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PROJECT DESIGN DOCUMENT FORM FOR CDM PROJECT ACTIVITIES (F-CDM-PDD) Version 04.1
PROJECT DESIGN DOCUMENT (PDD)
Title of the project activity Ova Wind Power Plant Version number of the PDD V1.3 Completion date of the PDD 13.04.2015 Project participant(s) Ayres Elektrik Üretim A.Ş. Host Party(ies) Turkey Sectoral scope and selected methodology(ies) Sectoral Scope 1, category “Energy industries (renewable - / non-renewable sources)” and ACM0002.: Grid connected electricity generation from renewable electricity generation - Version 14.0.0. Estimated amount of annual average GHG 23,299 tCO2/year emission reductions
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SECTION A. Description of project activity A.1. Purpose and general description of project activity
Ova Wind Farm will be located in Ödemiş district of İzmir province and in Köşk district of Aydın province in Turkey and developed by Ayres Elektrik Üretim A.Ş. The project will have 9 wind turbines with a unit capacity of 2 MW each. With a total installed capacity of 18 MWm/15 MWe, the project is estimated to supply grid as 45,114 MWh per annum 1 . Expected annual emission reductions of the project is approximately 23,299 tCO2/year which total of reduction of 163,092 tCO2-eq over the 7 year crediting period.
The Project Proponent has been granted a 49 year generation licence by the Turkish Energy Market Regulatory Authority for the proposed Project under the provisions of Law No. 4628 governing the electricity market in the Republic of Turkey.
The purpose of the project activity is to produce renewable electricity using wind as the power source and to contribute to Turkey is growing electricity demand through a sustainable and low carbon technology. The project will displace the same amount of electricity generated by the grid dominated with fossil fired power plants.
The project activity will produce positive environmental and economic benefits through the following aspects: Displacing the electricity generated by fossil fuel fired power plants by utilising the renewable resources so as to avoid environmental pollution and GHG emissions, Contributing the economic development of the region by providing sustainable energy resources, The dependency of foreign fossil fuel (foreign countries) will be reduced by the wind energy and the project will contribute to economy and strengthen wind energy sector in Turkey. Production of pillar and other equipment in Turkey will indirectly cause the know-how transfer and empower the local industry.
The project area belongs to the Ministry of Environment and the proposed project activity is the installation of a new grid-connected renewable power plant/unit. In the absence of the project activity, the electrical energy would have been delivered to the grid through a mix of existing power generation resources, as described in more detail in section B.4.
A.2. Location of project activity A.2.1. Host Party(ies)
Turkey
A.2.2. Region/State/Province etc. Aegean Region, İzmir and Aydın Provinces
1 The DLC Litmann Wind Assestment Report of Ova WPP page 4 p75 value is available to the DOE.
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A.2.3. City/Town/Community etc.
The project is located at Ödemiş district in İzmir province and Köşk district in Aydın province.
A.2.4. Physical/Geographical location
The coordinates of the boundaries of the proposed project activity are 596378.59E; 4209995.4N and 599448.14E; 4209376.66N. The nearest residential area is Bıçakçı village. Table 1: Turbine Coordinates2
E N T1 596888,37 4210076,47 T2 597427,61 4209619,49 T3 597802,90 4209387,72 T4 598061,89 4209363,47 T5 598322,13 4209329,91 T6 598523,14 4209485,92 T7 598724,08 4209321,76 T8 598914,36 4209416,05 T9 599126,18 4209406,83
Please see below the maps showing the location of the project activity in Turkey and the locations of the turbines in the project area:
Figure 1: The location of the project activity in central Aegean Region, Turkey
2 Generation License
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Figure 2: The locations of the turbines in the project area
A.3. Technologies and/or measures
Wind power is one of the most commonly used environment friendly technologies in energy sector all over the world. Within the scope of the project, all precautions have been taken for the environment during the design phase and the project will be implemented in line with the environmental law and related regulations.
Gamesa, a turbine manufacturer based in Spain, has been selected as equipment provider due to the quality of its products in terms of high reliability, grid friendliness and low maintenance requirements. The turbines will be delivered from Spain to the project site.
The project will involve 9 wind turbines with a unit capacity of 2,000 kW. The turbines are 3 bladed with a horizontal axis. The towers will have a hub height of 78m. The diameter of the blades is 97m3.
The turbines will connect to 31.5 kV Nazilli TM electricity transmission line. The metering will be done at substation before electricity is fed into the grid.
Table 2: Technical specifications of turbines
Parameter Value Rated Power 2,000 kW
3 Gamesa cataloge is available to the DOE.
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Rotor Diameter 97m Turbine Concept Gamesa G97/2000 Number of blades 3 Swept Area 7,390 m2 Hub Height 78m Blade Material Pre-impregnated epoxy glass fiber + carbon fiber Rotational speed 9.6 - 17.8 rpm Generator Doubly-fed machine
Joint action of the primary aerodynamic brakes and Brake Systems mechanical emergency brake
Technical lifetime of turbines is considered as 25 years as it is notified for onshore wind power plants in “Tool to determine the remaining lifetime of equipment”.4
PLF in case of wind energy will be calculated as follows: 1.In case of past period: The data such as actual power geerated in a year and the capacity of a particular wind mill will determine the PLF.
Plant Load Factor is the ratio of the actual output of a power plant over a period of time and its output if it had operated a full capacity of that time period. Plant Load Factor = Gross Generation / (Installed Capacity * Number of Hours) For this project, plant load factor is %28,61 as below:
PLF= 45.114.000/ (18.000*8760)*100=%28,61
The amount of electricity generated by the project is not influenced by factors outside the project boundary such as other power plants or demand for electricity. Rather, the governing factor is the wind speed at the project site.
All requirements and specifications of the meters will be done according to Communique on the counter to be used in the Electricity Market by Energy Market Regulatory Authority on 22.04.2011.5
4 https://cdm.unfccc.int/methodologies/PAmethodologies/tools/am-tool-10-v1.pdf 5 http://www.epdk.gov.tr/index.php/elektrik-piyasasi/mevzuat?id=68
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A.4. The Baseline Scenario discussed in more detail in B.4 below. As detailed in Section B.3, the greenhouse gas that will be reduced is carbon dioxide. In the absence of the project activity, the electrical energy would have been delivered to the grid through a mix of existing power generation resources, as described in more detail in section B.4.Parties and project participants Private and/or public Indicate if the Party involved Party involved entity(ies) project wishes to be considered as (host) indicates a host Party participants project participant (Yes/No) (as applicable) Party A (Turkey Ayres Elektrik Üretim A.Ş. No
Party B (Turkey) Rüzgar Danışmanlık No
A.5. Ayres Elektrik Üretim A.Ş.(private entity) is the project owner, shall be defined as the project participant. Contact details are given in Annex 1. Rüzgar Danışmanlık is the carbon consultant for this project.Public funding of project activity
The project activity does not receive any public funding.
A.6. Debundling for project activity
The project is not a debundled component of a large scale project activity, and no project activity is taking place within one kilometer of the project activity with the same project participants.
SECTION B. Application of selected approved baseline and monitoring methodology B.1. Reference of methodology
The project applies CDM-EB approved “ACM0002: Grid-connected electricity generation from renewable sources - Version 14.0.0.6”
The methodology refers to:
“Tool for the demonstration and assessment of additionality”, Version 07.0.0.7 “Combined tool to identify the baseline scenario and demonstrate additionality”, Version 05.0.0.8 “Tool to calculate project or leakage CO2 emissions from fossil fuel combustion”, Version 02.9 “Tool to calculate the emission factor for an electricity system”, Version 04.0.10 “Tool to determine the remaining lifetime of equipment”, Version 0111
The completion date of the baseline study is 31/01/2013.
B.2. Applicability of methodology
The methodology ACM0002 “Consolidated baseline methodology for grid-connected electricity generation from renewable sources” is applicable to grid-con
6http://cdm.unfccc.int/filestorage/A/0/4/A04BWNRKLUEP6O1QX75YVTH28JDICZ/EB%2075_repan13_ACM00 02_ver%2014.0.pdf?t=WDZ8bXg0cnFzfDAh4C_HT5rdPpbGgh2FR_Nd 7 http://cdm.unfccc.int/methodologies/PAmethodologies/tools/am-tool-01-v7.0.0.pdf 8 http://cdm.unfccc.int/methodologies/PAmethodologies/tools/am-tool-02-v5.0.0.pdf 9 http://cdm.unfccc.int/methodologies/PAmethodologies/tools/am-tool-03-v2.pdf 10 http://cdm.unfccc.int/methodologies/PAmethodologies/tools/am-tool-07-v4.0.pdf 11 http://cdm.unfccc.int/methodologies/PAmethodologies/tools/am-tool-10-v1.pdf
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nected 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 implementation of the project activity (greenfield); b) involve a capacity addition c) involve a retrofit of (an) existing plant(s); or d) involve a replacement of (an) existing plant(s). Since the proposed project activit install a new power plant at a site where no renewable power plant was operated prior to the implementation of the project activity (greenfield), ACM0002 “Consolidated baseline methodology for grid-connected electricity generation from renewable sources” version 14.0.0 is applicable. The applicability criteria and conditions may be seen in more detail as below:
Table 3: Applicability of ACM0002 v14.0.0.
Ref. Applicability Criteria Justification A) The project activity is the installation, capacity The project activity is a Greenfield, grid addition, retrofit or replacement of power connected wind power plant project.12 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; B) In the case of capacity additions, retrofits or Since the proposed project is the installation of replacements (except for wind, solar, wave or a new power plant at a site where no tidal power capacity addition projects which renewable power plant was operated prior to use Option 2: on page 10 to calculate the the implementation of the project activity parameter EGPJ,y): the existing plant started (greenfield), this condition is not applicable to commercial operation prior to the start of a the proposed project activity.13 minimum historical reference period of five years, used for the calculation of baseline emissions and defined in the baseline emission section, and no capacity expansion or retrofit of the plant has been undertaken between the start of this minimum historical reference period and the implementation of the project activity. C) In case of hydro power plants, one of the This condition is not applicable to the project following conditions must apply: activity as it does not involve the installation The project activity is implemented in of a hydro power plant.14 an existing single or multiple reservoirs, with no change in the volume of any of reservoirs; or The project activity is implemented in an existing single or multiple reservoirs, where the volume of any of reservoirs is increased and the power density of each reservoir, as per the definitions given in the project
12 The Energy Generation License for 49 years obtained from Electricity Market Regulation Authority (EMRA). 13 The Energy Generation License for 49 years obtained from Electricity Market Regulation Authority (EMRA). 14 The Energy Generation License for 49 years obtained from Electricity Market Regulation Authority (EMRA).
