grid-connected electricity generation from renewable sources

•••• •••• ••••

THE GOLD STANDARD:

Project Design Document for Gold Standard Voluntary Offset projects

(GS-VER-PDD)

For more information, please contact The Gold Standard: http://www.cdmgoldstandard.org [email protected] phone +41 61 283 09 16 fax +41 61 271 10 10 April 2006

Grid-connected electricity generation from renewable sources:

Belen 30 MW Wind Power Plant Project, Turkey

PROJECT DESIGN DOCUMENT FORM (GS-VER-PDD) Voluntary Offset Projects - Version 01

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This template shall not be altered. It shall be completed without modifying/adding headings or logo, format or font.

VOLUNTARY OFFSET PROJECTS

PROJECT DESIGN DOCUMENT FORM (GS-VER-PDD) Version 01 - in effect as of: January 2006)

CONTENTS A. General description of project activity B. Application of a baseline methodology C. Duration of the project activity / Crediting period D. Application of a monitoring methodology and plan E. Estimation of GHG emissions by sources F. Environmental impacts G. Stakeholders’ comments

Annexes Annex 1: Contact information on participants in the project activity Annex 2: Baseline information

Annex 3: Monitoring plan


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SECTION A. General description of project activity A.1 Title of the project activity Title: Grid connected electricity generation from renewable sources: Belen, 30MW Wind Power Project; Turkey Version: 002 Date: May 2008 A.2. Description of the project activity Belen Wind Power Project consists of erection of 10 wind turbines, each having a capacity of 3000 kW in Belen, Hatay, Southeast Mediterranean coast of Turkey. The owner of the project is Belen Elektrik Üretim A.Ş. The wind farm will serve with an overall capacity of 30MW and will be connected to the grid with approximately 2 km wiring via Antakya II transmission line, which will be installed as part of the project. The major purpose of the project activity is providing electricity from renewable sources to the rapidly growing Turkish electricity market. The project is expected to generate about 96,710 MWh electricity per year and prevent approximately 62,572 tonnes of CO2 emissions per year compared to the baseline scenario. The project is expected to be registered as a Gold Standard Voluntary Emission Reduction (GS-VER) project on the grounds that renewable resources will be utilised for electricity generation to the national grid which is dominated by fossil fuel power plants. As the financial incentives for energy generation from renewable sources are not sufficient in the country, investing on the renewable energy production is not attractive for the private sector. VER revenue will make the project financially viable and financial inflows provided by sale of credits will increase the Internal Rate of Return (IRR) of the project to an acceptable level. Table.1. summarises the evaluation of the project in sense of sustainable development indicators. As stated in the Environmental Impact Pre-assessment Report1 submitted to the Ministry of Environment and Forestry; the project will contribute to sustainable development in the region and in Turkey in the following ways:

• Air Quality (+1): Wind energy projects do not emit any gases harmful to environment or human health. No residuals which may have negative impacts on soil or water will be released as well.

• Other Pollutant (+1): The project will also contribute the reduction of other gases (such as NOx and SOx); which would have been emitted by conventional electricity generation. The project replaces the fossil fuel generation.

• Employment (job quality) (+1): The project will enable temporary and permanent jobs for local people in a new sector which requires high proportion of highly skilled labour, such as electrical and civil engineers.

• Access to affordable clean energy services (+1): The produced electricity will be distributed countrywide via national grid which is dominated by fossil fuel powered plants. The project will enable the use of local resources for energy production; which will decrease the dependency on imported fossil fuel or electricity and increase country’s ability to generate electricity.

• Employment (numbers) (+1): The project will create employment opportunities for the local residents during both construction and operational phases of the project. 60-70 workers will be hired during construction phase and 15-20 personnel will be hired for operational phase.

• Technological self reliance (+1): Although electricity produced by wind energy is cheaper than other sources, investment required for to build up technological capacity is high. The project will contribute to technological capacity of the sector.

1 Environmental Impact Pre-assessment Report.


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Neither negative nor positive impacts have been determined in respect of water quality and quantity, soil condition or biodiversity. There will be no effects on livelihood of the poor and human institution capacity as well. Therefore; those items has been left as “0”. To be conservative, the balance of payments has been left at zero as it is difficult to monitor if the project will actually lead to less fuel being imported to Turkey. The Environmental Impact Pre-Assessment report has been submitted to the Ministry of Environment and Forestry. Investigating the documents, the Ministry concluded that the project has no significant environmental impact and is not required to go through a further EIA process. (Annex.5)

Component Indicators Score (-2 to 2)/(-, 0, +)

Rationale

Local/regional/global environment Water quality and quantity 0 No negative impacts on water quality. Air quality (emissions other than GHGs) +1 No emissions harmful to human health or

environment. Positive impact on air quality. Other pollutants (including, where relevant, toxicity, radioactivity, POPs, stratospheric ozone layer depleting gases)

+1 Positive impact on environment by replacing fossil fuel with wind energy.

Soil condition (quality and quantity) 0 No residuals which may affect the soil quality will be released

Biodiversity (species and habitat conservation) 0 No impact on flora or fauna or any species under protection.

Sub total +2 Social sustainability and development Employment (including job quality, fulfilment of labour standards)

+1 Temporary and permanent jobs will be available for local people.

Livelihood of the poor (including poverty alleviation, distributional equity, and access to essential services)

0 No effect on livelihood of the poor.

Access to energy services +1 The local resources will be utilised for energy production; the dependency on imported fossil fuel will be lowered.

Human and institutional capacity (including empowerment, education, involvement, gender)

0 No effect on human and institutional capacity.

Sub total +2 Economic and technological development Employment (numbers) +1 60-70 workers will be hired during construction

phase and 15-20 people will have permanent jobs

Balance of payments (sustainability) 0 No impacts on balance of payments Technological self reliance

(including project replicability, hard currency liability, skills development, institutional capacity, technology transfer)

+1 Technological capacity of the wind power sector will increase.

Sub total +2 Total +6

A.3. Project participants:

Name of Party involved (*) ((host) indicates a host Party)

Private and/or public entity(ies) project participants (*)

Kindly indicate if the Party involved

Table 1 - Sustainable Development Matrix


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Proje mevkii

N

(as applicable) wishes to be considered as

project participant (Yes/No)

Turkey (host) BELEN ELEKTRİK ÜRETİM A.Ş. No JPMorgan Ventures Energy Corporation A.4. Technical description of the project activity: A.4.1. Location of the project activity:

The project will be based on Belen, Hatay ; Turkey. A.4.1.1. Host Party(ies):

Host country is Republic of TURKEY and she does not have a quantitative reduction target under the Kyoto Protocol. Therefore; the project is eligible for the VER application.

A.4.1.2. Region/State/Province etc.:

Mediterranean region, Province of Hatay, County of Belen. A.4.1.3. City/Town/Community etc:

The wind turbines are located on three hills namely; Kemikli, Allahverdi and Büyükdüz near District of Halilbey.

A.4.1.4. Detail of physical location, including information allowing the unique identification of this project activity (maximum one page): 10 turbines each with a capacity of 3000 kW will be erected on the locations given by Table.1. The location has been shown below (Figure.1&2).

Figure 1. Location of Project activities

Table.1. Coordinates of the turbines to be erected


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Turbine

East North

1 36012'23.40289" 36

028'33.79044"

2 36012'12.43353" 36

028'22.69750"

3 36012'00.54173" 36

028'19.40129"

4 36012'33.88508" 36

028'48.40795"

5 36012'21.96341" 36

028'44.78718"

6 36012'09.79158" 36

028'45.89684"

7 36011'58.26978" 36

028'49.03284"

8 36011'45.80972" 36

028'50.32969"

9 36011'34.81612" 36

028'59.96597"

10 36011'22.90263" 36

029'11.68901"

Figure.2. Satellite Image of the project location (Google Earth)


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A.4.2. Size of the project: The installed capacity is 30MW so this is a large scale project. A.4.3. Category(ies) of project activity: The Belen WPP falls in the category A.1., Renewable Energy, according to the Gold Standard-VER Project Developer’s manual. A.4.4. Brief explanation of how the anthropogenic emissions of anthropogenic greenhouse gas (GHGs) by sources are to be reduced by the proposed project activity, including why the emission reductions would not occur in the absence of the proposed project activity, taking into account national and/or sectoral policies and circumstances: Turkey’s energy and electricity demand have increased at an annual rate of 7% over the period of 1990 – 2004 in the country in the First National Communication (FNC) of Turkey2. This rise in demand has been supplied mainly by thermal and hydro power plants. The CO2 emission from electricity generation has been calculated as 167.800 kt, which accounts 76.7% of total net GHG emission of Turkey in 2004. As the GDP is expected to grow at over 6% per year for the next 15 years, gross electricity demand will increase from 166 TWh to 499 TWh during the period 2005-2020. In order to supply the increasing demand, the total electricity generation capacity will reach to 520 TWh in 2020. Figure.3 shows the expected trend of primary energy sources for generating capacity during the period 2005-2020. It can be seen that electricity generation facilities will continue to rely on fossil fuels which are predicted to constitute 72.5 % of the energy sources in 20202. Considering the increasing demand on energy in the country, in the absence of the Project the same amount of electricity would be supplied by the grid, which depends on mainly the power plants fed by fossil fuel sources. Figure.4. shows that the share of fossil fuel in electricity production has increased during last three years3. Therefore, the project will help to reduce greenhouse gas emissions per unit of electricity generation in the future.

2 Chapter.5.Projections and Mitigations Scenarios, First National Communication of Turkey on Climate Change, January 2007, (pg. 121-157) (http://www.undp.org.tr/Gozlem2.aspx?WebSayfaNo=531)

3 Monthly Electricity Statistics, Jan 2008, International Energy Agency (pg.33) (http://www.iea.org/Textbase/stats/surveys/mes.pdf)

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Figure 3. Breakdown of actual and expected generating capacity by primary sources2

Figure.4. Electricity production by fuel type in recent years A.4.4.1. Estimated amount of emission reductions over the crediting period: The annual electricity generation is estimated to be 96,710MWh and approximately 62,572 tCO2 emissions per year will be saved by the project. The total amount of emission reduction sums up to 438,000 tCO2 over the crediting period of 7 years (Table 2).

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Table 2 - Expected emission reduction by the project activity

Years Annual estimation of emission reductions in tonnes of CO2 e

Oct. 2009 15,643 2010 62,572 2011 62,572 2012 62,572 2013 62,572 2014 62,572 2015 62,572 Oct. 2016 46,929 Total emission reductions (tonnes of CO2 e)

438,000

Total number of crediting years 7 Annual average over the crediting period of estimated reductions (tonnes of CO2e)

62,572


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SECTION B. Application of a baseline methodology B.1. Title and reference of the approved baseline methodology applied to the project activity: “Consolidated baseline methodology for grid connected electricity generation from renewable sources (ACM0002 version 7)” The above methodology is hereafter referred to as the “Baseline Methodology”. The Baseline Methodology will be used in conjunction with the approved monitoring methodology ACM0002 version 7(“Monitoring Methodology”). The PDD also draws upon:

• Tool for assessment and demonstration of additionality, ver 5.2 • Tool to calculate the emission factor for an electricity system, ver 01

B.1.1. Justification of the choice of the methodology and why it is applicable to the project activity: ACM0002 methodology defines the baseline scenario for the proposed project as: Electricity delivered to the grid by the project 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. The choice of methodology ACM0002, Version 7, is justified as the project activity meets its applicability criteria:

• The Belen WPP Project is a grid-connected renewable power generation project that adds electricity from wind power.

• The project does not involve switching from fossil fuels to renewable energy at the site of the project activity.

• The geographic and system boundaries for the relevant electricity grid can be clearly identified and information on the characteristics of the grid is available.

B.2. Description of how the methodology is applied in the context of the project activity: The baseline scenario for the Turkish electricity grid has been determined by a conservative approach in accordance with the methodology. Combined Margin (CM) approach has been used to calculate the baseline emission factor with the selected methodology. Basic assumptions are;

• Project activity is limited to Turkish Electricity Grid • Weight of thermal power plants (and thus emission factor) will remain same over the crediting period • When there is no data about emission factor of fuel sources, it has been accepted as “0” or the lowest

value has been used As new domestic coal reserves are utilised for power generation in future years, the weight of fossil fuels in electricity production is expected to increase accordingly. This will increase CO2 emissions per unit of electricity generation, however; in order to apply a conservative approach, emission factors are calculated with the values leading to lowest Combined Margin.


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Table 3 shows the main gases included in the project boundary. CO2 emission is included in baseline but the project activity does not emit any gases listed.

Table 3- Main gases included in the project boundary

Source Gas Included? Justification/Explanation CO2 Yes Main Emission Source CH4 No Excluded for simplification

Baseline Electricity generation in baseline (Turkey Grid)

N2O No Excluded for simplification CO2 No Zero-emission electricity

generation CH4 No No emission

Project Activity Emission from the reservoir of the proposed project (inside project boundary)

N2O No Zero-emission electricity generation

According to the ACM0002, four different methods for the calculation of the operating margin are described: (a) Simple OM, (b) Simple adjusted OM, (c) Dispatch Data Analysis OM and (d) Average OM. Table 4 shows the share of primary sources in electricity generation for the five most recent years. Hydro and other renewable energy sources are accepted as low cost/must run sources and their share is below 50%, therefore, in accordance with the Tool, (a) Simple OM method will used in the calculations. Other methods are not applicable due to data constraints.

Table 4 - Share of primary sources in electricity generation, 2002 – 20064

2002 2003 2004 2005 2006 Thermal 73.8 74.8 69.2 75.4 74.8 Hydro 26.0 25.1 30.6 24.4 25.1 Wind 0.1 0.0 0.1 0.1 0.1 Geothermal 0.1 0.1 0.1 0.1 0.0 Total 100.0 100.0 100.0 100.0 100.0 The Ex-ante option defined as a 3 year generation-weighted average based on the most recent data available has been selected for data vintage. The step-wise approach provided in ACM0002 to calculate the combined margin emission factor for Turkey is described below. STEP 1 - Calculation of the Operating Margin emission factor The Simple Operating Margin (OM) emission factor (EFOM, y) is calculated as the generation-weighted average emissions per electricity unit (tCO2/MWh) of all generating sources serving the system. Low operating cost and must run power plants should be excluded from the calculations.

4Annual Development of Turkey’s Gross Electricity Generation by Share of Primary Energy Resources (1970-2006) (http://www.teias.gov.tr/ist2006/index.htm)

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As electricity generated by solar and low cost biomass facilities are insignificant and there is no nuclear plant in Turkey, only hydro, wind and geothermal facilities are accepted as the low cost /must run plants. The following formula shall be applied:

EFOM,y=∑

∑

j

yj

ji

jiyji

GEN

COEFF

,

,

,,, *

where Fi, j, y is the amount of fuel i consumed by relevant power source j in year y;

J refers to the power sources delivering electricity to the grid with the above described conditions; COEFi, j, y is the CO2 emission coefficient of fuel i; GENj, y is the electricity delivered to the grid by source j.

The following data are available in Turkish Electricity Transmission Company (TEİAŞ) web site:

• Annual fuel consumption by fuel type5, • Annual heating values for fuels consumed for electricity generation6, • Annual electricity generation by fuel type, import and export7

Annual heating values for each fuel type are directly related with the fuel consumption and are used to calculate average Net Calorific Values (TJ/kt) (Table.5). Table.5. Net Calorific Values for each fuel type for Turkey. Fuel Type NCV

(TJ/kt) Hard Coal+ Imported Coal 21.87 Lignite 6.82 Fuel Oil 40.12 Diesel Oil 42.64 LPG 45.99 Naphtha 44.10

Natural Gas 37.08

5 Fuel Consumed in thermal P.P.in Turkey by the Electric Utilities (2000-2005)&(2006) (http://www.teias.gov.tr/ist2006/index.htm)

6 Heating Values Of Fuels Consumed In Thermal P.Ps In Turkey By The Electric Utilities (2000-2005) &(2006), (http: //www.teias.gov.tr/ist2006/index.htm).

7 Annual Development of Turkey’s Gross Electricity Generation by Primary Energy Resources and The Electric Utilities (2001-2005) / Turkey’s Gross Electricity Generation by Primary Energy Resources and The Electric Utilities (2006), (http: //www.teias.gov.tr/ist2006/index.htm).

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The operating calculation has been based on data from 3 most recent years available: 2004, 2005 and 2006. The coefficients required for calculation of CO2 emission factor (tCO2/TJ) have been obtained through IPCC 2006 guidelines for GHG inventories8. All data used for the calculations can be found in Annex 2. Table 6 shows total CO2 emission by electricity generation calculated using lower IPCC emission factors and available data by the ACM002 methodology.

Table 6 - Calculation of emission by electricity generation (2004-2006)

NCV (TJ/kt)

Lower COEF

(tCO2/TJ)

Total Fuel Consumption (2004 - 2006)

(t or m3)

Total Emission (2004 - 2006)

(tCO2) Hard Coal+ Imported Coal 21.87 94.6 15,441,634 31,947,227.47 Lignite 6.82 90.9 132,679,613 82,242,778.28 Fuel Oil 40.12 75.5 6,155,607 18,645,70294 Diesel Oil 42.64 72.6 119,084 368,615.23 LPG 45.99 61.6 25,614 72,564.05 Naphtha 44.10 69.3 306,683 937,333.96 Natural Gas 37.08 54.3 46,117,033 92,789,290.64

Total Emissions 227,003,512.57 Net electricity generated and supplied to the grid by thermal power plants has been calculated using data obtained from TEİAŞ web page9,10. Ratio between total gross and total net generation (including low-cost/must run plants) has been calculated for each year. The same ratio is assumed to be valid for all thermal plants and total net generation by the plants has been calculated accordingly. Summing up total net generation with the imported electricity, total supply excluding low cost / must run sources for each year is determined and given in Table 7.

Table 7 - Net Electricity Generation from thermal power plants (units in GWh)

Year Gross

generation Net

generation Net/Gross

Gross Gen. Thermal

Net Gen Thermal

Import Total Supply to the grid

2004 150,698.3 145,065.7 0.963 104,464.0 100,559.2 1,144.3 101,703.5

2005 161,956.2 155,469.1 0.960 122,242.0 117,345.9 1,798.1 119,144.0

2006 176,299.8 169,543.1 0.962 131,835.1 126,782.5 573.2 127,355.7

Total Net Thermal Gen. 344,687.6 1,672.6 346,360.2 Finally, OM emission factor considering years 2004 - 2006 has been calculated as simply dividing the total CO2 emission (Table 6) by total net electricity supply to the grid (Table 7) which is;

8 Table 2.2.Default Emission Factors for Stationary Combustion in the Energy Industries, Vol.2. Energy, 2006 IPCC Guidelines for National Greenhouse Gas Inventories, (http://www.ipcc-nggip.iges.or.jp/public/2006gl/pdf/2_Volume2/V2_2_Ch2_Stationary_Combustion.pdf)

9 Annual Development of Turkey’s Gross Electricity Generation by Primary Energy Resources and The Electric Utilities (2001-2005), (http://www.teias.gov.tr/ist2006/index.htm)

10Turkey’s Gross Electricity Generation by Primary Energy Resources and The Electric Utilities (2006), (http://www.teias.gov.tr/ist2006/index.htm)

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OM = 227,003,512.57tCO2 / 346,360,200 MWh= 0.655 tCO2/MWh STEP 2 - Calculation of Build Margin emission factor: The Build Margin emission factor EFBM is calculated as the generation-weighted average emission factor of a sample of power plants m for a specific year with the formula:

EFBM [tCO2/MWh] =∑

∑

m

m

mi

mimi

GEN

COEFF,

,, *

where; Fi,m is the amount of fuel i consumed by relevant power sources m;

COEFi,m is the CO2 emission coefficient of fuel i, taking into account the carbon content of the fuels used by relevant power sources m;

GENm is the electricity (MWh) delivered to the grid by source m.

