM ENERJİ (AK ENERJİ) 14.500 119.3 385 HE PAMUK (Toroslar) 23.300 28.0 386 HE MERCAN ZORLU 19.100 45.0 387 NG ENERJİ-SA (Mersin) 41.650 342.6 2005-05-24 2005-05-21 2005-04-30 2005-04-22 2005-04-07 2005-03-18 2005-03-15 2005-02-15 2005-02-15 2005-02-07 2005-02-04 2005-02-04 2005-01-29 2005-01-29 2004-12-31 2004-12-31 2004-12-17 2004-11-12 2004-10-22 2004-10-08 2004-10-01 2004-09-24 2004-08-05 2004-07-09 2004-07-07 2004-06-29 2004-06-23 2004-06-16 2004-06-11 2004-06-09 2004-05-18 2004-05-05 2004-04-28 2004-04-26 2004-04-22 2004-03-24 2004-03-11 2004-02-20 2004-02-12 2004-01-08 2003-12-31 2003-12-31 2003-11-22 2003-11-22 2003-11-14 2003-11-12 2003-10-26 2003-10-18 2003-10-08 2003-10-05 Kocaeli Erzincan Izmir Istanbul Izmir Bursa Canakkale Canakkale K.Maras Istanbul Istanbul Istanbul Tekirdag Tekirdag Batman Istanbul Istanbul Sirnak Duzce Izmir Ankara Konya Aydin Kocaeli Istanbul Tekirdag Adana Bursa Ankara Tekirdag Kirklareli Kocaeli K.Maras Denizli Kutahya Tekirdag Mersin Tekirdag Bursa Ankara Istanbul Bursa Hatay Mersin Batman Canakkale Izmir Mersin Tunceli Mersin UNFCCC/CCNUCC CDM – Executive Board 388 HE 389 FO 390 NG Page 79 85.000 132.9 ANADOLU EFES BİRA I 3.800 32.0 ZORLU ENERJİ (Sincan) 10.660 90.8 17.1 KÜRTÜN 391 NG BAYDEMİRLER (Beylikdüzü) 2.066 392 NG TÜBAŞ 1.400 9.0 393 NG PAKGIDA (Düzce-Köseköy) 2.100 16.7 394 NG ÖZAKIM ENERJİ (Gürsu) 7.000 60.0 395 NG KEN KİPAŞ (KAREN)ELEKTRİK 24.340 104.8 396 HE YAPISAN HACILAR DARENDE 13.300 54.0 397 NG ZORLU ENERJİ (Sincan) 39.700 338.2 398 NG CAN TEKSTİL (Çorlu) 0.900 6.9 50.0 399 NG YURTBAY (Eskişehir) 6.900 400 NT ALKİM KAĞIT 3.385 26.7 401 NG İZMİR 1,590.700 10,780.0 25.400 208.9 5.200 32.0 402 NG BATIÇİM ENERJİ (AK ENERJİ) 403 NG HAYAT KİMYA (İzmit) 404 FO ALİAĞA PETKİM 21.700 151.9 405 HE EŞEN-II (GÖLTAŞ) 21.700 40.0 406 NG BATIÇİM ENERJİ (AK ENERJİ) 407 LN ETİ MADEN (BANDIRMA BORAKS) 5.080 41.8 10.700 78.0 1,432.000 9,711.0 408 NG BURSA D.GAZ 409 DO VAN ENGİL GAZ (ZORLU ENERJİ) 15.000 75.0 410 LN KEMERKÖY 630.000 2,698.0 411 LN ORHANELİ 210.000 950.0 412 HC ÇATALAĞZI-B 300.000 1,721.1 KANGAL 457.000 2,391.0 1,350.900 7,919.0 413 LN 414 NG AMBARLI-D.GAZ 415 LN ÇAYIRHAN PARK HOLD. 620.000 3,601.0 416 LN YENİKÖY 420.000 2,150.0 417 NG HAMİTABAT 1,156.000 6,804.0 418 LN ELBİSTAN A 1,355.000 3,144.0 15.000 105.0 419 GT ZORLU ENERJİ (DENİZLİ) 420 LN YATAĞAN 630.000 2,869.0 421 LN SOMA B 990.000 4,715.0 422 NG ALİAĞA-ÇEVRİM 180.000 1,025.0 423 FO HOPA 424 LN 50.000 241.6 3,201.0 SEYİTÖMER 600.000 425 FO AMBARLI 630.000 0.0 426 LN SOMA A 44.000 0.0 BİLGİN ELEK. (HAZAR 1-2) 30.100 0.0 365.000 1,499.0 427 HE 428 LN TUNÇBİLEK 429 DO HAKKARİ ÇUKURCA 2003-09-26 2003-09-05 2003-07-18 2003-07-11 2003-07-11 2003-07-02 2003-06-19 2003-06-14 2003-06-14 2003-05-31 2003-05-17 2003-05-16 2003-05-03 2003-03-28 2003-03-13 2003-03-11 2003-02-24 2003-01-31 2003-01-27 2003-01-10 1998-01-01 1996-01-01 1993-01-01 1992-01-01 1989-01-01 1989-01-01 1988-01-01 1987-01-01 1986-01-01 1985-01-01 1984-01-01 1984-01-01 1982-01-01 1981-01-01 1975-01-01 1973-01-01 1973-01-01 1967-01-01 1957-01-01 1957-01-01 1956-01-01 Gumushane Ankara Ankara Istanbul Tekirdag Duzce Bursa K.Maras Malatya Ankara Tekirdag Eskisehir Afyon Izmir Izmir Kocaeli Izmir Mugla Izmir Balikesir Bursa Van Mugla Bursa Zonguldak Sivas Istanbul Ankara Mugla Kirklareli K.Maras Denizli Mugla Manisa Izmir Artvin Kütahya Istanbul Manisa Elazig Kütahya 1.000 0.0 62.000 146.4 Hakkari Denizli 27.000 93.4 Tokat 702.600 1,616.0 430 HE ADIGÜZEL 431 HE ALMUS 432 HE ALTINKAYA 433 HE ASLANTAŞ 138.000 674.9 434 HE ATATÜRK 2,405.000 8,139.9 435 HE BERDAN 10.200 15.0 Mersin 436 HE ÇATALAN 168.900 646.0 Adana 437 HE ÇAMLIGÖZE 32.000 97.5 Sivas Samsun Osmaniye Sanliurfa UNFCCC/CCNUCC CDM – Executive Board 438 HE Page 80 DEMİRKÖPRÜ 69.000 102.7 Manisa 439 HE DERBENT 56.400 289.0 Samsun 440 HE DİCLE 110.000 180.8 Diyarbakir 74.500 220.0 Giresun 441 HE DOĞANKENT 442 HE GEZENDE 159.400 220.0 Mersin 443 HE GÖKÇEKAYA 278.400 471.1 Eskisehir 444 HE HASAN UĞURLU 500.000 1,182.0 445 HE HASANLAR 446 HE HİRFANLI Samsun 9.400 29.6 128.000 290.0 Bolu Kirsehir 194.1 Kirikkale 447 HE KAPULUKAYA 54.000 448 HE KARACAÖREN-1 32.000 72.7 Burdur KARACAÖREN II 46.400 123.0 Burdur 1,800.000 8,383.8 Diyarbakir Gaziantep 449 HE 450 HE KARAKAYA 451 HE KARKAMIŞ 452 HE 189.000 672.9 7,110.0 Elazig KEBAN 1,330.000 453 HE KEMER 48.000 78.2 Aydin 454 HE KESİKKÖPRÜ 76.000 173.2 Ankara KILIÇKAYA 120.000 300.0 Sivas 456 HE KÖKLÜCE 90.000 450.0 Tokat 457 HE KRALKIZI 94.500 50.0 Diyarbakir 9.300 24.0 K.Maras 455 HE 458 HE KISIK 459 HE MANAVGAT 48.000 143.0 Antalya 460 HE MENZELET 124.000 603.0 K.Maras 461 HE ÖZLÜCE 170.000 593.9 