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emissions section, is greater than 4 W/m2; or The project activity results in new single or multiple reservoirs and the power density of each reservoir, as per the definitions given in the project emissions section, is greater than 4 W/m2 . D) In case of hydro power plants using multiple This condition is not applicable to the project reservoirs where the power density of any of activity as it does not involve the installation the reservoirs is lower than 4 W/m2 all the of a hydro power plant. following conditions must apply:
The power density calculated for the entire project activity using equation (5) is greater than 4 W/m2;
Multiple reservoirs and hydro power plants located at the same river and where are designed together to function as an integrated project1 that collectively constitute the generation capacity of the combined power plant;
Water flow between multiple reservoirs is not used by any other hydropower unit which is not a part of the project activity;
Total installed capacity of the power units, which are driven using water from the reservoirs with power density lower than 4 W/m2, is lower than 15 MW;
Total installed capacity of the power units, which are driven using water from reservoirs with power density lower than 4 W/m2, is less than 10 per cent of the total installed capacity of the project activity from multiple reservoirs. . E) The methodology is not applicable to the This condition is not applicable to the project following: activity as it does not involve switching from Project activities that involve fossil fuels to renewable energy sources and switching from fossil fuels to does not involve the installation of a biomass renewable energy sources at the site of fired power plant. the project activity, since in this case the baseline may be the continued use of fossil fuels at the site;
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Biomass fired power plants;
A hydro power plant2 that results in the creation of a new single reservoir or in the increase in an existing single reservoir where the power density of the power plant is less than 4 W/m2.
A hydro power plant2 that results in the creation of a new single reservoir or in the increase in an existing single reservoir where the power density of the power plant is less than 4 W/m2.
F) In the case of retrofits, replacements, or The project activity is a Greenfield, grid capacity additions, this methodology is only connected wind power plant project. applicable if the most plausible baseline scenario, as a result of the identification of baseline scenario, is “the continuation of the current situation, that is to use the power generation equipment that was already in use prior to the implementation of the project activity and undertaking business as usual maintenance.
B.3. Project boundary
The spatial extent of the project boundary includes the project power plant and all power plants connected physically to the electricity system. The project boundary for the project activity is as demonstrated in the figure below:
Figure 3: Project Boundary
The greenhouse gases and emission sources included in or excluded from the project boundary are shown in the table below:
Table 4: The greenhouse gases and emission sources Source GHGs Included? Justification/Explanation
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CO2 emissions CO2 Yes Main emission source. The dominant emissions resulting from from power plants are in the form of CO2, electricity therefore CO2 emissions from fossil fuel fired
generation in power plants connected to the grid will be fossil fuel fired considered in baseline calculations.
power plants that CH4 No Minor emission sources are replaced due N2O No Minor emission sources to the project activity
Baselinescenario
Construction and CO2 No Minor emission sources as stated in ACM0002
operation of the CH4 No v14.0.
project activity N2O No
Project scenario
The following figure represents the line diagram of the project activity, including metering points:
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Figure 4: Monitoring line diagram In accordance with ACM002, version 14.0 no project emissions are relevant for the project activity, since these emissions are occurred as a result of the operation of geothermal power plants and water reservoirs of hydropower plants.
B.4. Establishment and description of baseline scenario
According to the “Baseline Methodology Procedure” in “Tool to calculate the emission factor for an electricity system, Version 04.0.0” baseline emissions are calculated under Section B.6.3.
The electricity generation is predominantly composed by fossil fuel fired power plants in Turkey. The share of resources in the electricity generation in Turkey may be seen in Figure 3. The contribution to annual electricity generation from wind energy was only 2.1 % in 2011.
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Figure 3: Projected Electricity Generation Mix15
As per the 10-year projection of TEIAS (Turkish Electricity Transmission Company), it is obvious that fossil fuels would continue being the main sources for electricity generation (70.9% in 2021). High growth rate of energy demand is forecasted to continue over coming decade. Fossil fuels will be dominant in the electricity generation mix, with an expected share of 71% in 2021. Renewables including wind energy would have a limited share of then 28 %. For this reason, main part of the new capacity will be fossil fuel based.
B.5. Demonstration of additionality
The local stakeholder consultation meeting was organized on 12.12.2013 in the project area as it is before the construction of the plant. In addition to this, during the financial analysis done for the investment decision, the VER revenue has been taken into account. Turbine contract signing date has been taken as investment decision date.
Time schedule of the project activity may be seen in in Table 5 as followed:
Table 5: Time schedule of the project activity Event Actual / Expected Date Obtaining Generation License Actual 20.09.2012 Board Decision on VER Project Actual 03.06.2013 Development Local Stakeholders Meeting Actual 12.12.2013 Turbine Contract Actual 15.06.2014 Start of Construction Actual 04.09.2014 Loan Agreement Actual 28.04.2014 Project Commissioning Expected March 2015
As seen in Table 5, the project proponent has considered VER revenue and the investment decision was based on VER revenue.
Approved consolidated baseline methodology ACM0002 “Consolidated baseline methodology for grid- connected electricity generation from renewable sources” version 14.0 requires the use of the latest “Tool for demonstration and assessment of additionality” (v07.0.0) agreed by the CDM Executive Board to demonstrate and assess the additionality of the proposed project.
The steps completed from the tool may be seen below:
15 http://www.teias.gov.tr/TürkiyeElektrikİstatistikleri/istatistik2011/istatistik%202011.htm
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(a) Step 0 Demonstration whether the proposed project activity is the first-of-its-kind;
(b) Step 1 Identification of alternatives to the project activity;
(c) Step 2 Investment analysis;
(d) Step 3 Barriers analysis; and
(e) Step 4 Common practice analysis
Step 0: Demonstration whether the proposed project activity is the first-of-its-kind N/A Step 1: Identification of alternatives to the project activity
Sub-step 1a: Define alternatives to the project activity
In the absence of the proposed project activity, plausible and credible project activities to the proposed project activity are as below:
The proposed project activity not undertaken as a VER project activity Construction of some other renewable energy plant with the same annual power output Continuation of the current situation (no project activity or other alternatives undertaken).
The alternative, “The proposed project activity not undertaken as a VER project activity” is not realistic, since the equity IRR of the proposed project activity is far below the benchmark IRR. (Please see Investment Analysis Section)
The Electricity Market Regulatory Authority (EMRA) gives priority to local resources with low environmental impact to generate electricity and therefore other renewable resources may be considered as alternatives to the proposed project.
Utilizing solar power or biomass for electricity generation is still at the early stage in Turkey. The biomass sector in Turkey lacks adequate regulatory framework. Especially for landfill gas, investors are dependent on municipal administrations since they hold the authority to control landfills. As for solar, the EPDK has awarded only one license for solar. The reason why solar capacity has not been utilised is that the regulatory framework has been absent. This delay is largely due to the commercial infeasibility of solar projects.16 In addition to this, Odemis district is resourceful of geothermal energy. However the Project Participant’s knowledge is focused in wind energy and OvaWPP has licence only for wind power investment in the proposed project area. Therefore, other project activities delivering same electricity in the same project area is not realistic for Project Participant.
In case no project activity is taken, the same amount of electricity would be generated by the existing grid to supply the increasing demand of the country. This alternative is that 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. Outcome of Sub-Step 1a
Considering these circumstances, the alternative “Continuation of the current situation” seems realistic. It is seen that this scenario is consistent with the baseline definition of ACM0002., version 14.0 where the
16 http://www.pwc.com.tr/tr_TR/tr/publications/industrial/energy/assets/Renewable-report-11-April-2012.pdf
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Sub-step 1b: Consistency with mandatory laws and regulations
The Project is in compliance with all required relevant regulations and there is no breach of any legislation. The Project is subject to the following laws;
Table 6: Applicable Mandatory Laws and Regulations Applicable Mandatory Laws and Regulations Number/Legislation Date Electricity Market Law Nr. 4628 / 03.03.200117 Law on Utilization of Renewable Energy Resources for the Nr. 5346 / 18.05.200518 Purpose of Generating Electrical Energy Environmental Law Nr. 2872 / 11.08.198319
Outcome of Sub-Step 1b
The alternatives discussed above are in compliance with applicable legal and regulatory requirements.
Step 2: Investment Analysis
According to “Tool for the demonstration and assessment of additionality” version 07.0.0, the economical or financial attractiveness of the proposed project should be determined without taking into consideration the VER revenues. It should be noted that the guidance provided by the Executive Board on investment analysis has been taken into account. The following sub-steps are conducted in order to do the investment analysis.
Sub-step 2a: Determine appropriate analysis method:
With respect to “Tool for the demonstration and assessment of additionality” version 07.0.0, simple cost analysis can only be applied to projects that do not generate any other financial benefits than the VER related incomes. Electricity produced by the proposed project will be sold to the national grid and is expected to create revenues, the simple cost analysis is eliminated.
As the appropriate analysis method, benchmark analysis (option III) has been selected.
Sub-step 2b: Option III. Apply benchmark analysis
As implied in Annex 5: Guidance on the Assessment of Investment Analysis (version 05), required/expected returns on equity is appropriate benchmark for an equity IRR.
The expected return on capital should be higher than expected return on equity for an investment to be feasible. The expected return on equity consists of a risk free rate of return; an equity risk premium; a risk premium for the host country and an adjustment factor to reflect the risk of projects in different sectoral scopes.
17 http://www2.epdk.gov.tr/mevzuat/kanun/elektrik/elektrik.html 18 http://www.ttgv.org.tr/content/docs/yek-8.1.2011.pdf 19 http://www.mevzuat.adalet.gov.tr/html/631.html
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As per the requirements of “Tool for the demonstration and assessment of additionality” (Version 07.0.0) expected return on equity is determined as 11.37%.
Calculation of expected return on equity:
The following formula is used for expected return on equity:
Expected Cost of Equity = US Treasury Bond Rate+ Beta*(Equity Risk Premium + Country Risk Premium)
1. Choice of Risk Free Rate
The risk free rate has been used as the US treasury bond rate. Taking into account Annex 5: Guidance on the Assessment of Investment Analysis (version 05), the risk free rate of return is based on the long-term average returns of US treasury bonds and is used as 3% .
2. Choice of Beta
Elektricity Index in Istanbul Stock Exchange has been considered and Beta is taken as 0.848 for the year 2014 before the investment decision date 15.06.2014 by Bloomberg which is one of the well-known data supplier to the financial market.
3. Choice of Country Risk One of the simplest and most easily accessible measure of the country risk is the rating assigned to a country’s debt by a rating agency. These rating measure default risk but they are affected by many of the factors that drive equity risk. Country Default Spreads and Risk Premiums, by Aswath Damodaran20 which was lastly updated in July 2013 is taken as a reference for country risk premium. Aswath Damodaran is a Professor of Finance at the Stern School of Business at New York University and well known as author of several widely used academic and practitioner texts on Valuation, Corporate Finance and Investment Management. The country risk premium for Turkey is taken as 3.38%.
4. Equity Risk Premium
As per Annex 5: Guidance on the Assessment of Investment Analysis (version 05), the value of 6.5 % is used for equity risk premium. The equity risk premium is derived from the long-term historical returns on equity in the US market relative to the return of bonds.