The cohort of power units to be included in calculation of the Build Margin consists of either:

• Set of 5 power plants/units that have been built most recently, or • Set of power capacity additions in the electricity system that comprise 20% of the system generation (in

MWh) and that have been built most recently. The larger annual generation set of power plants shall be used from those options. Therefore; set of power plants that comprise 20% of the system generation and have been recently added to the system is chosen for BM calculations. The gross electricity generation in year 2006 is taken as reference for determination of plants that comprise 20% of the system generation. The gross generation was 176,299.8 GWh (Table 7) in 2006 and 20% of that amount is calculated as 35,259.96 GWh. Summing up all the plants build in 2006, 2005 and 2004, the total generation is 35.289,8 GWh. The lists of most recent capacity additions to the grid by year and their average and firm generation capacities are available at the TEİAŞ web page11,12,13. However; for the year 2006, the annual generation capacity data for each plant is not available. Two datasets are published for the year 2006; which are: (1) Annual generation capacity by fuel type9 (2) List of plants added in 2006 with their installed capacity14. Comparing two datasets, it is concluded that 1080 MW of installed capacity mentioned in the first dataset belongs to the power plants working with lignite in the second dataset. Therefore; the generation capacity 7,020 GWh out of 11,155 GWh of thermal total has been

11 Generation Units Put Into Operation and Out of Operation in 2006,(http://www.teias.gov.tr/ist2006/index.htm) 12 Generation Units Put Into Operation and Out of Operation in 2005, (http://www.teias.gov.tr/ist2005/index.htm) 13 Generation Units Put Into Operation and Out of Operation in 2004, (http://www.teias.gov.tr/ist2004/index.htm) 14 Türkiye Elektrik Enerjisi 10 yıllık Üretim Kapasite Projeksiyonu, (2007-2016) (http://www.teias.gov.tr/projeksiyon/projeksiyon%20Temmuz2007.pdf)

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accepted to be produced by lignite while the rest is assumed to be produced by natural gas. All the data used for calculations could be found in Annex.2.

Table 8 - Calculation of emission factor for each fuel type

A

B C D

COEF

(tCO2/Tj) OXID Generation

Efficiency %

EFBAT (tCO2/MWh) (A*B/C*278)

Coal 94.6 1 33.6% 1.014 Lignite 90.9 1 32.8% 0.998 Fuel Oil 75.5 1 35.1% 0.774 Diesel 72.6 1 27.5% 0.949 LPG 61.6 1 45.0% 0.492

Naphtha 69.3 1 45.0% 0.554 Natural Gas 54.3 1 46.0% 0.425

Data for oxidation index and default values for effective CO2 emission factor have been obtained through IPCC15 guidelines. For the generation efficiencies, the real values of present thermal power plants have been used from Türkiye Çevre Atlası prepared by Ministry of Environment and Forestry16. The average generation efficiencies have been calculated from the published values for existing plants. The rest of the generation efficiencies (for LPG and Naphta) have been obtained from the reference documents for best available techniques of European Integrated Pollution Prevention and Control Bureau (EIPPCB)17 (Table 8). The Build Margin emission factor has been determined for most recent capacity additions using the EF values calculated for each fuel source (Table 9). The emission factor has been taken as “zero” where no data is available.

Table 9 - Distribution of most recent capacity additions by fuel source.

E F (=E/35,289.8)

G EFW

(=F*G) Fuel Source Generation

(MWh) Percent Generation EFBAT Weighted

EFBAT Coal 1,463 4.1% 1.014 0.04 Lignite 11,480 32.5% 0.998 0.32 Fuel Oil 565 1.6% 0.774 0.01 Diesel oil 6 0.0% 0.949 0.00 LPG 50 0.1% 0.492 0.00 Naphtha 323 0.9% 0.554 0.01

15 Table 1.4.Default CO2 emission factors for Combustion,Vol.2. Energy, 2006 IPCC Guidelines for National Greenhouse Gas Inventories, (http://www.ipcc-nggip.iges.or.jp/public/2006gl/pdf/2_Volume2/V2_1_Ch1_Introduction.pdf) 16 TabloX.3.1. Türkiyedeki termik santrallerin adları, bulunduğu yer ve diğer bilgiler, Türkiye Çevre Atlası, MoEF, Ankara 2004, pg.197, (http://www.cedgm.gov.tr/dosya/cevreatlasi/atlasin_metni.pdf 17 EIPPCB, Reference Document on Best Available Techniques for Large Combustion Plants, (http://eippcb.jrc.es/pages/FActivities.htm).

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Natural Gas 19,811 56.1% 0.425 0.24 Renewable and wastes 85 0.2% 1.014 0.00 Solid 5 0.0% 0.998 0.00 Total Renewable 1.502 4.3% 0.774 0.00 TOTAL Capacity additions 35,289.8 0.624

The Weighted Build Margin (EFW) emission factor in last column has been determined by multiplying EFBAT value with the corresponding electricity generation percentage for that fuel type to the total electricity generation. Finally, the overall build margin emission factor has been calculated by summing up the weighted EFBAT values;

EFBM = 0.624

STEP 3 - Calculation of the Baseline Emission Factor Based on ACM0002, weighted average baseline emission factor is calculated as follows:

EF = wOM*EFOM + wBM*EFBM

Where weights wOM and wBM are by default 0,75 and 0,25 according to the selected methodology. And EFOM

and EFBM are calculated as described in the previous steps. Based on the formula above, baseline emission factor is calculated as; EF = 0.75 * 0.655 + 0.25 * 0.624 = 0.647

Therefore the baseline emission factor is

0.647 tCO2/MWh

B.3. Description of how the anthropogenic emissions of GHG by sources are reduced below those that would have occurred in the absence of the registered VER project activity: It is assumed that in the absence of the project activity, the corresponding amount of electricity will be supplied by the grid which is dominated by fossil power plants. As the percentage of fossil fuel sources in electricity production is expected to rise in future years, emissions per unit of electricity generation will continue to increase accordingly. The Project will provide emission reductions by enabling the usage of renewable resources for electricity generation. This section refers to the Tool to for the Demonstration and Assessment of Additionality Version 5.2 and the numbering in this section reflect the Tool’s guidelines provided at EB 39. Step 1 - Identification of Alternatives to the project activity consistent with current laws and regulations Sub-step 1a - Define alternatives to the project activity: (1)Within this framework, most realistic and reliable alternatives to the project activity are;

a. Proposed project activity not undertaken as a VER project activity

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b. Supply of equal amount of electricity by the existing grid c. No project activity

a The first alternative as the project undertaken without VER credits is unlikely as the project is not financially attractive for the project developer and faces a number of significant barriers to implementation, which the VER finance helps it overcome. b. The second alternative (Scenario b) is the baseline scenario applied to the calculations above. Implementation of the proposed project as a VER activity will be additional to this scenario. As the solid fuel reliance of Turkish grid is expected to continue, the emission factor per MWh of electricity generated shall increase overtime. However; in order to follow a conservative approach, the emission factor calculated has been accepted to remain constant over the Project period. c. In case of no project activity option, the growing electricity demand will be supplied by other resources, which is the same as the second alternative. Outcome of Step 1a: The only realistic and credible alternative scenario to the project activity is Scenario (b) Supply of equal amount of electricity by the existing grid. Sub-step 1b - Consistency with mandatory laws and regulations: (2) The alternative Scenarion(b) is in compliance with all mandatory applicable and legal and regulatory requirements. New power generation capacity is regulated by Electricity Market Regulation Authority (EMRA) who issues the licenses for electricity generation and is responsible for ensuring that new capacity applies with its rules and regulations. (3) N/A (4)The project activity is not the only alternative and therefore additional. Outcome of Step 1b: The alternative scenario to the project activity is the supply of electricity by the existing grid with additional capacity is in compliance with mandatory legislation and regulations. Step 2 - Investment analysis The investment analysis has been done in order to make an economic and financial evaluation of the project. That “the proposed project activity is not (a) the most economically and financially attractive” has been demonstrated below: Sub-step 2a - Determine appropriate analysis method (1)There are three options for investment analysis method:

• Simple Cost Analysis • Investment Comparison Analysis and • Benchmark Analysis

Simple Cost Analysis is not applicable on the grounds that the project generates an income/ economical benefits to the project from sales of electricity. Investment Comparison Analysis is also eliminated since the baseline assumption for the project is generation of electricity by the grid and no alternative investment is point at issue. Therefore, Benchmark Analysis will be used for the evaluation of the project investment.

Deleted: 1.

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Deleted: scenarios discussed above are in compliance with the applicable legal and regulatory requirements.¶


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Sub-step 2b - Option III-Apply benchmark analysis (4) Since there is no pre-determined value for IRR or any other financial indicator for wind power plants in Turkey, Benchmark value will be selected as the Eurobond rates. The government bonds have a term period of 1 to 3 years; which is rather short compared to the investment period and are not preffered. (5) Eurobond is fixed interest bonds with term as long as 5 to 30 years. Each bond has a pre-defined coupon period (6 months for USD and one year for EUR), at the end of which the investor will receive a yield at the fixed interest rate, providing regular payment. The percentage of yield may change in accordance with the fluctuations in the international and national markets. (6) Eurobond Rates in Turkish market for eight to thirty years periods have been determined and given in Table 1018;

Table 10- Eurobond Rates in Turkey for various due dates.