Elazig 462 HE SARIYAR 160.000 310.1 Ankara 358.0 Samsun 113.0 Erzurum Ankara 463 HE SUAT UĞURLU 69.000 464 HE TORTUM 26.200 465 HE YENİCE 37.900 118.7 466 HE BERKE 510.000 1,614.0 467 HE SEYHAN I 60.000 447.1 Adana 468 HE SEYHAN II 7.500 6.0 Adana 283.500 732.1 K.Maras Osmaniye 469 HE SIR 470 HE KADINCIK I 70.000 200.0 Mersin 471 HE KADINCIK II 56.000 175.0 Mersin 4.5 Adana Antalya 472 HE YÜREĞİR 6.000 473 HE KEPEZ I-II 32.400 90.0 474 HE OTHERS 45.000 100.0 475 HE ADİLCEVAZ(MOSTAR EN.) 0.400 0.5 Bitlis 476 HE AHLAT(MOSTAR EN.) 0.200 0.5 Bitlis 477 HE BAYBURT(BOYDAK EN.) 0.400 1.7 Bayburt 478 HE BESNİ(KAYSERİ VE CİVARI EN.ÜR.) 0.300 0.2 Adiyaman BÜNYAN(KAYSERİ VE CİVARI) 1.200 3.2 Kayseri 14.400 22.0 Mardin 479 HE 480 HE ÇAĞ-ÇAĞ(NAS EN.) 481 HE ÇAMARDI(KAYSERİ VE CİVARI EN.ÜR.) 0.100 0.1 Nigde 482 HE ÇEMİŞKEZEK(BOYDAK EN.) 0.100 0.5 Tunceli 483 HE DEĞİRMENDERE(KA-FNIH EL.) 0.500 0.8 Osmaniye 484 HE DERME(KAYSERİ VE CİVARI EN.ÜR.) 4.500 7.0 Malatya 485 HE ERKENEK(KAYSERİ VE CİVARI EN.ÜR.) 0.300 0.5 Malatya 486 HE GİRLEVİK(BOYDAK EN.) 3.000 19.0 Erzincan 487 HE HAKKARİ (OTLUCA)((NAS EN.) 1.300 5.0 Hakkari UNFCCC/CCNUCC CDM – Executive Board 488 HE Page 81 İNEGÖL(CERRAH)(KENT SOLAR EL.) 0.300 0.8 Bursa 489 HE İZNİK (DEREKÖY)(KENT SOLAR EL.) 0.200 0.9 Bursa 490 HE KARAÇAY(OSMANİYE)(KA-FNIH EL.) KAYADİBİ(BARTIN)(İVME ELEKTROMEKANİK 0.400 2.0 Osmaniye 0.500 2.0 Bartin 491 HE 492 HE KERNEK(KAYSERİ VE CİVARI EN.ÜR.) 0.800 0.6 Malatya 493 HE KOVADA-I(BATIÇİM EN.) 8.300 1.6 Isparta 494 HE KOVADA-II(BATIÇİM EN.) 51.200 24.4 Isparta 1.0 Hatay 495 HE KUZUCULU (DÖRTYOL)(KA-FNIH EL.) 0.300 496 HE M.KEMALPAŞA(SUUÇTU)(KENT SOLAR EL.) 0.500 1.3 Bursa 497 HE MALAZGİRT(MOSTAR EN.) 1.200 3.0 Mus 498 HE PINARBAŞI(KAYSERİ VE CİVARI EN.ÜR.) 0.100 0.3 Kayseri 499 HE SIZIR(KAYSERİ VE CİVARI EN.ÜR.) 5.800 35.0 Kayseri 500 HE TURUNÇOVA(FİNİKE)(TURUNÇOVA EL.) 0.600 0.8 Antalya 501 HE ULUDERE(NAS EN.) 0.600 2.6 Sirnak 502 HE VARTO(MOSTAR EN.) 0.300 0.6 Mus 1,595.400 10,951.0 Sakarya 503 NG GEBZE D.GAZ 504 NG ADAPAZARI 797.700 5,473.0 Sakarya 505 NG TRAKYA ELEKTRİK ENRON 498.700 3,797.0 Tekirdag 506 NG ESENYURT (DOĞA) 188.500 1,400.0 Istanbul 507 NG OVA ELEK. 258.400 2,019.0 Kocaeli 3,797.0 Tekirdag Sanliurfa 508 NG UNİMAR 504.000 509 HE BİRECİK 672.000 2,092.0 510 HE AHİKÖY I-II 4.200 21.0 Sivas 16.000 35.0 Burdur 