The key parameters are presented in Table 7:
Table 7: Key parameters applied in the calculation of expected return on equity
20http://webcache.googleusercontent.com/search?q=cache:5Nlqwk1mkq0J:www.stern.nyu.edu/~adamodar/pc/dataset s/ctrypremJune13.xls+&cd=1&hl=tr&ct=clnk&gl=tr
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Parameter Value Source Risk Free Rate (US Treasury 3% Reference: Guidelines on assessment of Bond Rate) investment analysis v5 BETA 0.848 Beta for electricity market in Turkey in 2014, Bloomberg21 Country Risk Premium 3.38% Country Default Spreads and Risk Premiums, July 2013, Aswath Damodaran22 Equity Risk Premium for 6.5% Guidelines on assessment of investment USA analysis v5 Expected return on equity 11.37 % Calculated
As a conservative approach, 11.37 % is accepted as the benchmark for the proposed project.
Sub-step 2c: Calculation and comparison of financial indicators
The main financial indicators may be seen in Table 8:
Table 8: Main Financial Indicators Parameter Unit Value Reference Total investment € Loan agreement 20,446,650 Loan % 80 Loan agreement Equity % 20 Loan agreement Production expenses €/ year average 805,548 Estimation Installed capacity MW 18 MW m/15 License MWe Yearly electricity MWh/year 45,114 DLC Litmann Wind Generation Assesment Report23 Electricity feed in $cent/kWh 7.3 Law on Utilization of tariff Renewable Energy Resources for the Purpose of Generating Electrical Energy Revenue €/year average 2,435,161 Calculated24 Corporate tax % 20
The key assumptions for the calculation of the equity IRR are as follows:
All relevant costs and revenues are included in the calculation of the equity IRR of the project activity. The investment period has been chosen as 25 years as per EB62 Annex 5. The lifetime of the project activity has been supposed as 25 years. The revenue from yearly electricity generation is based on the guaranteed feed in tariff applicable at the time of the investment decision. According to the Law on Utilization of Renewable Energy Resources, the guaranteed feed in tariff for electricity generated from wind energy is 7.3
21 The value is available in theIRR calculation spreadsheet. 22 http://www.stern.nyu.edu/~adamodar/pc/datasets/ctrypremJune13.xls 23 The DLC Litmann Wind Assestment Report of Ova WPP page 4 p75 value is available to the DOE 24 Yearly electricity generation(45.114.000kWh) has multiplied electricity feed in tariff(7,3$ =5,37 €)
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$cent/kWh. However, the renewable energy fund price for Turkish made tower has been also added to have an average electricity price.25 Only the portion of investment costs which is financed by equity have been considered as the net cash outflow and the portion of the investment cost which is financed by debt have not been considered as a cash outflow.
The Internal Rate of Return (IRR) is calculated as 6.59%. This is obviously below the financial benchmark of 11.37% and the project activity cannot be considered to be a financially attractive alternative.
The production expenses is in estimation only %3,93 of the total investment.
Sub-step 2d: Sensitivity Analysis
The objective of the sensitivity analysis is to assess if the conclusion regarding the financial attractiveness is steady to reasonable variations in the critical assumptions. According to the Annex 5 of EB 62 “Guidelines on the assessment of Investment analysis” version 5, only variables including the initial investment cost, that constitute more than 20% of either total project costs or total project revenues should be subjected to reasonable variation.
In accordance with the guidelines, important parameters for the feasibility of the proposed project activity are defined as investment cost, production expenses and revenues. The mentioned parameters have been tested with a range of ±10% for the sensitivity analysis.
The following table demonstrates the results for a ±10% deviation of selected parameters which increase the equity IRR.
Table 9: Sensitivity Analysis of the equity IRR with changes in investment cost, production expenses and revenues
Parameter Value Applied Equity Value Applied Equity IRR IRR Investment cost 18,401,985 (-10%) € 9.60% 22,491,315(+10% 4.37% ) €
Production expenses 731,598 (-10%) € 7.57% 879,498 (+10%) € 5.613%
Electricity 40.602.600 kWh (-10 )%) 3.08% 49.625400 kWh 10.53% production (yearly) (+10%) Electricity price 0,0493 Euro cent (-10 %) 3.08% 0,0603 Euro cent 10.53% (0,0548 Euro cent)* (+10 %)
Investment cost 16,357,320 € (-20 %) %13.9 24,535,980 € %2.62 (+20%) Production expenses 657,647 € (-20 %) &8.54 953,449€ (+20%) %4.61 Electricity 36.091.200 kWh (-20 %) - %0.21 54.136.800 kWh %15.02 production (yearly) (+20%) Electricity price 0,0438 Euro cent (-20 %) -%0.21 0,0657 Euro cent( %15.02
25 IRR calculation spreadsheet is available to the DOE.
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(0,0548 Euro cent)* +20 %)
* Average electricity price is 0,0548 Euro cent. 15 years price is 0,0537 and 5 years price is 0,0581 Euro cent incuding benefit contributions from tower. (0,0548= (0,0581*5)+(0,0537*15) )/20
The project is estimated to supply grid as 49,218 MWh per annum according to P 50 valueWith this generation amount, the Internal Rate of Return (IRR) is calculated as 10.15%. But the bank wanted to use p75 value as the electricity production value for this project because the P75 is the right approach for estimation of it.
Outcome of Step 2 The sensitivity analysis shows that the equity IRR of the proposed project does not overcome the financial benchmark despite favourable conditions.
The sensitivity analysis further substantiates that the project activity is not a feasible alternative and so additional.
Step 3: Barrier Analysis
The analysis is not applied.
Step 4: Common Practice Analysis
According to “Tool for the demonstration and assessment of additionality” version 07.0.0, the proposed project activity apply the measures listed in the definitions section of the tool. So, Sub-step 4a is applied.
Sub-step 4a: The proposed VER project activity(ies) applies measure(s) that are listed in the definitions section
EB 69 Report Annex 8, “The Guidelines on Common Practice” version 02.0 is applied for the proposed project activity.
Step 1: Calculate applicable capacity or output range as +/-50% of the total design capacity or output of the proposed project activity.
The installed capacity of the proposed project activity is 18 MW. Therefore, the lower limit of the applicable output range is 9 MW and upper limit is 27 MWe.
Step 2: Identify similar projects (both CDM and non-CDM) which fulfil all of the following conditions:
(a) The projects are located in the applicable geographical area; (b) The projects apply the same measure as the proposed project activity; (c) The projects use the same energy source/fuel and feedstock as the proposed project activity, if a technology switch measure is implemented by the proposed project activity; (d) The plants in which the projects are implemented produce goods or services with comparable quality, properties and applications areas (e.g. clinker) as the proposed project plant; (e) The capacity or output of the projects is within the applicable capacity or output range calculated in Step 1;
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(f) The projects started commercial operation before the project design document (CDM-PDD) is published for global stakeholder consultation or before the start date of proposed project activity, whichever is earlier for the proposed project activity.
The power plant projects connected to Turkey’s national electricity grid as of end of 2012 may be seen in Annex 1 of TEIAS Capacity Projection Report (2013-2017).26 Step 3: Within the projects identified in Step 2, identify those that are neither registered CDM project activities, project activities submitted for registration, nor project activities undergoing validation. Note their number Nall.
From the list obtained from TEIAS Capacity projection Report (2013-2017), it has been understood that there are initially 632 projects. When projects registered as VER projects and projects under validation are excluded, the new list entails 547 projects. Satisfying the steps 2 and 3, Nall is 2.
Step 4: Within similar projects identified in Step 3, identify those that apply technologies that are different to the technology applied in the proposed project activity. Note their number Ndiff.
According to the guidance on common practice, classification of different technologies has been realised taking into account the main criteria “energy source/fuel”, “size of installation (power capacity)” and “Investment climate in the date of investment decision (subsidies or other financial flows, promotional policies and legal regulations)”. The power plants which have different fuel types such as hydro, lignite, natural gas, fuel oil, coal etc., are accepted as different technologies. Also, the power plants which have an installed capacity of 15 MW are considered as different technologies, as they are small-scale projects according to CDM. In addition, the company types of the power plants are considered while defining the different power plants because different company types have different promotional policies, legal regulations, subsidies and other financial flows. As a result, when both the fuel types of the power plants and the company types are taken into account, the number of companies that apply technologies different that the technology applied in the proposed project activity, Ndiff, is 2.
Step 5: Calculate factor F=1-Ndiff/Nall representing the share of similar projects (penetration rate of the measure/technology) using a measure/technology similar to the measure/technology used in the proposed project activity that deliver the same output or capacity as the proposed project activity.
The factor F defined in the guideline is calculated with the formula below:
F = 1 – Ndiff/Nall
F = 1 – 2/2 = 0.0 (0%)
Nall-Ndiffer is 2 and the factor F is lower than 0.2, the proposed project activity is not a “Common Practice”.27
Outcome of Step4
The project activity is not regarded as “common practice”, then the proposed project activity is additional.
B.6. Emission reductions
26 http://www.teias.gov.tr/YayinRapor/APK/projeksiyon/KAPASITEPROJEKSIYONU2013.pdf 27 Common Practice Analysis is available to the DOE.
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B.6.1. Explanation of methodological choices
According to the methodology ACM0002 “Consolidated baseline methodology for grid-connected electricity generation from renewable sources” version 14.0.0, 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 calculated as follows:
BEy = EGPJ,y * EFgrid,CM,y
Where:
BEy = Baseline emissions in year y (tCO2/yr) EGPJ,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) EFgrid,CM,y = Combined margin CO2emission factor for grid connected power generation in year y calculated using the latest version of the T”ool to calculate the emission factor for an electricity system” (tCO2/MWh)
Calculation of EGPJ,y
The calculation of EGPJ,y is different for (a) greenfield plants; (b) retrofits and replacements and; (c) capacity additions. Since the proposed project activity falls under the description greenfield plants, the following method has been adopted:
Greenfield renewable energy power plants:
EGPJ,y = EG facility,y
Where: EG PJ,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) EG facility,y = Quantity of net electricity generation supplied by the project plant/unit to the grid in year y (MWh/yr)
Calculation of EFgrid,CM
As referred in ACM0002 “Consolidated baseline methodology for grid-connected electricity generation from renewable sources” (version 14.0.0), EFgrid,CM is calculated according to the “Tool to calculate the emission factor for an electricity system” version 04.0.0.
This tool provides the following steps to calculate combined margin (CM) emission factor:
Step 1. Identify the relevant electric systems; Step 2. Choose whether to include off-grid power plants in the project electricity system (optional); Step 3. Select a method to determine the operating margin (OM); Step 4. Calculate the operating margin emission factor according to the selected method; Step 5. Calculate the build margin (BM) emission factor; Step 6. Calculate the combined margin (CM) emissions factor.
Step 1. Identify the relevant electric systems
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According to the “Tool to calculate the emission factor for an electricity system” (version 04.0.0), a project electricity system has to be defined by the spatial extent of the power plants that are physically connected through transmission and distribution lines to the project activity and that can be dispatched without significant transmission constraints.
Similarly, a connected electricity system, e.g. national or international, is defined as 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.
The transmission lines in Turkey are operated by TEİAŞ (Turkish Electricity Transmission Co), which is a state owned company. The grid is 48.971 km long and constitutes of 606 transformer stations with a total transformer capacity of 98,852 MVA and 10 interconnections to neighbour countries. 28 The interconnected grid system is operated continuously and there are no electricity price differences throughout the regions.29 For this reason, the relevant electric power system is defined as the national grid system of Turkey.