Code-Due date

Issue Date Currency Fixed Interest Rate (%)

Yield (%)

651-18.01.2011

18.06.2003 EUR 9.500 4.66

684-02.04.2019

02.02.2007 EUR 5.875 7.61

630-15.01.2030

18.01.2000 USD 5.937 7.98

Sub-step 2c - Calculation and comparison of financial indicators (7) The main parameters used for evaluation of the investment are given in Table 11. Although the electricity sale price is fixed at a maximum 5.5 c€/kWh by Renewable Energy Law, this is expected to rise at the commissioning date of the plant.

Table 11- Financial parameters used in investment analysis

Installed Capacity 30 MW

Expected Electricity Generation 96,710MWh Emission Reduction(ER) 62,572 tCO2e ER sales price 7 Euro/t CO2e Total Investment 42,573,000 Euro Loan 34,058,400 Euro Loan Period 10 years Electricity Sales Price 6.30Euro VAT 18% Income Tax 20%

Wind power investments are highly capital intensive projects. The initial investment (costs for the WT itself, foundations, electrical equipment and grid-connection) constitutes approximately 75% of the electricity production

18 http://www.isbank.com.tr/fiyatoran/fiyatgoster.asp

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cost. Therefore, the major factor for determining the return of investment in wind power projects is the cost of capital19. For the Belen WPP project, the Internal Rate of Return (IRR) on Capital Employed is calculated as 8.4 % and IRR for Equity is calculated as 11.9% without the carbon credit income. As the cost of financing expenditures (i.e. loan repayments and interests) are not included in calculations of IRR on Capital Employed, it is comparable with the chosen benchmark, Eurobonds. (8) The privatisation of the energy market in Turkey is still in progress and the competition remains limited in electricity market. The pricing is not cost based, which pose risks to energy investments. Acceptable IRR values for similar projects in Turkey are announced as at least 10%20 for renewable projects which will benefit from the loans by World Bank. (9) Those assumptions related market development and bond rates are applicable across the project activity and to its alternatives. (10) Comparing the IRR on Capital Employed for the project (8.4%)with the Eurobond interest rates shown above (7.98% for 30 years) and expected IRR values for renewable energy projects (10%) in Turkey, it is concluded that the investment is not financially attractive without VER revenue. The same amount of investment would bring almost the same revenue by other financial instruments without any market risks. However, the carbon revenue may increase IRR on Capital Employed to 9.5 % and the project becomes more attractive financially. Sub-step 2d - Sensitivity Analysis (11) In order to determine whether investment decision is the most attractive alternative financially, a sensitivity analysis has been done. Three parameters used for analysis;

• Investment Cost • Operating Cost • Electricity Sales revenue

For a range of ±10% fluctuations in parameters above, including carbon revenue, Table 12 and Figure.5 below have been obtained.

Table 12 - Sensitivity analysis for the IRR on Capital Employed with carbon revenue for the project

-10 -5 0 5 10 Investment 11.1 10.3 9.5 8.8 8,1 Operating 9.8 9.6 9.5 9.4 9.3 El. Sell Revenue 8.0 8.7 9.5 10.3 11.0

Table 12shows the change in IRRs by fluctuations in investment, operating and electricity sales revenue with constant VER revenue. The project becomes competitive only if the marginal fluctuations occur in investment cost or electricity prices. IRR becomes 11,1 and 11,0 with VER revenue for 10% decrease in investment cost or 10% increase in sales revenue respectively.

19 Wind Energy-The Facts, Volume 2-Costs&Prices p. 103, (http://www.ewea.org/index.php?id=33)

20 Announcement, Clean Energy Foundation, (http://www.temev.org.tr/duyurularS.htm)

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Figure.5. Sensitivity analysis with VER revenue However; the electricity sale prices for renewable energy power plants have been fixed in accordance with Renewable Energy Law and therefore any change in electricity revenue is unlikely. On the other hand, a high portion of the investment cost will be spent on the purchase of turbines which are exported from Europe and the prices are generally fixed with the generation capacity. As a result, fluctuations in both expenditures are unlikely to be realised. In addition, it should be noted that calculations do not include the project risks which are difficult to quantify and to be included in the calculations. When those risks are also considered, it is obviously seen that project activity is not the most attractive financial alternative, and is therefore additional to baseline scenario. Details of the analysis, including commercially sensitive information, are not given with the report. However; they could be submitted as a spread sheet upon request. Outcome of Step 2: The project activity is unlikely to be financially attractive compared to other investment means. Step 3 - Barrier Analysis Sub-step 3a - Identify barriers that would prevent the implementation of type of the proposed GS-VER project activity (1)Wind energy investments in Turkey has to face a number of financial obstacles in Turkey as the chairman of Wind Power and Hydro Power Plants’ Businessmen Association stated in his speech at the 6th Energy Arena in İstanbul. Only 1% of Turkey’s wind power potential is currently utilised and underlined obstacles due to present laws and regulations. (a) Investment barriers:

• Lack of incentives: There are more financial incentives for thermal power plants by the government. Law No. 5710 Nuclear Power Plant Establishment and Operation (2007) which enables the electricity generation from nuclear power also gives the opportunity of the transfer of ownership and operation of a state owned coal field subject to the terms that a coal- fired thermal power plant with a capacity of equal or greater to

Deleted: He has stated that o


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1,000MW is established by 2014. The government also provides a 15 year purchase contract for the electricity generated whereas it is only 10 years for renewable energy.

• Fixed pricing: The electricity pricing from renewable sources is fixed by the law and independent from the cost of generation.

• Higher fees: The annual fee for the usage of the interconnection line is determined in accordance with the established capacity of the power plant by TEİAŞ. However; conventional power plants tend to utilise 80-85% of their established capacity whereas wind power plants only utilise 30-45%. This means a thermal power plant and wind power plant with the same established capacity will pay the same annual fee but wind power plant will produce significantly less electricity21.

• Less competitiveness in the market: The wind energy cannot compete with conventional energy as the electricity is not continuously fed from wind power plants and needs to be balanced in pool of energy sources.

• Uncertainties on the future energy policies: No national targets for renewable energy have been set. The market is still in development phase.

(b) Technological barriers:

• Lack of infrastructure:TEİAŞ has limited the capacity of the wind power to 5% of the short circuit capacity of the high voltage transmission line into which wind power is fed. Therefore, many projects with high potential capacity (and therefore lower costs per installed MW) could not be realised as the capacity is limited by the capacity of transmission line to the grid.

(d) Other barriers:

• Construction barriers: The project design involves the construction of a road to the site which is a significant extra cost. The Project also includes construction of 2 km transmission wiring from Belen WPP to the transmission station.

Outcome of Step 3a: As a result, the main barriers for renewable energy investments in Turkey are the lack of financial incentives, grid connection fees, restricted pricing policies, uncertainties on future national energy and carbon policies and economic parameters when compared with conventional technology investments under the view of the present regulatory framework. The voluntary carbon market is an innovative and effective actor “enabling environment” for investment in renewable sources for electricity generation in Turkey. The national economic policy studies generally focus on the manifold aspects of how to support the rapidly developing economy and increasing energy demand which is one of the main problems to be solved urgently. The funds from international credit buyers will help the simultaneously fast growing electricity market to pursue a sustainable path by supporting renewable energy projects. Sub-step 3b - Show that the identify barriers would not prevent the implementation of at least one of the alternatives (except the proposed project activity)

21 The speech of Mr. Ü. Tolga Bilgin, chairman of RESSIAD, in 6th Energy Arena on March 9th , 2007 in İstanbul Continental Hotel about the Problems of Renewable Energy (http://www.ressiad.org.tr/makaleler.php?ID=62)

23 “Türkiye Elektrik Piyasasında RES projelerinin Son Durumu”, Murat Durak, Chairman of Turkish Wind Energy Association, Turkish- American Clean Energy Conference, İstanbul, Turkey (http://www.americanturkishcouncil.org/events/cleanenergy/pdf/WednesdayBallroom1/DurakMurat_2008CleanEnergy.pdf)

Deleted: Firstly,

Deleted: Furthermore, wind energy cannot compete with conventional energy as the electricity is not continuously fed from wind power plants and needs to be balanced in pool of energy sources. ¶¶Finally, the annual fee for the usage of the interconnection line is determined in accordance with the established capacity of the power plant by TEİAŞ. However; conventional power plants tend to utilise 80-85% of their established capacity whereas wind power plants only utilise 30-45%. This means a thermal power plant and wind power plant with the same established capacity will pay the same annual fee but wind power plant will produce significantly less electricity22.

Deleted: In addition to the general barriers mentioned above, a specific barrier faced by the project is the construction phase of the project. The project design involves the construction of a road to the site which is a significant extra cost. The Project also includes construction of 2 km transmission wiring from Belen WPP to the transmission station.