511 HE AKSU (ÇAYKÖY) 512 HE ÇAL (LİMAK) (Denizli) 513 HE ÇAMLICA (AYEN ENERJİ) 2.500 12.0 Denizli 84.000 429.0 Kayseri 3.000 16.0 Afyon 514 HE DİNAR-II (METAK) 515 HE FETHİYE 16.500 89.0 Mugla 516 HE GAZİLER (Iğdır) 11.200 48.0 Igdir 517 HE GİRLEVİK-II / MERCAN 11.000 39.0 Erzincan 518 HE GÖNEN 10.600 47.0 Balıkesir 28.0 K.Maras 519 HE SUÇATI (ERE EN.) 7.000 520 HE SÜTCÜLER 2.300 13.0 Isparta 521 HE TOHMA MEDİK (ALARKO) 12.500 59.0 Malatya 7.200 19.0 Izmir 10.200 31.0 Canakkale Giresun 522 WD ARES (ALAÇATI) 523 WD BORES (BOZCAADA) 524 FO AKSU SEKA (MİLDA KAĞIT) 8.000 20.0 148.300 1,038.1 ALBAYRAK TURİZM(BALIKESİR SEKA) 9.300 56.0 BOR ŞEKER 9.600 6.0 70.0 Zonguldak Zonguldak 525 FO ALİAĞA PETKİM 526 FO 527 FO Izmir Balikesir Nigde 528 FO OYKA KAĞ.(CAYCUMA SEKA) 10.000 529 FO ERDEMİR 73.500 450.0 530 FO HALKALI KAĞIT 5.100 39.0 Istanbul 531 FO MED UNİON A.Ş. (EBSO) 3.400 26.9 Izmir 532 FO MOPAK (Dalaman) 26.200 106.0 Mugla 35.0 Konya 533 FO S.ŞEHİR (ETİ) ALÜMİNYUM 11.900 534 FO TÜPRAŞ İZMİR (ALİAĞA RAF.) 44.000 306.0 Izmir 535 FO TÜPRAŞ (İzmit-Yarımca) 45.000 291.2 Kocaeli 536 FO TÜPRAŞ (Batman) 8.800 Batman UNFCCC/CCNUCC CDM – Executive Board 537 FO 538 FO 539 DO Page 82 8.000 37.0 OTHERS (Isolated) 96.000 300.0 TÜPRAŞ (Batman) 10.300 72.0 0.100 1.0 TİRE-KUTSAN (Tire) Izmir Batman 540 DO OTHERS 541 IC ÇOLAKOĞLU-2 145.000 1,087.5 542 HC İSDEMİR 220.400 772.0 Hatay 35.000 300.0 Zonguldak Kocaeli 543 HC KARDEMİR 544 LN ALKİM (ALKALİ KİMYA) (Dazkırı) 2.500 17.0 Afyon 545 LN PETLAS 6.000 40.0 Kirsehir 546 LN MARMARA KAĞIT (Bilorsa) 2.000 9.0 Bilecik 547 LN OTHERS 147.500 285.0 548 LPG GOODYEAR (Adapazarı) 9.600 79.0 Sakarya 549 LPG GOODYEAR (İzmit) 4.200 35.0 Kocaeli 550 LPG MOPAK KAĞIT (Işıklar) 551 LPG 4.600 33.0 Izmir 65.0 Kayseri ORTA ANADOLU MENSUCAT 10.000 552 NT MENDERES TEKS. (AKÇA ENERJİ) 10.400 76.1 Denizli 553 NT ALKİM KAĞIT 1.815 14.3 Afyon 554 NT DENTAŞ (Denizli) 5.000 38.0 Denizli 555 NT MENSA MENSUCAT 10.400 85.0 Adana 556 NT TOROS (Ceyhan) 4.700 38.0 Adana 557 NT TOROS (Mersin) 12.100 96.0 Mersin 558 NG AKIN ENERJİ (B.Karıştıran) 4.900 37.0 Kirklareli 559 NG ALTINYILDIZ (Yenibosna) 4.700 40.0 Istanbul 560 NG ARÇELİK (Eskişehir) 6.300 49.0 Eskisehir 561 NG ARÇELİK (Çayırova) 6.500 48.0 Kocaeli 7.0 Tekirdag 562 NG ATLAS HALICILIK (Çorlu) 1.000 563 NG BAYDEMİRLER (Beylikdüzü) 