Step 2. Choose whether to include off-grid power plants in the project electricity system (optional)
According to the applicable tool, Project Participants may choose between the following two options 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.
Option I has been chosen for the project activity and therefore only grid power plants are included in the calculation.
Step 3. Selection of an operating margin (OM) method
According to “Tool to calculate the emission factor for an electricity system” (version 03.0.0), the calculation of the operating margin emission factor (EF grid, OM, y) is based on one of the following methods:
(a) Simple OM; or (b) Simple adjusted OM; or (c) Dispatch data analysis OM; or (d) Average OM.
Option (a) Simple OM method has been selected for calculation of the operating margin emission factor. This choice is applicable since low-cost/must-run resources constitute less than 50% of total grid generation. The low-cost/must-run resources include hydro, geothermal, wind, low-cost biomass, nuclear and solar power generation.
The share of the installed capacity of renewable energy sources excluding hydro power is 2.9% of the total electricity generation and is therefore not taken into consideration. There is no indication that coal is used as a must-run and no nuclear energy plants are located in Turkey. This makes wind power as the
28 The emission factor from neighbouring countries is taken as 0 tCO2eq/MWh for determining the OM. 29 http://www.teias.gov.tr/, official webpage of TEIAŞ (Turkish Electricity Transmission Co.)
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Table.11. Breakdown by sources of the electricity generation from the Turkish grid, 201230 Generation (GWh) Liquid Geothermal Years Coal Total Natural Gas Wastes Hydro Total Total +Wind 2008 57,715.60 7,518.50 98,685.30 219.90 33,269.80 1,008.90 198,418.00 2009 55,685.10 4,803.53 96,094.70 340.10 35,958.40 1,931.10 194,812.93 2010 55,046.40 2,180.00 98,143.70 457.50 51,795.50 3,584.60 211,207.70 2011 66,217.90 903.60 104,047.60 469.20 52,338.60 5,418.20 229,395.10 2012 68,013.10 1,638.70 104,499.20 720.70 57,865.00 6,760.10 239,496.80
For the simple OM, the emissions factor can be calculated using either of the two following data vintages:
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. Ex post option: If the ex post option is chosen, the emission factor is determined for the year in which the project activity displaces grid electricity, requiring the emissions factor to be updated annually during monitoring.
The ex ante option has been selected for the proposed project activity. Data from the period 2011-2012 has been obtained for calculating the three year average. This period is standing for the most recent data available at the time of submission of the PDD to DOE.
Step 4. Calculate the operating margin emission factor according to the selected
The simple OM emission factor is calculated as the generation-weighted average CO2 emissions per unit net electricity generation (tCO2e/MWh) of all generating power plants serving the system, not including low-cost / must-run power plants / units. It may be calculated:
Option A: Based on the net electricity generation and a CO2 emission factor of each power unit;
Option B: Based on the total net electricity generation of all power plants serving the system and the fuel types and total fuel consumption of the project electricity system.
Since the fuel consumption and the average efficiency data for each power plant/unit are not available Option B is used for simple OM calculation.
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:
30 http://www.teias.gov.tr/TürkiyeElektrikİstatistikleri/istatistik2012/istatistik%202012.htm
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FC NCV EF i,,,, y i y CO2 i y i EFgrid,, OMsimple y EGy
Where:
EFgrid,OMsimple,y = Simple operating margin CO2 emission factor in year y (t CO2/MWh) FCi,y = Amount of fuel type i consumed in the project electricity system in year y (mass or volume unit) NCVi,y = Net calorific value (energy content) of fuel type i in year y (GJ/mass or volume unit) EFCO2,i,y = CO2 emission factor of fuel type i in year y (t CO2/GJ) EGy = 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) i = All fuel types combusted in power sources in the project electricity system in year y y = The relevant year as per the data vintage chosen in step 3
Step 5. Calculate the build margin (BM) emission factor
In terms of vintage of data, project participants can choose between one of the following two options:
Option 1: For the first crediting period, calculate the build margin emission factor ex ante based on the most recent information available on units already built for sample group m at the time of CDM-PDD submission to the DOE for validation. For the second crediting period, the build margin emission factor should be updated based on the most recent information available on units already built at the time of submission of the request for renewal of the crediting period to the DOE. For the third crediting period, the build margin emission factor calculated for the second crediting period should be used. This option does not require monitoring the emission factor during the crediting period.
Option 2: For the first crediting period, the build margin emission factor shall be updated annually, ex post, including those units built up to the year of registration of the project activity or, if information up to the year of registration is not yet available, including those units built up to the latest year for which information is available. For the second crediting period, the build margin emissions factor shall be calculated ex ante, as described in Option 1 above. For the third crediting period, the build margin emission factor calculated for the second crediting period should be used.
Project Proponent chooses Option 1 in terms of vintage of data for the proposed project activity:
The sample group of power units m used to calculate the build margin should be determined as per the following procedure, consistent with the data vintage selected above:
(a) Identify the set of five power units, excluding power units registered as VER project activities, that started to supply electricity to the grid most recently (SET5 units) and determine their annual electricity generation (AEGSET-5-units, in MWh); (b) Determine the annual electricity generation of the project electricity system, excluding power units registered as VER project activities (AEGtotal, in MWh). Identify the set of power units, excluding power units registered as VER project activities, that started to supply electricity to the grid most recently and that comprise 20 per cent of AEGtotal (if 20 per cent falls on part of the generation of a unit, the generation of that unit is fully included in the calculation) (SET≥20 per cent) and determine their annual electricity generation (AEGSET-≥20 per cent, in MWh);
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(c) From SET5-units and SET≥20 per cent select the set of power units that comprises the larger annual electricity generation (SETsample);
Identify the date when the power units in SETsample started to supply electricity to the grid. If none of the power units in SETsample started to supply electricity to the grid more than 10 years ago, then use SETsample to calculate the build margin.
The most recent information available belongs to 2012 and based on TEIAŞ statistics which is the official information source for the grid31. Since the data of 2012 does not provide any information about the commissioning dates of the plants, the set of five power units that started to supply electricity to the grid most recently cannot be determined. Therefore, SET≥20% is selected as the set of power units that 32 comprises the larger annual electricity generation (SETsample).
The built margin (BM) emission factor is the generation-weighted average emission factor (tCO2/MWh) of all power units m during the most recent year y for which power generation data is available 33, calculated as follows:
EGm,,, y EF EL m y m EFgrid,, BM y EGmy, m
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) EFEL,m,y = CO2 emission factor of power unit m in year y (t CO2/MWh) m = Power units included in the build margin y = Most recent historical year for which electricity generation data is available
According to, “Tool to calculate the emission factor for an electricity system” (version 04.0.0), the CO2 emission factor of each power unit m (EFEL,m,y) should be determined as per the guidance from the tool in step 4 for simple OM, using options A1, A2 or A3, using for y the most recent historical year for which power generation data is available, where m is the power units included in the build margin.
As plant specific fuel consumption data is not available for Turkey, option A2 has been selected for the calculation of the CO2 emission factor of each power unit m (EFEL,m,y) as follows:
Where:
EFELm,y = CO2 emission factor of the power unit m in year y (tCO2/MWh) EFCO2,m,i,y = Average CO2 emission factor of fuel type i used in power unit m in year y (tCO2/GJ) ηm,y = Average net energy conversion efficiency of power unit m in year y (ratio) m = All power units serving the grid in year y except low-cost/must-run power units
31 http://www.teias.gov.tr/TürkiyeElektrikİstatistikleri/istatistik2012/istatistik%202012.htm 32 The excel spreadsheet is available to the DOE. 33 The most recent year for which power generation data is available is 2011. Reference: TEIAŞ Generation and Transmission Statistics www.teias.gov.tr
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y = The most recent year for which power generation data is available at the time of submission of the VER-PDD to the DOE for validation (ex-ante option)
Where several fuel types are used in the power unit, the lowest CO2 emission factor for EFCO2,m,i,y has been used.
Step 6. Calculate the combined margin emissions factor
According to the applicable methodological tool, the calculation of the combined margin (CM) emission factor (EFgrid, CM) is based on one of the following methods:
(a) Weighted average CM; or (b) Simplified CM.
The Project Proponent chooses option (a), weighted average CM.
The combined margin emissions factor is calculated as follows:
EFgrid,,,,,, CM y EF grid OM y w OM EF grid BM y w BM
Where:
EFgrid,BM,y = Build margin CO2 emission factor in year y (t CO2/MWh) EFgrid,OM,y = Operating margin CO2 emission factor in year y (t CO2/MWh) wOM = Weighting of operating margin emissions factor (per cent) wBM = Weighting of build margin emissions factor (per cent)
According to the “Tool to calculate the emission factor for an electricity system” (version 04.0.0), the default weights for the operating margin and build margin emission factors for wind power generation is defined as: wOM=0.75 wBM=0.25 for the first crediting period.