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(2) The baseline alternative is defined as provision of equivalent amount of annual power output by the grid where the proposed project is connected. The barriers analysed above don’t prevent the baseline alternative from implementation. Step.4. Common practice analysis Sub-step 4a: Analyse other activities similar to the proposed project activity: (1) The wind power plant projects in Turkey, either under operation or construction, have been listed in Table.13.with the basic information. The investments to wind power have increased in 2006 and populated in 2008 as it can be seen from the table. The capacities of the plants which became operational in 2006 are much higher than the plants previously commissioned in 1998 and 2000. In the past, the very few wind farms that were built in Turkey were developed as Build and Operate (BO) or Build Operate and Transfer (BOT) protocols with the government in accordance with Energy Market Law. This model is no longer available and the reduced risk that the government-backed contracts provided is not longer available. Most of the projects constructed in 2006 and thereafter have been registered as either Gold Standard (GS) or Verified Emission Reduction (VER) projects and are benefiting from carbon finance to make them financially attractive and overcome the other barriers they face. Table.13. Wind Projects in Turkey23

Wind Projects in Turkey (as of 22 January, 2008)

NO Location Company Comm. Date

Installed capacity (MW)

Turbine Manufacturer

Developed as

Turbine capacity

1 İzmir-Çeşme Alize A.Ş. 1998 1.5 Enercon BOT 3 turbines, 500 kW 2 İzmir- Çeşme Güçbirliği

A.Ş. 1998 7.2 Vestas BOT 12 turbines, 600kW

3 Çanakkale-Bozcaada

Bores A.Ş. 2000 10.2 Enercon BOT 17 turbines, 600kW

4 İstanbul- Hadımköy

Sunjüt A.Ş. 2003 1.2 Enercon BOT 2 turbines, 600kW

5 Balıkesir-Bandırma

Bares A.Ş. I/2006 30 GE VER 20 turbines, 1500 kW

6 İstanbul-Silivri Ertürk A.Ş. II/2006 0.85 Vestas BO 1 turbine, 850 kW 7 İzmir-Çeşme Mare A.Ş. I/2007 39.2 Enercon GS 49 turbines, 800 kW 8 Manisa-Akhisar Deniz A.Ş. I/2007 10.8 Vestas VER 6 turbines, 1800 kW 9 Çanakkale-

İntepe Anemon A.Ş.

I/2007 30.4 Enercon GS 38 turbines, 800 kW

10 Çanakkale-Gelibolu

Doğal A.Ş. II/2007 14.9 Enercon GS* 13 turbines, 800 kW+ 5 turbines 900 kW

CAPACITY UNDER OPERATION 146.25 11 Hatay-

Samandağ Deniz A.Ş. I/2008 30 Vestas VER 15 turbines, 2000

kW 12 Manisa-Sayalar Doğal A.Ş. I/2008 30.4 Enercon GS 38 turbines, 800 kW 13 İstanbul-

Kemerburgaz Lodos A.Ş. I/2008 24 Enercon GS* 12 turbines, 2000

kW 14 İstanbul-

Çatalca Ertürk A.Ş. I/2008 60 Vestas GS 20 turbines, 3000

kW


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15 İzmir- Aliağa Innores A.Ş.

I/2008 42.5 Nordex GS 17 turbines, 2500 kW

16 Balıkesir- Şamlı Baki A.Ş. I/2008 90 Vestas GS 30 turbines, 3000 kW

CAPACITY UNDER CONSTRUCTION 276.9 *awaiting GS validation

Sub-step 4b: Discuss any similar Options that are occurring: (2)The 11th project, recently built in Hatay-Samandağ Wind Power Plant Project has a comparable size and location to the project activity, however; it is already developed as VER project. All the wind power projects are facing the same barriers and require financial aid either by VER revenue or BO, BOT protocols to be realised. B.4. Description of how the definition of the project boundary related to the baseline methodology selected is applied to the project activity: The project boundary consists of the Turkish National Electricity Grid. All of the Turkish electricity network is interconnected and there are no separate regional electricity grids. The emission factor for electricity imported from neighbouring countries has been taken as “0” during the calculations. B.5. Details of baseline information, including the date of completion of the baseline study and the name of person (s)/entity (ies) determining the baseline: Date of completion of the baseline study: 6th May 2008 Baseline determined by ClimateCare and Belen Elektrik Üretim A.Ş. Contact Person: Aslı Sezer Özçelik

Z. Pınar Öztürk Telephone: +90 312 439 95 03 Fax: +90 312 439 95 06 E-mail: [email protected], [email protected] Address: Refik Belendir Sokak 35/3 Y. Ayrancı - ANKARA / TURKEY

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SECTION C. Duration of the project activity / Crediting period C.1 Duration of the project activity: C.1.1. Starting date of the project activity: Construction of the project is expected to start in June 2008. Estimated commissioning date is April 2009. C.1.2. Expected operational lifetime of the project activity: Expected operational lifetime of the project activity is 25 years C.2 Choice of the crediting period and related information: Renewable crediting period of three times seven years will be used. C.2.1. Renewable crediting period C.2.1.1. Starting date of the first crediting period:

First crediting period of the project is expected to start in 01/10/2009. C.2.1.2. Length of the first crediting period:

Length of first crediting period is 7 years C.2.2. Fixed crediting period: C.2.2.1. Starting date: NA C.2.2.2. Length: NA


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SECTION D. Application of a monitoring methodology and plan D.1. Name and reference of approved monitoring methodology applied to the project activity: Monitoring methodology applied to the project is ACM0002 version 7, “Consolidated monitoring methodology for grid connected electricity generation from renewable resources” D.2. Justification of the choice of the methodology and why it is applicable to the project activity: The project activity fulfils the criteria of the selected methodology;

• Project is a grid connected electricity generation project using wind power • Project boundary is clearly identified and information about characteristic of the grid is available • Project does not involve fuel switching activity.

D.2. 1. OPTION 1: Monitoring of the emissions in the project scenario and the baseline scenario Since the selected baseline is the grid supplied electricity and the project activity is zero emission electricity generation from wind power, option 1 is not applicable to the project. D.2.1.1. Data to be collected in order to monitor emissions from the project activity, and how this data will be archived: ID number (Please use numbers to ease cross-referencing to D.3)

Data variable

Source of data

Data unit

Measured (m), calculated (c) or estimated

(e)

Recording frequency

Proportion of data to be monitored

How will the data be archived? (electronic/ paper)

Comment

N/A


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D.2.1.2. Data to be collected in order to monitor project performance on the most sensitive sustainable development indicators: Sustainable Development Indicator

Data type Data variable

Data unit

Measured (m), calculated (c) or estimated (e)

N/A D.2.1.3. Description of formulae used to estimate project emissions (for each gas, source, formulae/algorithm, emissions units of CO2 equ.) N/A D.2.1.3. Relevant data necessary for determining the baseline of anthropogenic emissions by sources of GHGs within the project boundary and how such data will be collected and archived : ID number (Please use numbers to ease cross-referencing to table D.3)

Data variable

Source of data

Data unit

Measured (m), calculated (c), estimated (e),

Recording frequency


How will the data be archived? (electronic/

paper)

Comment

N/A

D.2.1.4. Description of formulae used to estimate baseline emissions (for each gas, source, formulae/algorithm, emissions units of CO2 equ.) N/A


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D. 2.2. OPTION 2: Direct monitoring of emission reductions from the project activity (values should be consistent with those in section E). D.2.2.1. Data to be collected in order to monitor emissions from the project activity, and how this data will be archived: ID number (Please use numbers to ease cross-referencing to table D.3)

Data variable

Source of data

Data unit

Measured (m), calculated (c), estimated (e),

Recording frequency


How will the data be archived? (electronic/

paper)

Comment

D1 GENy-Net electricity generated by the plant

TEİAŞ and Project Owner

MWh m Continuous 100% Electronic and Paper Electricity generated by the project activity and supplied to the grid can be monitored through metering devices and

invoices

D2 GDy Equipment counter and project owner

Litre m Continuous 100% Paper Although the amount is negligible, emission from auxiliary power source is considered for a more accurate result.

D.2.2.2. Description of formulae used to calculate project emissions (for each gas, source, formulae/algorithm, emissions units of CO2 equ.):

The only project emission will be originated from use of diesel generator as auxiliary power equipment. The amount of fuel consumed will be monitored annually in order to calculate the emission from use of auxiliary equipment. Following formula will be used:

Pe = (FDy) × NCVdiesel x COEFdiesel

Pe: Project emissions from diesel generator (tCO2) FDy : Annual diesel fuel consumption (Litres) NCVdiesel: Net Calorific Value for diesel oil (TJ/m3) COEFdiesel: CO2 emission coefficient for diesel oil (tCO2/TJ)

The generator will be used for power outage and therefore fuel consumption is expected to be low. The emissions due to diesel consumption will be determined during verification process.


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D.2.3. Treatment of leakage in the monitoring plan No source of leakage is determined within the project boundary. D.2.3.1. If applicable, please describe the data and information that will be collected in order to monitor leakage effects of the project activity ID number (Please use numbers to ease cross-referencing to table D.3)

Data variable

Source of data

Data unit

Measured (m), calculated (c) or estimated (e)

Recording frequency


How will the data be archived? (electronic/ paper)

Comment

N/A D.2.3.2. Description of formulae used to estimate leakage (for each gas, source, formulae/algorithm, emissions units of CO2 equ.) N/A D.2.4. Description of formulae used to estimate emission reductions for the project activity (for each gas, source, formulae/algorithm, emissions units of CO2 equ.) Details of the calculations for baseline emission have been given in section B.2. D.3. Quality control (QC) and quality assurance (QA) procedures are being undertaken for data monitored The monthly electricity generated by the project is the only data to be monitored in order to determine annual emission reduction. The electricity generated will be already recorded by TEİAŞ and the project owner for billing of the electricity supplied to the grid by two separate metering devices, one of which will provide the data for the monthly invoicing to TEİAŞ. The collected data will be kept by Belen Elektrik Üretim A.Ş. during the crediting period and the following two years, after the last issuance of VERs.

Data (Indicate table and ID number e.g. 3.-1.; 3.2.)

Uncertainty level of data (High/Medium/Low)

Explain QA/QC procedures planned for these data, or why such procedures are not necessary.

D1 Low Since same data is also used for billing by TEİAŞ, it will be measured very accurately as explained above.