1.000 8.3 Istanbul 564 NG Tekirdag CAN TEKSTİL (Çorlu) 4.300 33.0 565 NG COGNİS (Tuzla)* 1.000 8.0 566 NG ÇOLAKOĞLU-1 123.400 1,047.0 567 NG DOĞUŞ (B.Karıştıran) 1.000 8.0 Tekirdag 568 NG GÜLLE ENTEGRE (Çorlu) 6.300 29.0 Tekirdag 569 NG İGSAŞ (Yarımca) 11.000 76.0 Kocaeli 570 NG SANKO (İSKO) (İnegöl) 9.200 63.0 Bursa 157.0 Canakkale Kocaeli Izmir Kocaeli 571 NG KALESERAMİK (Çan Seramik+Kalebodur) 21.600 572 NG KARTONSAN (İzmit) 24.000 192.0 7.0 Tekirdag 573 NG NUR YILDIZ (GEM-TA)* 1.400 574 NG SARKUYSAN (Tuzla) 7.700 60.0 Kocaeli 575 NG SAMUR HALI A.Ş. 4.300 33.0 Ankara 34.0 Bilecik 576 NG TERMAL SERAMİK (Söğüt) 4.600 577 NG TRAKYA İPLİK (Çerkezköy) 4.200 29.0 Tekirdag 578 NG Bursa YILFERT (TÜGSAŞ GEMLİK GÜB.) 8.000 50.0 579 NG TÜP MERSERİZE (B.Karıştıran) 1.000 7.0 Tekirdag 580 NG YILDIZ SUNTA (Köseköy) 5.200 33.7 Kocaeli 581 NG YONGAPAN (Kastamonu) 5.200 30.5 Kocaeli 84.100 296.0 582 NG OTHERS 583 BG BELKA (Ankara) 3.200 22.0 Ankara 584 BG KEMERBURGAZ 4.000 7.0 Istanbul 10.000 57.0 Balikesir 540.000 1,170.0 585 BG BANDIRMA BAĞFAŞ 586 HE OYMAPINAR (ETİ ALİMİNYUM) Antalya UNFCCC/CCNUCC CDM – Executive Board 587 HE Page 83 BAĞCI SU ÜRÜNLERİ 0.300 1.7 588 HE MOLU 3.400 10.6 Mugla Kayseri 589 HE YEŞİLLİLER (Kırşehir) Kirsehir 0.500 1.0 70.200 398.1 Izmir 126.600 817.0 Bilecik 98.000 805.0 Tekirdag ARENKO DENİZLİ 12.000 84.0 594 NG AKIM EN. BAŞPINAR(SÜPER FİLM)G.ANTEP 25.300 177.0 Gaziantep 595 NG AKSA AKRİLİK KİMYA (YALOVA) 59.500 450.0 Yalova 596 NG BERK ENERJİ (BESLER -KURTKÖY) 10.400 73.1 Istanbul 597 NG BİS ENERJİ (Bursa San.) 174.000 1,435.7 Bursa 600.5 Bursa 590 NT ATAER ENERJİ (EBSO) 591 NG AK ENERJİ (Bozüyük) 592 NG AK ENERJİ (Çerkezköy) 593 NG 598 NG Denizli BOSEN (Bursa San.) 80.000 599 NG BİL ENERJİ (Ankara) 36.600 255.0 Ankara 600 NG EGE BİRLEŞİK ENERJİ 12.800 107.0 Izmir CAM İŞ ELEKTRİK (B.Karıştıran) 32.900 270.0 Kirklareli 131.300 985.0 Samsun 601 NG 602 NG CENGİZ ENERJİ ÇİFT YAK. 603 NG DESA ENERJİ 604 NG ENERJİ-SA (Adana) 605 NG ENERJİ-SA (Çanakkale) 606 NG ENERJİ-SA (Kentsa) Köseköy 607 NG ENTEK (Köseköy) İztek 608 NG ENTEK (Demirtaş) 609 NG MAKSİ ENERJİ 610 NG MODERN ENERJİ 611 NG NUH ENERJİ 1 (Nuh Çimento) 612 NG SAMSUN TEKKEKÖY (AKSA EN.) 613 NG ŞAHİNLER ENERJİ(ÇORLU/TEKİRDAĞ) 614 NG YENİ UŞAK ENERJİ 9.800 70.0 80.400 525.0 Izmir Adana 42.525 345.0 Canakkale 