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B.6.2. Data and parameters fixed ex ante
Data / Parameter ID.1 / EGgross Unit MWh Description Gross electricity production by fossil fuel power sources (2010-2012) Source of data TEIAS (Turkish Electricity Transmission Company) www.teis.gov.tr. The distribution of gross electricity generation by primary energy resources and the electricity utilities in Turkey (2010, 2011, 2012). Value(s) applied Please see calculations of emission factor (Section B.6.1.) Choice of data TEIAS, the Turkish Electricity Transmission Company is the official or source for the related data, thus providing the most up-to-date and Measurement methods accurate information available. and procedures Purpose of data Calculation of baseline emissions Additional comment -
Data / Parameter ID.2 / FCi,y Unit tonnes (m3 for gaseous fuels) Description Amount of fossil fuel type i consumed in the project electricity system by generation sources in year y (2010-2012) Source of data TEIAS (Turkish Electricity Transmission Company) www.teis.gov.tr . Fuels consumed in thermal power plants in Turkey by the electricity utilities (2010-2012) Value(s) applied Please see calculations of emission factor (Section B.6.1) Choice of data TEIAS, the Turkish Electricity Transmission Company is the official or source for the related data, thus providing the most up-to-date and accurate Measurement methods information available. and procedures Purpose of data Calculation of baseline emissions
Additional comment -
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Data / Parameter ID.3 / NCVi,y Unit GJ/tonnes (m3 for gaseous fuels) Description Net calorific value (energy content) of fossil fuel type i in year y Source of data Calculated based on TEIAS (Turkish Electricity Transmission Company) www.teis.gov.tr. Heating values of fuels consumed in thermal plants in Turkey by the electricity utilities (2010-2012)
Value(s) applied Please see calculations of emission factor (Section B.6.1) Choice of data TEIAS, Turkish Electricity Transmission Company is the official source or for the related data, hence providing the most up-to-date and accurate Measurement methods information available. and procedures Purpose of data Calculation of baseline emissions Additional comment -
Data / Parameter ID.4 / EFC02,i,y
Unit tCO2/GJ
Description CO2 emission factor of fossil fuel type i used in power unit m in year y Source of data IPCC default values at the lower limit of the uncertainty at a 95% confidence interval as provided in table 1.4 of Chapter 1 of Volume 2 (Energy) of the 2006 IPCC Guidelines for National Greenhouse Gas Inventory http://www.ipcc-nggip.iges.or.jp/public/2006gl/index.htm Value(s) applied Please see calculations of emission factor (Section B.6.1) Choice of data There is no information on the fuel specific default emission factor in or Turkey, hence, IPCC values has been used as referred in the “Tool to Measurement methods calculate the emission factor for an electricity system (version 2.2)”. and procedures Purpose of data Calculation of baseline emissions Additional comment -
Data / Parameter ID.5 / EGm,y Unit MWh Description Net electricity generated by power plant/unit m Source of data TEIAS (Turkish Electricity Transmission Company) www.teis.gov.tr . Generation units put into operation in 2010, 2011, 2012
Value(s) applied Please see Appendix 4 Choice of data Once for each crediting period using the most recent three historical years or for which the data is available at the time of submission of the PDD to the Measurement methods DOE for validation. and procedures Purpose of data Calculation of baseline emissions Additional comment -
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Data / Parameter ID.6 / ηm,y Unit % Description Average net energy conversion efficiency of power unit m in year y Source of data “Appendix 1, Default efficiency factors for power plants” of “Tool to calculate the emission factor for an electricity system” version 04.0.0. Value(s) applied See calculations of emission factor (Section B.6.1) Choice of data The average values of thermal plants in Turkey are taken from “Tool to or calculate the emission factor for an electricity system” 04.0.0. Measurement methods and procedures Purpose of data Calculation of baseline emissions Additional comment -
B.6.3. Ex ante calculation of emission reductions
Calculation of the operating margin emission factor
The amount of fuel consumption (FCi,y) is taken from website of TEIAS for the calculation of the Simple OM. The fuel consumption values for 2010-2012 may be seen in Table 12:
Table 12: Fuel consumption of generation sources connected to the grid (2010-2012)34 Units 2010 2011 2012 Total Natural Gas 1000m3 21,783,414 22,804,587 23,090,121 67,678,122 Lignite tonnes 56,689,392 61,507,310 55,742,463 173,939,165 Coal tonnes 7,419,703 10,574,434 12,258,462 30,252,599 Fuel Oil tonnes 891,782 531,608 564,796 1,988,186 Diesel Oil tonnes 20,354 15,047 176,379 211,780 Lpg tonnes 0 0 0 0 Naphta tonnes 13,140 0 0 13,140
Turkish specific net calorific values (NCVi,y) values for fossil fuel types have been calculated, using data from the IPCC Guidelines for National Greenhouse Gas Inventory for the emission factor of the fossil fuel types (EFCO2,i,y).
The NCV and emission factors may be seen in Table 13:
Table 13: NCV and emission factor of fossil fuel type35
NCVi (GJ/tonnes) EFCO2,i (tonnes/GJ) 2010 2011 2012 Natural Gas 37,381 30,742 30,280 0.054 Lignite 7,131 7,298 7,029 0.091 Coal 22,315 22,793 24,342 0.093 Fuel Oil 40,231 41,584 41,698 0.075 Diesel Oil 43,087 43,128 44,721 0.073 Lpg 0 0 0 0.061 Naphta 33,486 0 0 0.069
34 http://www.teias.gov.tr/TürkiyeElektrikİstatistikleri/istatistik2012/istatistik%202012.htm 35 http://www.teias.gov.tr/TürkiyeElektrikİstatistikleri/istatistik2012/istatistik%202012.htm
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The electricity delivered to the grid by all power sources serving the system, not including low- cost/must-run power plants/units (EGgross,y) is obtained from TEIAS (Turkish Electricity Transmission Company). Table 14 shows the gross electricity production for 2010-2012 produced by fossil fuel power sources:
Table 14: Gross electricity generation by fossil fuel power sources 2010-201236
EGgross,y (MWh) 2010 2011 2012 Total Natural Gas 98,143,700 104,047,600 104,499,200 306,690,500 Lignite 35,942,100 38,870,400 34,68,.900 74,812,500 Coal 19,104,300 27,347,500 33,324,200 79,776,000 Fuel Oil 2,180,000 900,500 981,300 4,061,800 Diesel Oil 4.249 3,100 657,400 660,504 Lpg 0 0 0 0 Naphta 31,937 0 0 31,937
To calculate the net electricity fed into the grid by specific fuel sources, relation between overall gross/net electricity generation data is calculated. The electricity consumption of the power plants is included in the gross electricity production. This relation is derived in in Table 15:
Table 15: Relation between net and gross electricity generation 2010-2012 2010 2011 2012 Gross generation (MWh) 211,090,300 229,395,100 239,496.4 Net generation (MWh) 203,046,100 217,557,700 227,703.3 Relation 96.2% 94.8% 95.1%
The net electricity delivered to the grid by the fossil fuel plants (EGnet,y) is calculated in Table 16 The calculation of EFgrid,OM,y requires the inclusion of electricity imports with an emission factor of 0 tCO2/MWh. Therefore, the imports in the electricity production has been added.
Table 16: Net electricity generation fossil fuel power plants and electricity imports 2010- 201237 2010 2011 2012 Total Gross electricity generation (MWh) 155,370,105 171,638,300 174,871,700 501,880,105 Net electricity generation 149,449,269 162,781,305 166,260,800 478,491,374 EGnet,y (MWh) Electricity imports 1,143,800 4,555,800 5,827,000 11,526,600
Electricity supplied to grid EGy 150,593,110 167,428,770 172,087,800 490,109,680
Based on the above values, the simple operating margin CO2 grid emission factor (EFgrid,OMsimple,y) calculated through equation is 0.624 tCO2/MWh.
Calculation of the build margin emission factor
The average CO2 emission factor of fuel types (EFCO2,m) and the average net energy conversion efficiency of the power plants (ηm,y) used for the calculation of emission factor of the power units (EFEL,m,y) are presented in Table 17:
Table 17: Emission factors of the power units
36 http://www.teias.gov.tr/TürkiyeElektrikİstatistikleri/istatistik2012/istatistik%202012.htm 37 http://www.teias.gov.tr/TürkiyeElektrikİstatistikleri/istatistik2012/istatistik%202012.htm
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Average emission Average conversion Emission factor of the factor EFCO2,m,i,y efficiency ηm,y power unit EFEL,m,y (tCO2/GJ) (tCO2/MWh) Natural Gas 0.054 60% 0.324 Lignite 0.091 39% 0.840 Coal 0.093 39% 0.858 Fuel Oil 0.075 46% 0.587 Diesel Oil 0.073 46% 0.571 Naphta 0.069 60% 0.414 Hydro n.a. n.a. 0 Wind n.a. n.a. 0
The data on the electricity generated and delivered to the grid by power units (EGm,y) are presented in the below table.
Table 18: Electricity generated by the power units included in the build margin calculation
EG (MWh) 2011 2012 m,y Gross generation (MWh) 21,600,770 40,837,320
Gross Elect. Excluding VERs 18,600,710 37,434,000 (MWh)
The build margin emission factor EFgrid,BM,y calculated through equation is 0.1945 tCO2/MWh.
Calculating the combined margin emission factor
The combined margin emission factor EFgrid,CM,y calculated through equation is 0.516 tCO2/MWh
B.6.4. Summary of ex ante estimates of emission reductions Baseline Project Leakage Emission reductions Year emissions emissions (t CO2e) (t CO2e) (t CO2e) (t CO2e) 19415 0 0 19,415 01.03.2015-31.12.2015 2016 23,299 0 0 23,299 2017 23,299 0 0 23,299 2018 23,299 0 0 23,299 2019 23,299 0 0 23,299 2020 23,299 0 0 23,299 2021 23,299 0 0 23,299 01.01.2022-31.02.2022 3,883 0 0 3883 Total 163,092 163,092 Total number of 7 crediting years Annual 23,299 average over the crediting period
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B.7. Monitoring plan B.7.1. Data and parameters to be monitored
Data / Parameter EGfacility,y Unit MWh/yr Description Quantity of net electricity supplied to the grid in year y Source of data Meter reading records Value(s) applied 45,114 Measurement methods The net electricity generation supplied to the grid will be measured and procedures continuously by TEAIS meters (both main and spare) and recorded monthly. Monitoring frequency Please see B.7.3. for more detailed description of the monitoring plan. QA/QC procedures Measurements are undertaken using energy meters. Concerning metering system accuracy, project participants have to comply with relevant national legislation. The project must ensure that the metering devices are in line with the technical requirements which are set out by the Communiqué for Metering Devices to be used in the Electricity Market 38 , which describes the minimum accuracy requirement the metering devices have to fulfil, which are categorized according to the installed capacity. Maintenance and calibration of TEİAŞ meters will be carried out according to the System Usage Agreement. The meters will be calibrated every year39 the instructions of the manufacturer or legal requirements. Since TEİAŞ meters are sealed by TEİAŞ, the project proponent cannot intervene with the devices.40 The net electricity export/supplied to a grid is the difference between the measured quantities of the grid electricity export and the import. Data measured by meters will be crosschecked with the PMUM records. Purpose of data Calculation of baseline emissions Additional comment -
B.7.2. Sampling plan
N/A
B.7.3. Other elements of monitoring plan
The Project Owner will be responsible to implement the monitoring report according to the Gold Standard rules and procedures. The manager of the plant will provide the necessary documents during verification.
38 http://www.epdk.gov.tr/index.php/elektrik-piyasasi/mevzuat?id=68 39 http://eud.teias.gov.tr/SKAM/SKAornek.pdf 40 http://www.epdk.org.tr/documents/elektrik/mevzuat/yonetmelik/elektrik/dengeleme_uzlastirma/DUYson.doc http://www.mevzuat.gov.tr/MevzuatMetin/1.5.3516.doc
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According to the Turkish Law and Regulations, the methods of monitoring the net electricity fed to the grid and quality control and assures are explained below:
Monitoring data is collected in accordance with the agreement done between the project owner and Turkish Electricity Distribution Company (TEDAS) which provides the infrastructure for the connection to the national grid. The metering system is defined in the agreement as two groups: main meter and spare meter. The design of the metering system is checked and approved by TEDAS before commissioning of the plant. The technical specifications of the power meters should be in line with Measure and Metering Devices Regulation by Ministry of Industry and Trade. In addition, the Communiqué for Power Meters announced by Energy Market Regulations Authority (EMRA) requires all meters to be in line with either Turkish Standards Institution or International Electrotechnical Commissions Standards. The meters are placed at the point the electricity is fed to the grid and sealed on behalf of the both parties. This prevents any intervention and assures the accuracy and quality of the measurements. All requirements and specifications of the meters will be done according to Communique on the counter to be used in the Electricity Market by Energy Market Regulatory Authority on 22.04.201141
Data will be stored electronically, during the crediting period and at least two years after the last issuance of credits for the wind farm project activity in the concerning crediting period. The Project Participant will be responsible for storage of data received from the measuring devices.