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D.4. Please describe the operational and management structure that the project operator will implement in order to monitor emission reductions and any leakage effects, generated by the project activity The emission reduction will be monitored by the amount of electricity generated by the project activity. This will be measured and recorded monthly by both TEİAŞ and project owner. There is no need for an additional protocol for VER activity. The emission reduction generated by the project will be calculated by multiplying the annual electricity generated in MWh with combined margin emission factor in tCO2/MWh. JP Morgan will also monitor the process for validation and verification purposes. D.5 Name of person/entity determining the monitoring methodology: ClimateCare (Project Partner) Telephone: +90 312 439 95 03 Fax: +90 312 439 95 06 E-mail: [email protected]


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SECTION E. Estimation of GHG emissions by sources E.1. Estimate of GHG emissions by sources: The project activity involves zero emission as the electricity is generated by wind power. There will not be any GHG generation by project activities. E.2. Estimated leakage: No leakage is expected for project activities E.3. The sum of E.1 and E.2 representing the project activity emissions: GHG emission by project activities is zero. E.4. Estimated anthropogenic emissions by sources of greenhouse gases of the baseline: The thermal power plants connected to the national grid are sources of baseline emission. The emission factor for baseline scenario, OM, has been calculated with the most recent data available (Annex 2). The Combined Margin emission factor is 0.647 tCO2/MWh and annual electricity generation is 96,710 MWh for the project. This will save a total of about 62,572 tCO2e per annum. E.5. Difference between E.4 and E.3 representing the emission reductions of the project activity: Since the project activity will not cause any GHG emission, the emission generated by baseline scenario will be equal to the amount of emission reduction by the project. E.6. Table providing values obtained when applying formulae above: Year Estimation of project

activity emission reductions (tonnes CO2

e)

Estimation of baseline emission reduction (tonnes

CO2 e)

Estimation of leakage (tonnes CO2

e)

Estimation of emission

reductions (tonnes CO2 e)

Oct. 2009 0 15,643 0 15,643 2010 0 62,572 0 62,572 2011 0 62,572 0 62,572

2012 0 62,572 0 62,572

2013 0 62,572 0 62,572

2014 0 62,572 0 62,572

2015 0 62,572 0 62,572

Oct. 2016 0 46,929 0 46,929 Total 0 438,000 0 438,000

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SECTION F. Environmental impacts F.1. Documentation on the analysis of the environmental impacts, including transboundary impacts: Environmental Impact Assessment (EIA) is not mandatory for wind power plants according to the national legislations. However; it may be requested by the relevant agency after the project introductory document is submitted. Ministry of Environment and Forestry (MoEF) has approved that EIA is not required for the project activity after reviewing introductory project document for the Belen WPP project (Annex 5) The Gold Standard sustainable development matrix of the project activity has a total score of +6 with no negative effects (see Section A.2). Therefore; EIA is not required in accordance with the Gold Standard rules as well. However; following minor environmental impacts are required to be mentioned:

• Some trees will be cut in order to widen the entrance road to the site for about 1 km and to clear the surroundings of the turbines (Figure.6 and 7).

The forest is a red pine growth management site and trees are cut/planted periodically. Open spaces are left for the animals living in forest as well. Although, those open spaces will be used for switchgear building and the turbines to keep tree cutting at a minimum, the local Forest Management is contacted for new trees to be planted in return of the ones needed to be cut.

• The local minibus station (yellow building in Figure.6.) will be demolished to enlarge the road as well. The construction company will build a new one afterwards.

Figure.6. The entrance road to the site is narrow for construction vehicles.

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Figure.7. The turbines will be erected on the open areas but a few trees are still required to be cut.

• The locations of the turbines are on an important bird migration route. However; the literature research showed that the bird deaths due to wind turbines are negligible compared to human infringement, environmental despoliation, and collisions with man-made objects24. In addition, radar studies from Tjaereborg in the western part of Denmark, where a 2 megawatt wind turbine with 60 metre rotor diameter is installed, show that birds - by day or night - tend to change their flight route some 100-200 metres before the turbine and pass above the turbine at a safe distance25.

F.2. If environmental impacts are considered significant by the project participants or the host Party, please provide conclusions and all references to support documentation of an environmental impact assessment undertaken in accordance with the procedures as required by the host Party: No significant environmental impact has been determined.

24 M. Sagrillo, Putting Wind Powers Effect on Birds in Perspective, American Wind Energy Association, 2003(http://www.awea.org/faq/sagrillo/swbirds.html), 20.03.2008

25 Dutch Wind Industry Association (http://www.windpower.org/en/tour/env/birds.htm), 20.03.2008

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SECTION G. Stakeholders’ comments G.1. Brief description how comments by local stakeholders have been invited and compiled: The initial Stakeholder consultation meeting was held on 08.04.2008, at 15:30 in Halilbey District where the project area is located nearby. The content, date and time of the meeting has been announced in local (Yeni Belen) and national (Posta) newspapers. All the stakeholders including central and local governmental agencies, local NGOs and GS endorsed NGOs have been invited to the meeting by fax or email. General information about the climate change, voluntary carbon market and Gold Standard certification has been given as an introduction. A brief summary of the PDD including some technical details of the project, calculated emission reduction and monitoring has been given. Local people were not familiar with wind power plants. Some picture shots of wind power plants in construction phase and operational phase were distributed to them (Figure.8).

Figure.8. Initial stakeholder consultation meeting Foreseen possible environmental effects are explained for construction phase and operational phase and it is clearly stated that there will be no significant environmental impact on either human health or surrounding ecosystem. The Public Consultation Checklists are distributed to the stakeholders and they are asked to fill them down. The representative from Directorate of Hatay Environment and Forestry has also acknowledged that the project has no emissions, liquid or solid waste which would have significant impacts. In addition, it was stated that some trees will be cut in order to enlarge the road to the site and to clear the surroundings of the turbines. However; it was assured that new plantation will be done in return by local Forestry Management and a pre-defined fee will be paid for each planted tree by the construction company. Those trees will be followed until they grow up to 10 years old by the management. The project developers have also stated that they are fully aware of importance of Belen for being on one of the bird migration routes. They also explained that the literature showed that the bird death rate due to wind turbines is negligible compared to human infringement, environmental despoliation, and collisions with man-made objects. In addition, radar studies from Tjaereborg in the western part of Denmark, where a 2 megawatt wind turbine with 60

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metre rotor diameter is installed, show that birds - by day or night - tend to change their flight route some 100-200 metres before the turbine and pass above the turbine at a safe distance. The representative from Iskenderun Environmental Protection association has stated that they support those kinds of projects and when the wildlife is the point at issue, the site selection should be done carefully. Finally, the Mayor made a speech to say that the project will bring benefits to the country in terms of implementation of clean technologies. He said those kind of investments are always welcomed in the region (Figure.9.).

Figure.9. Mayor, making a speech to local people.

Main Stakeholder Consultation Main Stakeholder Consultation Meeting has been held on 02.June.2008. All the stakeholders including central and local governmental agencies, local NGOs and GS endorsed NGOs have been invited to the meeting by fax or email. A nontechnical summary of the PDD in local language has been provided to them as well. The issues which have been raised in the Initial Stakeholder Consultation were discussed during the meeting. A brief summary of the PDD has been presented to the attendees. Checklists have been distributed in order to ease any comments for the project. One of the residents asked whether the project would emit any radiation and it was clarified again that there would be no negative impacts for the human health. Some of residents were concerned about the local minibus station which will be demolished for the road enlargement. The representative from Belen Elektrik Üretim A.Ş. confirmed that the building will be re-constructed and any harm given to common sites will be mitigated. It was also mentioned that those kinds of impacts would be monitored curing the implementation of the project as a procedure of Gold Standard. The questions about job opportunities and construction period have been raised. The representative from Belen Elektrik Üretim A.Ş. explained that the construction will begin in fourth quarter of this year and local people will be hired. He also added that there may be permanent job opportunities for qualified local people.

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G.2. Summary of the comments received: The questions asked by the participants and answers are as follows:

- How was the selection of the site done and will there be any other projects in future?

Prefeasibility studies including measurements of wind speed in different locations have been done for the selection of the site. There may be other projects in the place depending on the opportunities.

- Will the construction of power plant affect the price of electricity in the town?

The electricity will be connected to the national grid and will be distributed countrywide. Therefore; there would not be any advantages for the local people in terms of electricity price. However, the project will enable usage of local resources for electricity production. This may reduce the demand on imported electricity and may affect the price indirectly by reducing or keeping it steady in future.

- Will cutting of trees increase the risk of erosion?

The number of trees to be cut is not high enough to oppose a risk of erosion in the area.

- How will the security be provided for the turbines?

The turbines will be surrounded by security barriers. People are not allowed to approach the turbines not closer than a certain distance.

- What is the risk of fire and which precautions have been taken?

There exists a fire risk but necessary precautions will be taken. In case of fire or any emergency situation, the personnel will inform the local authorities and react together with them.

- What will be the employment opportunities for the local people?

The workers will be hired from local people during construction phase and some of the personnel could be employed for the operation of the turbines.

- What may the effects on tourism sector in the area?

It has stated that tourism has been affected positively by wind power plants in some areas in Turkey. Educational trips may be organised for schools to raise awareness in climate change issues. G.3. Report on how due account was taken of any comments received: Comments by the participants were noted during meeting and Public Consultation Checklists are evaluated. No significant effects which would require a revision in the project has been determined. Requests of local people about employment have been positively responded by the construction firm, Belen Elektrik Üretim A.Ş. Invitation List and Attendee List have been submitted in Annex.4.