120.000 930.0 Kocaeli 60.100 478.5 Kocaeli 104.000 784.2 Bursa 7.700 55.0 Istanbul 77.000 541.1 Tekirdag 38.000 326.0 Kocaeli 131.300 980.0 Samsun 22.800 162.2 Tekirdag 8.700 65.0 Usak 752.0 Bursa 615 NG ZORLU ENERJİ (Bursa) 90.000 616 NG ZORLU ENERJİ (B.Karıştıran) 65.800 494.1 Kirklareli 617 NG ESKİŞEHİR ENDÜSTRİ ENERJİ(OSB) 59.000 451.8 Eskisehir 5.200 37.0 Kocaeli 618 WS İZAYDAŞ (İzmit çöp) 619 FO AKSA ENERJİ (Hakkari) 24.000 175.0 Hakkari 144.0 Bilecik 620 FO HABAŞ (Bilecik) 18.000 621 FO HABAŞ (İzmir) 36.000 288.0 Izmir 622 FO KIZILTEPE 33.000 250.0 Mardin 623 FO PS3-1 (SİLOPİ) 44.100 285.8 Sirnak 624 FO PS3-2 (SİLOPİ) 29.500 191.2 Sirnak 625 FO PS3-A -1 11.000 80.0 Sirnak 626 FO PS3-A -2 (İDİL) 24.000 180.0 Sirnak 627 FO SİİRT 24.000 190.0 Siirt 628 HE BEREKET (DENİZLİ) 3.700 12.0 Denizli 143.2 Mugla 629 HE BEREKET (DALAMAN) 30.000 630 HE EŞEN-II (GÖLTAŞ) 21.700 40.0 Mugla 55.0 Sakarya 631 HE KAREL (PAMUKOVA) 9.300 632 HE MURGUL BAKIR 4.700 7.5 633 HE Artvin BEYKÖY ZORLU 16.800 87.0 Eskisehir 634 HE KUZGUN ZORLU 20.900 0.0 Erzurum 635 HE TERCAN ZORLU 15.000 28.0 Erzincan 636 HE ATAKÖY ZORLU 5.500 8.0 Tokat UNFCCC/CCNUCC CDM – Executive Board 637 HE Page 84 ÇILDIR ZORLU 15.400 20.0 Kars 638 HE İKİZDERE ZORLU 18.600 100.0 Rize 639 WD ALİZE ENERJİ (DELTA PLASTİK) 1.500 4.0 Izmir TOTAL 49,468.3 256,636.4 51,327.3 20% 256,636,38 MWh 2 51,327,276 MWh AEGtotal AEGSET-=20 per cent Abbreviations: AS: Asphaltite, BG: Biogas, DO: Diesel Oil, FO: Fuel Oil, GT: Geothermal, HC: Hard Coal, HE: Hydroelectric, IC: Imported Coal, LN: Lignite, LPG: Liquefied Petroleum Gas, NG: Natural Gas, NT: Naphta, WD. Wind, WS: Waste Appendix 5: Further background information on monitoring plan Not available. Appendix 6: Summary of post registration changes Not available. ----History of the document Version 04.1 Date 11 April 2012 04.0 EB 66 13 March 2012 EB 25, Annex 15 26 July 2006 02 EB 14, Annex 06b 14 June 2004 01 EB 05, Paragraph 12 03 August 2002 Decision Class: Regulatory Document Type: Form Business Function: Registration Nature of revision Editorial revision to change version 02 line in history box from Annex 06 to Annex 06b. Revision required to ensure consistency with the “Guidelines for completing the project design document form for CDM project activities” (EB 66, Annex 8). 03 Initial adoption.