The main and spare meter readings are recorded monthly and cross-checked whether calibration is required. The capacity of the transmission line connected is 31.5 kVA, the accuracy class for power meters have been defined in the Communiqué for Power Meters as 0.2S class. The calibration will be implemented in accordance with the related standard procedures. The periodical maintenance is under the responsibility of TEDAS and has been fixed as once in 10 years.
The Project aims to create local employment opportunities in the project region in a sustainable way. The Project proponent prefers to prioritize personnel from the project region, which is defined as a Gold Standard indicator to be verified each year. The proposed project will provide local employment both during the construction and operational phases. It is planned to hire 14 employees temporarily during the construction and about 7 or 9 employees permanent during the operation of the plant. Roles and responsibilities have been summarized in the following chart.
Ova Wind Farm Engineer Electrical Engineer / 1 person
Technician Security (3 or 4 person) (3 or 4 person)
41 http://www.epdk.gov.tr/index.php/elektrik-piyasasi/mevzuat?id=68
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SECTION C. Duration and crediting period C.1. Duration of project activity C.1.1. Start date of project activity
15/06/201442 Turbine contract signing date has been taken as investment decision and start date of project activity.
C.1.2. Expected operational lifetime of project activity
25 years and 0 months
C.2. Crediting period of project activity C.2.1. Type of crediting period
Renewable crediting period will be used.
C.2.2. Start date of crediting period
The first crediting period starts on 01/03/2015.
C.2.3. Length of crediting period
7 years and o months, which is planned to be renewed twice.
SECTION D. Environmental impacts D.1. Analysis of environmental impacts
As parallel with the requirements of “Regulation on Environmental Impact Assessment”, the proposed project has been exempted from performing an Environmental Impact Assessment.43
D.2. Environmental impact assessment
The proposed project has been exempted from performing an Environmental Impact Assessment.
SECTION E. Local stakeholder consultation E.1. Solicitation of comments from local stakeholders
The stakeholders to the project activity was defined jointly by the project owner and Rüzgar Danışmanlık, who is the consultant to the GS project cycle, taking into account the characteristics and possible impacts of the project activity.
The stakeholders from all categories suggested by Gold standard were invited to the meeting. Generally the preferred means for invitation was through e-mails. Most of the stakeholders were invited through emails, letters and phone calls followed by the emails and letters where possible.
All local people were informed about the meeting in advance by announcements, invitation posters and newspaper announcement and some of them were invited face to face to the meeting. The meeting was also announced on a local newspaper which name is Hedef and Cephe Newspapers on 20-21.11.2013.
42 Turbine contract signing date. 43 Exemption letter is available to the validating DOE.
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E.2. Summary of comments received
The local stakeholder meeting was held on 13th of December 2013 in Bıçakçı Coffeehouse, Ödemiş District, İzmir province. All local people were informed about meeting in advance by local announcements. Before the meeting the questionnaire regarding the sustainable development indicators and monitoring of the indicators along with the explanation of the indicators, meeting evaluation forms and non-technical description of the Ova project have been provided to the stakeholders. In general the participation to the meeting was good with more than 70 people.
During the meeting some questions were raised by participants, which were answered by project participant and consultant. The questions and answers are given in below section (ii. Assessment of comments). One of the most important topics raised during meeting was what will be happen their lands during the operation period. The concern of local people was answered by project developer and consultant. The project owner stated that after the construction, during the operations period, they will build fences around the turbines and the areas other than this area can be used by the villagers. The Q&A session and the questionnaires aimed at discussing the sustainable development indicators as identified by the Gold Standard.
At the end of the meeting, continuous input mechanism discussed and the book was given to the head of Bıçakçı village with a protocol. All local stakeholders agreed on this mechanism. During this part of the meeting, the contact details of the project owner, project proponent and the GS Regional Manager’s were shared with the the participants and also head of Bıçakçı village. Local stakeholders were encouraged to give feedback about the project.
As no females participated the meeting, Çağla Balcı Eriş (Rüzgar Danışmanlık)interviewed women separately after the official meeting in a villager’s house. They did not disclose any negative ideas about the project.
To the meeting for women, only eight adults and one child attended. More women were expected to participate but they did not show up in spite of the efforts of project proponent and project owner. After the the environmental effects of the project, carbon certification, the Gold Standard process and climate change was explained to the women by the Çağla Balcı Eriş (Rüzgar Danışmanlık), ladies were asked to give their opinions about the project. They also commented on their expectations about employment opportunities and asked about the requirements. They were informed in the same lines as the main meeting. This meeting was closed also by a general support from womens.
The documents including the LSC report, the GS Passport and the PDD has been delivered to the stakeholders who have been selected as stakeholders to the project activity. The main communication method has been through e-mails and delivery of several hard copies of the mentioned documents for those who don’t have an email address (specifically the locals) to the headman of the Bıçakçı and Sarıçam villages.
The feedback round has started on 21.03.2014 with sending out the documents to the stakeholders and no feedback has been received till 21.05.2014.The beginning of two months Stakeholder Feedback Round has been announced from the headman of Bıçakçı and Sarıçam villages. This public announcement emails and documents will contain information such as location of available these documents, the procedure to commit comments, timing and the contact's details.
In addition, all these documents have been made available under the GS registry webpage (www.markit.com) as required by GS..
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More details of the Stakeholders Consultation Process may be found in GS LSC Report and GS Passport.
E.3. Report on consideration of comments received
Detailed information of the Stakeholders Consultation Process may be found in GS LSC Report and GS Passport. SECTION F. Approval and authorization
N/A
- - - - -
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Appendix 1: Contact information of project participants
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Organization name: AYRES Elektrik Üretim A.Ş. Street/P.O.Box: Akçeşme Mah. Çiğdem Cad. No:1 Building: ---- City: Merkez/DENİZLİ State/Region: Aegean Region Postcode/ZIP: 20000 Country: TÜRKİYE Telephone: +90 258 372 25 25 FAX: +90 258 372 25 26 E-Mail: [email protected] URL: ---- Represented by: Özge Yastı Title: Account Manager-Board Member Salutation: Mrs Last name: Yastı Middle name: ---- First name: Özge Department: Finance Mobile: +90 532 310 69 39 Direct FAX: +90 258 372 25 26 Direct tel: +90 258 372 25 25 Personal e-mail: [email protected] Organization name Rüzgar Danışmanlık Street/P.O. Box Göztepe Mah. Birinci Orta Sok. Building Nursaray Apt.No:1 D:22 City Üsküdar Istanbul State/Region N.A Postcode 34676 Country Turkey Telephone +90 216 3550968 Fax +90 216 3327679 E-mail [email protected] Website www.ruzgardanismanlik.net Contact person Title Managing Consultant Salutation Last name Balcı Eriş Middle name First name Çağla Department Management Mobile +90 532 220 85 43 Direct fax +90 216 332 76 79 Direct tel. +90 216 355 09 68