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Annex 1 CONTACT INFORMATION ON PARTICIPANTS IN THE PROJECT ACTIVITY

Organization: JPMorgan ventures Energy Corporation Street/P.O.Box: Refik Belendir Sokak Y. Ayrancı - Çankaya Building: 35/3 City: ANKARA State/Region: Postfix/ZIP: Country: TURKEY Telephone: +90 312 439 95 03 / +90 312 439 95 04 FAX: +90 312 439 95 06 E-Mail: [email protected] URL: www.jpmorganclimatecare.com Represented by: Title: Country Manager Salutation: Last Name: Sezer Özçelik Middle Name: Ganime First Name: Aslı Department: Mobile: Direct FAX: Direct tel: Personal E-Mail: [email protected] Organization: Belen Elektrik Üretim A.Ş. Street/P.O.Box: Ankara-Konya Devlet Karayolu Building: 23. km P.K.15 City: ANKARA State/Region: Postfix/ZIP: 06831 Country: TURKEY Telephone: +90 312 484 05 70 FAX: +90 312 484 61 19 E-Mail: [email protected] URL: www.guris.com.tr Represented by: Title: General Manager Salutation: Last Name: Yakın Middle Name: First Name: Necdet Department: Mobile: Direct FAX: Direct tel: Personal E-Mail: [email protected]

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Annex 2

BASELINE INFORMATION

Data Used in calculation of OM for Turkish Electricity Grid

Table.1. Heating Values of Fuels Consumed in Thermal Power Plants in Turkey by the Electric Utilities (Tcal)26

Years 2004 2005 2006

Hard Coal 4,790 5,551 29,504

Imported Coal 19,728 20,984

Lignite 61,018 68,513 83,932

Total 85,536 95,048 113,436

Fuel Oil 22,926 19,263 16,769

Diesel Oil 295 291 627

Lpg 139 142 0

Naphta 2,197 895 141

TOTAL 25,557 20,591 17,537

Natural Gas 117,464 140,350 150,588

TOTAL 228,557 255,989 281,561

Table.2. Fuel Consumed in Thermal Power Plants in Turkey by the Electric Utilities (Tcal)27

Years 2004 2005 2006

Hard Coal 1,327,603 1,702,228 5,617,863 Imported Coal 3,237,110 3,556,830

Lignite 33,776,660 48,319,143 50,583,810 TOTAL 38,341,373 53,578,201 56,201,673 Fuel Oil 2,403,338 2,005,899 1,746,370 Diesel Oil 29,141 28,442 61,501 Lpg 12,673 12,908 33 Naphta 208,749 84,481 13,453 TOTAL 2,653,901 2,131,730 1,821,357 Natural Gas 13,325,721 15,756,764 17,034,548 26 Heating Values Of Fuels Consumed In Thermal P.Ps In Turkey By The Electric Utilities (2000-2005) &(2006), (http: //www.teias.gov.tr/ist2006/index.htm). 27

Fuel Consumed in Thermal P.P.in Turkey by the Electric Utilities (2000-2005)&(2006) (http://www.teias.gov.tr/ist2006/index.htm)

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Table.3 . Net Electricity supply to the grid by thermal plants and imports.28

Year Gross

generation Net generation NET/Gross

Gross Gen. Thermal

Net Gen Thermal

Import Total

2004 150,698.0 145,066.0 0.963 104,464.0 100,559.0 1,144.0 101,703.0

2005 161,956.0 155,469.0 0.960 122,242.0 117,346.0 1,798.0 119,140.0

2006 176,299.8 169,543.1 0.962 131,835.1 126,782.5 573.2 127,355.7

Table.4. Default Emission Factors for Stationary Combustion in the Energy Industries (kg of greenhouse gas per TJ on a Net Calorific Basis)29

CO2 Fuel Default Emission Factor Lower Upper

Residual Fuel Oil 77,400 75,500 78,800 Gas/Diesel Oil 74,100 72,600 74,800 Residual Fuel Oil 77,400 75,500 78,800 Liquefied Petroleum Gases 63,100 61,600 65,600 Naptha 73,300 69,300 76,300 Anthracite 98,300 94,600 101,000 Lignite 101,000 90,900 115,000 Natural Gas 56,100 54,300 58,300

Data Used in calculation of BM for Turkish Electricity Grid

Table.5. Generation Units put into Operation in 200430 GENERATION UNITS PUT INTO OPERATION IN 2004

POWER PLANTS

INSTALLED CAPACITY

(MW) ELECTRICITY UTILITIES FUEL TYPE

GENERATION CAPACITY (GWh)

COMMISSIONARY DATE

Average Firm

TÜPRAŞ BATMAN GR V 1.5 AUTOPRODUCERS D.OIL 4.1 4.1 2003

ECZACIBAŞI BAXTER HAS.ÜRÜN. 1.0 AUTOPRODUCERS N.GAS 5.8 5.8 13.01.2001

ÇIRAĞAN SARAYI İŞL. 1.4 AUTOPRODUCERS N.GAS 11.0 11.0 01.11.2002

BAHARİYE MENSUCAT (İzole) 1.0 AUTOPRODUCERS N.GAS 7.0 7.0 01.01.2004

ANKARA D.G.(BAYMİNA) GR-I-II-III 798.0 BOO N.GAS 6500.0 6500.0 08.01.2004

ENTEK GR-IV 31.1 IPP

N.GAS+NAPHTA 255.7 255.7 12.02.2004

ATATEKS 2 GM 5.6 AUTOPRODUCERS N.GAS 45.0 45.0 20.02.2004

TANRIVERDİ 4 GM 4.7 AUTOPRODUCERS N.GAS 38.7 38.7 24.03.2004

VAN SANT (SÖKÜLDÜ) -26.0 IPP FUEL-OIL -195.0 -195.0 06.04.2004

ÇOLAKOĞLU(KAPASİTE ARTIRIMI) 45.0 AUTOPRODUCERS IMPORTED 337.5 337.5 05.05.2004 28

Annual Development of Turkey’s Gross Electricity Generation by Primary Energy Resources and The Electric Utilities (2001-2005) / Turkey’s Gross Electricity Generation by Primary Energy Resources and The Electric Utilities (2006), (http: //www.teias.gov.tr/ist2006/index.htm). 29 Table 2.2.Default Emission Factors for Stationary Combustion in the Energy Industries, Vol.2. Energy, 2006 IPCC Guidelines for National Greenhouse Gas Inventories, (http://www.ipcc-nggip.iges.or.jp/public/2006gl/pdf/2_Volume2/V2_2_Ch2_Stationary_Combustion.pdf) 30

Generation Units Put Into Operation and Out of Operation in 2004, (http://www.teias.gov.tr/ist2004/index.htm)

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COAL

TEKBOY TEKSTİL 1 GM 2.2 AUTOPRODUCERS N.GAS 16.0 16.0 18.05.2004

GÜL ENERJİ GR-II 12.5 AUTOPRODUCERS FUEL-OIL 96.5 96.5 03.06.2004

KOMBASSAN KAĞIT GIDA VE TEKS 5.5 AUTOPRODUCERS N.GAS 38.1 38.1 09.06.2004

AYEN OSTİM ENERJİ ÜRETİM 31.1 IPP N.GAS 264.1 264.1 11.06.2004

BİS ENERJİ 2 GT 73.0 IPP N.GAS 602.7 602.7 16.06.2004

ENERJİ-SA ADANA 1 BT 49.8 AUTOPRODUCERS NAPHTA 322.9 322.9 23.06.2004

ŞAHİNLER ENERJİ 1 GM 3.2 AUTOPRODUCERS N.GAS 22.2 22.2 29.06.2004

BESLER GR-2, BT (5,2+7,5) 12.7 AUTOPRODUCERS N.GAS 97.7 97.7 07.07.2004

KAREGE (Düzeltme) -7.7 IPP N.GAS -57.9 -57.9 08.07.2004

ÇELİK ENERJİ ÜR.ŞTİ. 2 GM 2.4 IPP N.GAS 18.6 18.6 09.07.2004

ÇİNKUR (SÖKÜLDÜ) -30.0 AUTOPRODUCERS FUEL-OIL -150.0 -150.0 20.07.2004

OTOPRODÜKTÖR(DÜZELTME) 6.4 AUTOPRODUCERS 43.2 43.2 20.07.2004

KOMBASSAN KAĞ. MATBAA GIDA 5.5 AUTOPRODUCERS N.GAS 35.7 35.7 24.09.2004

AYEN OSTİM ENERJİ ÜRETİM(BT) 9.9 IPP N.GAS 84.0 84.0 01.10.2004

HABAŞ ALİAĞA GRUP I-II 89.2 AUTOPRODUCERS N.GAS 713.9 713.9 08.10.2004

STANDART PROFİL 3 GM 6.7 AUTOPRODUCERS N.GAS 49.2 49.2 22.10.2004

KARKEY-II 3+3 DGM 54.3 IPP FUEL-OIL 369.7 369.7 12.11.2004

HAKKARİ-1 -15.3 MOBILE D.OIL -114.8 -114.8 30.11.2004

EÜAŞ DÜZELTME(ADALAR) -8.2 EÜAŞ D.OIL 0.0 0.0 09.12.2004

ALTINMARKA GIDA GR I-II-III 3.6 AUTOPRODUCERS N.GAS 28.8 28.8 17.12.2004

THERMAL TOPLAM 1,170.2 9,490.4 9,490.4

ERE(BİR KAPILI HES) GRUP-I 48.5 IPP

RUN OF RIVER 170.6 17.0 11.03.2004

ELTA ELK(DODURGA) GR-I-II-III-IV 4.1 AUTOPRODUCERS

RUN OF RIVER 12.3 0.0 26.04.2004

İSKUR TEKSTİL(SÜLEYMANLI) GRI-II 4.6 AUTOPRODUCERS

RUN OF RIVER 17.86 4.0 28.04.2004

BEREKET EN.(Feslek Hes) Gr-1-2 9.5 AUTOPRODUCERS RUN OF RIVER 41 25.0 05.08.2004

HYDROLIC TOTAL 66.7 241.8 46.0

TOTAL 1,236.9 9,732.2 9,536.4

Table.6. Generation Units put into Operation in 200531

POWER PLANTS INSTALLED

CAPACITY (MW) ELECTRICITY UTILITIES FUEL TYPE

GENERATION CAPACITY (GWh)