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Personal e-mail [email protected]
Appendix 2: Affirmation regarding public funding
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Appendix 3: Applicability of selected methodology
------
Appendix 4: Further background information on ex ante calculation of emission reductions44
2012
Index Added Installed Added Electricity Company (fuel type) Capacity (MW) Generation (GWh)
Akköy II HES (Akköy Enerji A.Ş.) Hydro 114.84 131.49 ARCA HES (GÜRSU EL.) Hydro 16.35 65.00 AYRANCILAR HES MURADİYE EL.) Hydro 41.50 749.39 BALKUSAN I HES (KAREN) Hydro 13.00 40.00 BALKUSAN II HES (KAREN) Hydro 25.00 80.00 BANGAL REG. KUŞLUK HES(KUDRET EN.) Hydro 17.00 56.00 ESENDURAK (MERAL EL.) Hydro 9.33 43.00 GÖKGEDİK (UHUD) HES Hydro 24.266 100.00 MENGE BARAJI VE HES (ENERJİSA) Hydro 44.7 102.00 NİKSAR HES Hydro 40.2 248.00 TUZLAKÖY SERGE REG. VE HES Hydro 7.1 21.00
44 http://www.teias.gov.tr/YayinRapor/APK/projeksiyon/KAPASITEPROJEKSIYONU2013.pdf
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YAMANLI III GÖKKAYA Hydro 28.5 105.00 YAMANLI III HİMMETLİ Hydro 27 100.00 CEYHAN HES (BERKMAN HES- ENOVA) Hydro 12.6 50.33 HORYAN HES Hydro 5.68 23.00 BALIKESİR RES (BARES ELEKTRİK ÜRETİM A.Ş.) Wind 112.8 434.00
BOZYAKA RES (KARDEMİR) Wind 12.00 38.00
İNNORES ELEK. YUNTDAĞ Wind 5.00 20.26 KARADAĞ RES (GARET EN.) Wind 10 34.00 DAĞPAZARI RES (ENERJİ SA) Wind 39.0 120.00 AKSU RES (AKSU TEMİZ EN.) Wind 72 216.00 KAYADÜZÜ RES (BAKTEPE EN.) Wind 39 129.00 KOZBEYLİ RES (DOĞAL EN.) Wind 20 70.00 METRİSTEPE (CAN EN.) Wind 39.00 85.00 POYRAZ RES Wind 50.00 230.00 SAMURLU RES(DOĞAL EN.) Wind 22.00 70.00 SOMA RES Wind 24.00 82.23 SÖKE ÇATALBÜK RES (ABK EN.) Wind 30.00 110.00 ITC-KA ENERJİ ADANA (BİYOKÜTLE) Biogas 4.24 31.80 KOCAELİ ÇÖP Biogas 2.26 18.00 Akköprü (Dalaman) Hydro 57.50 171.50 Akköy - Espiye HES (Koni İnşaat San. A.Ş.) Hydro 8.91 40.00 Alabalık REG.ve HES Santrali I-II (Darboğaz Elk.Ür. San.) Hydro 13.84 41.00 ANAK HES(KOR-EN EL.) Hydro 3.76 15.00 ARAKLI I REG.(YÜCEYURT EN.) Hydro 13.07 50.00 ARPA HES (MCK EL.) Hydro 32.41 78.00 AVCILAR HES Hydro 16.74 49.00 AYANCIK HES (İLK EL.) Hydro 15.60 65.00 BAĞIŞTAŞ II (AKDENİZ EL.) Hydro 32.40 122.00 ERİK HES (ELEKTRİK ÜRETİM A.Ş.) Hydro 6.48 34.00 FEKE I (AKKUR EN.) Hydro 29.4 117.00 FINDIK I HES(ADV) Hydro 11.25 48.00 GEMCİLER REG.(BOZTEPE) Hydro 7.98 35.00 GÜDÜL II HES (YAŞAM ENERJİ) Hydro 4,880 19,918.37 GÜLLÜBAĞ BARAJI VE HES (SENENERJİ) Hydro 96 384.00 GÜNDER REG. VE HES Hydro 28.2 84.00 HORU REG VE HES Hydro 8.48 34.00 KARTALKAYA HES (SIR ENERJI) Hydro 8 27.00 KAYAKÖPRÜ II HES (ARSAN ENERJİ) Hydro 10.2 36.00 KIRIKDAĞ HES (ÖZENİR ENERJİ) Hydro 16.86 71.00
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KOZDERE HES (ADO MADENCİLİK) Hydro 6.12 9.21 KÖKNAR HES (AYCAN ENERJİ) Hydro 8.024 25.00 KÜRCE REG. VE HES (DEDEGÖL ENERJİ) Hydro 12.046 48.00 MİDİLLİ REG. VE HES Hydro 20.97 81.00 MURSAL I HES (PETA MÜHENDİSLİK) Hydro 4.18 17.00 ÖREN REG. VE HES Hydro 19.9 21.70 PAPART HES (ELİT) Hydro 26.6 106.00 POLAT HES (ELESTAŞ ELEKTRİK) Hydro 6.6 28.00 SARIHIDIR HES (MOLU ENERJİ) Hydro 6 24.00 SIRAKONAKLAR HES (2 M ENERJİ) Hydro 18 69.00 SULUKÖY HES (DU ELEKTRİK) Hydro 6.9 28.00 ŞİFRİN REG. VE HES (BOMONTİ) Hydro 6.7 18.00 TELEME REG. VE HES Hydro 1.6 11.00 TELLİ I-II HES (FALANJ ENERJİ) Hydro 8.7 32.00 TUĞRA REG. VE HES (VİRA) Hydro 4.9 18.00 TUNA HES (NİSAN) Hydro 37.2 92.00 TUZKÖY HES (BATEN ENERJİ) Hydro 8.44 68.00 UMUT I HES (NİSAN ELEK) Hydro 5.8 21.00 ÜÇKAYA (ŞİRİKÇİOĞLU) Hydro 1 5.00 VİZARA REG. VE HES Hydro 8.6 27.00 YAĞMUR REG. VE HES Hydro 8.9 32.00 YAVUZ HES (AREM ENERJİ) Hydro 5.8 14.00 YEDİSU HES Hydro 22.7 72.00 YILDIRIM HES Hydro 10.7 39.00 ZEYTİNBENDİ HES Hydro 5.2 18.00 YOKUŞLU KALKANDERE HES Hydro 5.2 2.30 ALPARSLAN 1 Hydro 160 488.00 BEKTEMUR HES (DİZ-EP) Hydro 3.49 20.00 BOYABAT HES Hydro 513 1,468.00 BÜYÜKDÜZ HES (AYEN EN.) Hydro 68.86 192.00 CAN I HES(HED ELEK.) Hydro 1.84 9.98 CUNİŞ REG.(RİNERJİ) Hydro 8.4 36.00 ÇAĞLAYAN HES Hydro 6.0 21.00 ÇARŞAMBA HES Hydro 11.31 63.00 ÇINAR I HES Hydro 9.26 34.00 ÇUKURÇAYI HES (AYDEMİR) Hydro 1.8 4.00 DEMİRCİLER HES(PAK EN.) Hydro 8.44 35.00
DOĞANKAYA (MAR-EN) Hydro 20.55 98.00
DUMLU HES Hydro 3.98 9.00
EGER HES Hydro 1.92 10.00
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ERMENEK (ELEKTRİK ÜRETİM A.Ş.) Hydro 302.40 1,187.00
KILAVUZLU Hydro 40.50 150.00
MURATLI HES (ARMAHES ELEK.) Hydro 11.00 27.43
MURAT I-II REG. Hydro 35.60 189.00
SANCAR REG.(MELİTA) Hydro 0.70 3.00
DİNAR RES (OLGU EN.) Wind 16.10 60.00
GÜNAYDIN RES (MANRES EL.) Wind 10.00 40.00 ŞENKÖY RES (EOLOS RÜZ.) Wind 26.00 87.00 AREL EN.BİYOKÜTLE Biogas 2.40 18.00 BEREKET EN ÜR.BİYOGAZ Biogas 0.64 5.00 EKİM BİYOGAZ Biogas 1.20 10.00 ITC BURSA Biogas 9.80 80.00 PAMUKOVA YEN.EN. Biogas 1.40 10.00 SAMSUN AVDAN KATI ATIK Biogas 2.40 18.00 SEZER BİYOENERJİ (KALEMİRLER EN.) Biogas 0.50 4.00 ES ES ESKİŞEHİR EN. Biogas 2.04 15.00 GAZKİ MERKEZ ATIK SU AR. Biogas 1.66 12.00 İZAYDAŞ (İzmit çöp) Biogas 0.33 2.22 KAYSERİ KATI ATIK (HER EN.) Biogas 1.31 9.90 ORTADOĞU ENERJİ (Oda yeri) Biogas 4.09 31.81 ORTADOĞU ENERJİ (KÖMÜRCÜODA) Biogas 2.83 22.05 TRAKYA YENİŞEHİR CAM SAN. Biogas 6.00 45.00 DENİZ JEO.(MAREN MARAŞ) Jeothermal 24.00 191.00 AFYON DGKÇ (DEDELİ DG) Natural gas 126.10 945.00 AGE DGKÇ (DENİZLİ) Natural gas 141.00 1,057.00 AKDENİZ KİMYA Natural gas 4.04 30.00 ALES DGKÇ Natural gas 49.00 370.00 ALTINYILDIZ (TEKİRDAĞ) Natural gas 5.50 38.00 ASAŞ ALÜMİNYUM Natural gas 8.60 65.00 BEYPİ BEYPAZARI Natural gas 8.60 63.00 BİLECİK DGKÇ (TEKNO) Natural gas 25.80 190.00 BİLECİK DGKÇ (DEDELİ) Natural gas 126.10 945.00 BİNATOM ELEKTRİK ÜRT. A.Ş. Natural gas 10.36 77.97 BİS ENERJİ (Bursa San.) Natural gas 48.00 361.57 BOSEN (Bursa San.) Natural gas 27.96 209.86 DURMAZLAR MAK. Natural gas 1.29 10.00 DURUM GIDA Natural gas 3.60 29.00 EGE SERAMİK Natural gas 13.08 90.00 ENERJİ-SA (Çanakkale) Natural gas 0.92 7.32 ENERJİ-SA (Kentsa) Köseköy Natural gas 120.00 930.00
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ENERJİ-SA (Mersin) Natural gas 1.47 11.54 ENERJİ-SA (Adana) Natural gas 0.83 5.81 ERZURUM MEYDAN AVM (REDEVKO) Natural gas 2.44 16.00 GÜRTEKS İPLİK Natural gas 6.70 53.00 HATİPOĞLU PLASTİK YAPI ELEM. Natural gas 2.00 14.00 İŞBİRLİĞİ ENERJİ ÜR.A.Ş. Natural gas 19.46 146.00 İZAYDAŞ (İzmit çöp) Natural gas 1.20 9.00 JTI TORBALI KOJEN. Natural gas 4.00 30.00 KESKİNOĞLU TAVUKÇULUK Natural gas 6.00 44.84 KIVANÇ TEKSTİL SAN.ve TİC.A.Ş. Natural gas 2.14 11.58 MUTLU MAKARNACILIK Natural gas 2.00 16.00 ODAŞ DOĞAL GAZ Natural gas 73.28 552.17 OFİM EN. Natural gas 2.05 16.00 ÖZMAYA SAN. Natural gas 5.35 40.00 PANCAR ELEK. Natural gas 34.92 260.00 PİSA TEKSTİL SAN.A.Ş.(İSTANBUL) Natural gas 1.02 7.00 SELÇUK İPLİK Natural gas 8.60 65.00 SELVA GIDA Natural gas 1.71 14.00 MERSİN KOJEN. (SODA SAN.A.Ş.) Natural gas 252.20 1,765.00 ŞANLIURFA OSB (RASA EN.) Natural gas 11.72 82.09 TEKİRDAĞ -ÇORLU KOJ.(ODE YALITIM) Natural gas 2.04 15.00 YENİ UŞAK ENERJİ Natural gas 9.73 71.00 YONGAPAN (Kastamonu) Natural gas 15.04 112.65 ZORLU ENERJİ (B.Karıştıran) Natural gas 25.70 192.84 BAMEN KOJEN.(BAŞYAZICIOĞLU TEKS.) Natural gas 2.15 14.00 AKSA AKRİLİK KİMYA (İTH.KÖM.+D.G) Natural gas 75.00 525.00 BALSUYU MENSUCAT Natural gas 9.73 68.00 BİLKUR TEKSTİL Natural gas 2.00 14.00 ERDEMİR Fuel oil 53.90 351.15 EREN ENERJİ ELEK.ÜR.A.Ş. Hard Coal 30.00 195.97 GÖKNUR GIDA Hard Coal 6.00 6.00 KÜÇÜKER TEKSTİL Lignite 5.00 40.00
2011
Index Added Installed Added Electricity Company (fuel type) Capacity (MW) Generation (GWh)
Hasanlar Hydro 9.35 39.90 Kalkandere REG ve Yokuşlu HES Hydro 23.36 109.71
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Karasu 4-2 HES (Ideal Enerji Üretim) Hydro 10.35 58.00 Karasu 4-3 HES (Ideal Enerji Üretim) Hydro 4.60 22.00 Karasu 5 HES (İdeal Enerji Üretim) Hydro 4.10 24.00 Karasu I HES (İdeal Enerji Üretim) Hydro 3.84 19.00 Karası II HES (İdeal Enerji Üretim) Hydro 3.08 13.00 Kıran HES (Arsan Enerji A.Ş.) Hydro 9.74 41.00 Kozdere HES (Ado Madencilik Elekt.) Hydro 3.15 14.00 Ayrancılar HES (Muradiye Elektrik) Hydro 32.10 128.00 Çamlıca III HES (Çamlıca Elektrik) Hydro 27.62 43.00 Menge Barajı ve HES (EnerjiSA Enerji) Hydro 44.71 102.00 Saraçbendi HES (Çamlıca Elektrik) Hydro 25.48 101.00 Sarıkavak HES (Eser Enerji Yat. A.Ş.) Hydro 8.06 43.00 Sayan HES (Karel Elektrik Üretim) Hydro 14.90 47.00 Sefaköy HES (Püre Enerji Üretim A.Ş.) Hydro 33.11 121.00 Söğütlükaya (Posof III) HES Hydro 6.13 31.00 Tektuğ (Erkenek) Hydro 13.00 50.00 Yamaç HES (Yamaç Enerji Üretim A.Ş.) Hydro 5.46 17.00 Yaşıl HES (Yaşıl Enerji Elektrik) Hydro 3.80 15.00 Yedigöze HES (Yedigöze Elek.) (İlave) Hydro 155.33 474.94 ITC-Ka En (Aslım Biyokütle) Konya Biogas 5.7 44.50 ITC-Ka Enerji (Sincan) (İlave) Biogas 1.416 11.05 ITC-Ka Enerji Mamak Katı Atık Top. Biogas 2.826 18.91 Akres (Akhisar Rüzgar En. Elekt.) Wind 43.8 165.00 Ayvacık RES (Ayres Ayvacık Rüzgar) Wind 5 17.00 Baki Elektrik Şamlı Rüzgar (İlave) Wind 24 92.63 Bandırma Enerji (Bandırma RES) Wind 3 10.50 Çanakkale RES (Enerji-SA Enerji) Wind 29.9 92.00 Çataltepe RES (Alize Enerji Elektrik) Wind 16 52.00 Innores Elektrik Yuntdağ Rüzgar Wind 10 40.57 Killik RES (Pem Enerji A.Ş.) Wind 40 86.00 Sares RES (Garet Enerji Üretim) Wind 7.5 30.33 Seyitali RES (Doruk Enerji Elektrik) Wind 30 110.00 Soma RES (Soma Enerji) (İlave) Wind 36.9 116.00
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Susurluk RES (Alantek Enerji Üret.) Wind 45 112.00 Şah RES (Galata Wind Enerji Ltd. Şti) Wind 93 400.00 Turguttepe RES (Sabaş Elektrik) Wind 2 5.83 Ziyaret RES (Ziyaret RES Elektrik) Wind 22.5 82.17 Çeşmebaşı REG ve HES (Gimak En.) Hydro 8.20 28.00 Çukurçayı HES (Aydemir Elektrik Ür.) Hydro 1.80 8.00 Darca HES (Bükor Elektrik Üretim) Hydro 8.91 63.00 Değirmendere (Kadirli) (KA- FNİH Elek.) Hydro 0.50 1.20 Derme (Kayseri ve Civarı Enerji) Hydro 4.50 14.00 Duru 2 REG ve HES (Durucasu Elektrik) Hydro 4.50 22.00 Erenköy REG ve HES (Nehir Enerji) Hydro 21.46 49.00 Erkenek (Kayseri ve Civarı Enerji) Hydro 0.32 0.80 Eşen 1 HES (Göltaş Enerji Elektrik) Hydro 30.00 120.00 Eşen 1 HES (Göltaş Enerji Elektrik) Hydro 30.00 117.51 Girlevik (Boydak Enerji) Hydro 3.04 21.00 Gökmen REG ve HES (Su-Gücü Elektrik) Hydro 2.87 13.00 Hacınınoğlu HES (Enerji SA Enerji) Hydro 142.40 360.00 Hakkari (Otluca) (NAS Enerji A.Ş.) Hydro 1.30 6.00 Hasanlar HES (Düzce Enerji Birliği) Hydro 4.68 21.00 İncirli REG ve HES (Laskar Enerji) Hydro 25.20 126.00 İnegöl (Cerrah) (Kent Solar Elektrik) Hydro 0.30 1.00 İznik (Dereköy) (Kent Solar Elektrik) Hydro 0.24 1.00 Karaçay (Osmaniye)(KA-FNİH) Elektrik Hydro 0.40 2.00 Kayadibi (Bartın) (İvme Elektromek.) Hydro 0.46 2.30 Kazankaya REG ve İncesuyu HES (Aksa) Hydro 15.00 48.00 Kernek (Kayseri ve Civarı Enerji) Hydro 0.83 0.83 Kesme REG ve HES (Kıvanç Enerji) Hydro 4.60 16.00 Koruköy HES (Akar Enerji San ve Tic) Hydro 3.03 22.00 Kovada I (Batıçim Enerji Elektrik) Hydro 8.25 4.10 Kovada II (Batıçim Enerji Elektrik) Hydro 51.20 36.20 Köyobası HES (Şirikoğlu Elektrik) Hydro 1.10 5.00 Kulp I HES (Yıldızlar Enerji Elk. Ür.) Hydro 22.92 78.00
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Kumköy HES (AES-IC İçtaş Enerji) Hydro 17.49 98.00 Kuzuculu (Dörtyol) (Ka-FNİH Elektrik) Hydro 0.30 1.30 M. Kemalpaşa (Suutçu) (Kent Solar) Hydro 0.50 1.50 Malazgirt (Mostar Enerji Elektrik) Hydro 1.22 4.00 Adilcevaz(Mostar Enerji Elektrik) Hydro 0.40 0.80 Ahlat (Mostar Enerji Elektrik) Hydro 0.20 0.60 Aksu REG. Ve HES (Kalen Enerji) Hydro 5.20 16.00 Alkumru Baraju ve HES (Limak Hid.) Hydro 261.11 828.00 Balkondu I HES (BTA Elektrik Enerji) Hydro 9.19 33.00 Batman Hydro 0.48 1.16 Bayburt (Boydak Enerji) Hydro 14.60 51.00 Bayramhacılı Barajı ve HES Hydro 47.00 175.00 Berdan Hydro 10.20 47.20 Besni (Kayseri ve Civarı Enerji) Hydro 0.30 0.50 Boğuntu HES (Beyobası Enerji) Hydro 3.80 17.00 Bünyan (Kayseri ve Civarı El. Taş.) Hydro 1.20 3.40 Cevheri I II REG ve HES (Özcevher En.) Hydro 16.36 65.00 Çağ Çağ (NAAS Enerji A.Ş.) Hydro 14.40 25.00 Çakırman REG ve HES (Yusaka En.) Hydro 6.98 22.00 Çamardı (Kayseri ve Civarı Elek. Taş.) Hydro 0.10 0.20 Çamlıkaya REG ve HES (Çamlıkaya En) Hydro 2.82 6.31 Çanakçı HES (Can Enerji Entegre) Hydro 9.30 39.00 Çemişkezek (Boydak Enerji) Hydro 0.12 0.80 Molu Enerji (Zamantı Bahçelik HES) Hydro 4.17 30.00 Muratlı REG ve HES (Armahes El.) Hydro 26.70 94.00 Narinkale REG ve HES (EBD Enerji) Hydro 33.50 108.00 Otluca I HES (Beyobası Enerji Ür) Hydro 37.54 177.00 Otluca II HES (Beyobası Enerji Ür) Hydro 6.36 27.00 Ören REG ve HES (Çelikler Elektrik) Hydro 6.64 29.00 Pınarbaşı (Kayseri ve Civarı El. Taş) Hydro 0.10 0.40 Poyraz HES (Yeşil Enerji Elektrik) Hydro 2.66 10.00 Seyrantepe HES (Düzelteme) Hydro 7.14 20.24 Sızır (Kayseri ve Civarı Elek. Taş.) Hydro 5.80 46.00 Tefen HES (Aksu Madencilik Hydro 33.00 141.00
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San.) Turunçova (Finike) (Turunçova En.) Hydro 0.55 0.38 Tuztaşı HES (Gürüz Elek. Üretim) Hydro 1.61 10.00 Uluabat Kuv. Tün. Ve HES (Düzeltme) Hydro 2.98 11.09 Üzümlü HES (Akgün Enerji Üretim) Hydro 11.40 41.00 Varto (Mostar Enerji Elektrik) Hydro 0.29 0.80 Yapısan (Karıca REG ve Darıca I HES) Hydro 13.32 45.41 Yaprak II HES (Nisan Elektromek) Hydro 10.80 32.00 Yedigöl REG. Ve HES (Yedigöl Hidr.) Hydro 21.90 77.00 Bolu Belediyesi Çöp Top. Tes. Biyogaz Biogas 1.13 7.50 ITC Adana Enerji Üretim (İlave) Biogas 1.415 10.39 Kayseri Katı Atık Deponi Sahası Biogas 1.6 12.00 Aydın Germencik Jeothermal 20 150.00 Akım Enerji Başpınar (Süper Film) Natural gas 25.3 177.00 Aksa Akrilik Natural gas 25 189.08 Aldaş Altyapı Yönetim Danışmanlık Natural gas 2 15.00 Aliağa Çakmaktepe Enerji (İlave) Natural gas 244.4 1,840.00 Bosen Enerji Elektrik Üretim A.Ş. Natural gas 93 698.09 Boyteks Tekstil San ve Tic. A.Ş. Natural gas 8.6 67.00 Cengiz Çift Yakıtlı K.Ç.E.S. Natural gas 131.33 985.00 Cengiz Enerji San ve Tic A.Ş. Natural gas 35 281.29 Fraport IC İçtaş Antalya Havalimanı Natural gas 8 64.00 Global Enerji (Çorlu) (Pelitlik) Natural gas 4 29.91 Gordion AVM (Redevco Üç Emlak) Natural gas 2.01 15.00 Goren-1 (Gaziantep Organize San) Natural gas 48.7 277.00 Gülle Enerji (Çorlu) (İlave) Natural gas 3.904 17.99 Hamitabat (Lisans Tadili) Natural gas 36 245.43 Hasırcı Tekstil Tic ve San Ltd Şti Natural gas 2 15.00 HG Enerji Elektrik Üret. San. Tic. A.Ş. Natural gas 52.4 366.00 Isparta Mensucat (Isparta) Natural gas 4.3 33.00 Istanbul Sabiha Gökçen Ul. Ar. Hav. Natural gas 4 32.00 Knauf İnş. Ve Yapı Elemanlar Sn. Natural gas 1.6 12.00 Lokman Hekim Engürü Sağ. (Sincan) Natural gas 0.514 4.00 MOSB Enerji Elektrik Üretim Ltd. Şti (İlave) Natural gas 43.5 347.86
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Nuh Enerji El. Ürt. A.Ş. (İlave) Natural gas 120 900.00 ODAŞ Doğalgaz KÇS (Odaş Elektrik) Natural gas 55 415.00 Polyplex Europa Polyester Film Natural gas 3.9 30.67 Samsun Tekeköy En. San. (Aksa En.) Natural gas 131.33 980.00 Samur Halı A.Ş. Natural gas 8.6 66.00 Şanlıurfa OSB (Rasa Enerji Ür. A.Ş. Natural gas 116.8 800.00 Tekirdağ - Çorlu Teks. Tes (Nil Örme) Natural gas 2.67 21.00 Tirenda Tire Enerji Üretim A.Ş. Natural gas 58.4 410.00 Tüpraş O.A. Rafineri (Kırıkkale) (İlave) Natural gas 12 84.78 Yeni uşak Enerji Elektrik Santrali Natural gas 8.73 65.00 Zorlu Enerji (B. Karıştıran) Natural gas 7.2 54.07 Eti Bor (Borik Asit) (Emet)(Düzeltme) Fuel oil 0.6 4.47 Karkey (Silopi 1) Fuel oil 100.44 701.15 Mardin-Kızıltepe (Aksa Enerji) Fuel oil 32.1 225.00 Toros Tarım (Mersin) (Nafta+Doğalgaz) Fuel oil 12.1 96.00 Bekirli TES (İçdaş Elektrik En.) Hard coal 600 4,332.00
Appendix 5: Further background information on monitoring plan
Appendix 6: Summary of post registration changes
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History of the document
Version Date Nature of revision 04.1 11 April 2012 Editorial revision to change version 02 line in history box from Annex 06 to Annex 06b. 04.0 EB 66 Revision required to ensure consistency with the “Guidelines for completing 13 March 2012 the project design document form for CDM project activities” (EB 66, Annex 8). 03 EB 25, Annex 15 26 July 2006 02 EB 14, Annex 06b 14 June 2004 01 EB 05, Paragraph 12 Initial adoption. 03 August 2002 Decision Class: Regulatory Document Type: Form Business Function: Registration