COMMISSIONARY DATE

Average Firm

ÇAN GR I 160.000 EÜAŞ LIGNITE 1,040.0 1,040.0 14.02.2001

ÇAN GR II 160.000 EÜAŞ LIGNITE 1,040.0 1,040.0 14.03.2001

ELBİSTAN-B GR I 360.000 EÜAŞ LIGNITE 2,340.0 2,340.0 14.02.2001

AKBAŞLAR GR-II(İZOLE) 8.830 AUTOPRODUCER N.GAS 73.0 73.0 23.06.2001

AKÇA ENERJİ GR-III 8.730 AUTOPRODUCER NAPHTHA 65.4 65.4 13.12.2001

AYKA TEKSTİL GR-I 5.500 AUTOPRODUCER N.GAS 40.0 40.0 23.09.2001

BAYDEMİRLER GR IV-V-VI 6.210 AUTOPRODUCER N.GAS 51.4 51.4 03.02.2001

BOSEN GR-III 50.000 AUTOPRODUCER N.GAS 350.0 350.0 29.12.2001

31

Generation Units Put Into Operation and Out of Operation in 2005, (http://www.teias.gov.tr/ist2005/index.htm)


page 40

ÇUMRA ŞEKER 16.000 AUTOPRODUCER LIGNITE 40.0 40.0 31.12.2000

ETİ MAD.(BAN.ASİT)GR-I 11.500 AUTOPRODUCER RENEW.+WASTES 85.0 85.0 14.07.2001

EVYAP GR I-II 5.120 AUTOPRODUCER N.GAS 30.0 30.0 26.08.2001

GRANİSER GRANİT GR-I 5.500 AUTOPRODUCER N.GAS 42.0 42.0 13.11.2001

HABAŞ ALİAĞA GR III 47.694 AUTOPRODUCER N.GAS 381.6 381.6 01.06.2001

HABAŞ ALİAĞA GR IV 47.694 AUTOPRODUCER N.GAS 381.6 381.6 20.09.2001

HABAŞ ALİAĞA GR-V 24.600 AUTOPRODUCER N.GAS 196.8 196.8 23.11.2001

HABAŞ ALİAĞA (DÜZELTME) 6.158 AUTOPRODUCER N.GAS 49.3 49.3 23.11.2001

HAYAT KAĞIT GR-I 7.531 AUTOPRODUCER N.GAS 56.0 56.0 26.05.2001

İÇDAŞ ÇELİK GR-I 135.000 AUTOPRODUCER IMPORTED COAL 1,080.0 1,080.0 29.11.2001 KAHRAMANMARAŞ KAĞIT GR-I 6.000 AUTOPRODUCER IMPORTED COAL 45.0 45.0 07.12.2001

KORUMA KLOR GR I-II-III 9.600 AUTOPRODUCER N.GAS 77.0 77.0 02.12.2001 KÜÇÜKÇALIK TEKSTİL GR I-II-III-IV 8.000 AUTOPRODUCER N.GAS 64.0 64.0 26.11.2001 MERCEDES BENZ TURK GR I-II-III-IV 8.280 AUTOPRODUCER N.GAS 68.0 68.0 03.02.2001

MODERN ENERJİ GR-III 8.380 AUTOPRODUCER N.GAS 62.9 62.9 13.06.2001

MODERN ENERJİ GR-II 6.720 AUTOPRODUCER LPG 50.4 50.4 13.06.2001

MOSB GR I-II-III-IV-V-VI-VII 84.834 AUTOPRODUCER N.GAS 434.0 434.0 01.03 - 01.08.2005

ORS RULMAN 12.420 AUTOPRODUCER N.GAS 99.4 99.4 24.08.2001

PAK GIDA(Kemalpaşa) GR-I 5.670 AUTOPRODUCER N.GAS 45.0 45.0 06.12.2001

TEZCAN GALVANİZ GR I-II 3.664 AUTOPRODUCER N.GAS 29.0 29.0 26.05.2001 YONGAPAN(KAST.ENTG) GR-II 5.200 AUTOPRODUCER N.GAS 32.7 32.7 24.05.2001

ZEYNEP GİYİM SAN. GR-I 1.165 AUTOPRODUCER N.GAS 9.0 9.0 06.07.2001

OTOP DÜZELTME 0.024 AUTOPRODUCER RENEW.+WASTES 0.0 0.0

OTOP DÜZELTME 2.109 AUTOPRODUCER SOLID 5.2 5.2

OTOP DÜZELTME 0.060 AUTOPRODUCER LIGNITE 0.0 0.0

OTOP DÜZELTME 0.612 AUTOPRODUCER D.OIL 1.8 1.8

AK ENERJİ(K.paşa) GR- III 40.000 IPP N.GAS 256.9 256.9 08.11.2001

AK ENERJİ(K.paşa) GR I-II 87.200 IPP N.GAS 560.1 560.1 29.04.2001

ALTEK ALARKO GR I-II 60.100 IPP N.GAS 420.0 420.0 13.10.2001

BİS ENERJİ GR VII 43.700 IPP N.GAS 360.8 360.8 17.03.2001

CAN ENERJİ GR-I 3.900 IPP N.GAS 28.0 28.0 24.08.2001

ÇEBİ ENERJİ BT 21.000 IPP N.GAS 164.9 164.9 26.08.2001

ÇEBİ ENERJİ GT 43.366 IPP N.GAS 340.1 340.1 22.08.2001 ENTEK ELK.A.Ş.KOÇ ÜNİ.GR I-II 2.332 IPP N.GAS 19.0 19.0 06.02.2001

KAREGE GR IV-V 18.060 IPP N.GAS 141.9 141.9 06.04.2001

KARKEY(SİLOPİ-4) GR-IV 6.150 IPP F.OIL 47.2 47.2 29.06.2001

KARKEY(SİLOPİ-4) GR-V 6.750 IPP F.OIL 51.9 51.9 22.12.2001 METEM ENERJİ(Hacışıramat) GR I-II 7.832 IPP N.GAS 58.0 58.0 28.01.2001 METEM ENERJİ(Peliklik) GR I-II-III 11.748 IPP N.GAS 89.0 89.0 28.01.2001

NOREN ENERJİ GR-I 8.730 IPP N.GAS 70.0 70.0 23.08.2001

NUH ENERJİ-2 GR I 46.950 IPP N.GAS 319.7 319.7 23.05.2001 ZORLU ENERJİ KAYSERİ GR-I-II-III 149.871 IPP N.GAS 1,144.1 1,144.1 21.07.2001

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ZORLU ENERJİ KAYSERİ GR-IV 38.630 IPP N.GAS 294.9 294.9 25.10.2001 ZORLU ENERJİ YALOVA GR I-II 15.930 IPP N.GAS 122.0 122.0 25.11.2001

THERMAL TOTAL 1,757.749 12,236.3 12,236.3

TEKTUĞ(Kargılık) GR I-II 23.900 IPP RUN OF RIVER 83.0 19.0 24.04.2001 İÇTAŞ ENERJİ(Yukarı Mercan) GR I-II 14.190 IPP RUN OF RIVER 44.0 20.0 21.05.2001

MURATLI GR I-II 115.000 EÜAŞ 444.0 400.0 02.06.2001 BEREKET EN.(DALAMAN) GR XIII-XIV-XV 7.500 IPP RUN OF RIVER 35.8 0.0 15.07.2001

YAMULA GRUP I-II 100.000 BOT DAM 422.0 345.0 30.07.2001

HYDROLIC TOTAL 260.590 1,028.8 784.0

SUNJÜT(RES) GR I-II 1.200 AUTOPRODUCER WIND 2.4 2.0 22.04.2001

WIND TOTAL 1.200 2.4 2.0

TOTAL 2,019.539 13,267.5 13,022.3

Table 7 - Generation Units put into Operation in 200632 GENERATION CAPACITY

(GWh) ELECTRIC UTILITIES

INSTALLED CAPACITY Ortalama Güvenilir

(MW) Average Firm

EÜAŞ 1,080.0 7,020.0 7,020.0

OTOPRODÜKTÖR AUTOPRODUCER 143.5 1,086.2 1,086.2

SERBEST ÜR.ŞTİ. IPP 389.8 3,048.8 3,048.8

THERMAL TOTAL THERMAL TOTAL 1,613.3 11,155.0 11,155.0

SERBEST ÜR.ŞTİ. IPP 46.8 188.0 164.5

JEOTER.+RÜZGAR TOP. GEOTHERMAL+WIND TOTAL

46.8 188.0 164.5

EÜAŞ 52.1 124.0 0.0

SERBEST ÜR.ŞTİ. IPP 105.4 358.1 211.0

HYDROLIC TOTAL HYDRO TOTAL 157.5 482.1 211.0

TOTAL GENERAL TOTAL 1,817.6 11,825.1 11,530.5

Table.8. Thermal Power Electricity Utilities put into Operation in 200633

ÜNİTENİN ADI ÜNİTE GÜCÜ

(MW) KURULUŞ ADI YAKIT CİNSİ SERVİSE GİRİŞ

TARİHİ

EKOTEN TEKSTİL GR-I 1.932 OTOPRODÜKTÖR DOĞALGAZ 16.02.2006

ERAK GİYİM GR-I 1.365 OTOPRODÜKTÖR DOĞALGAZ 22.02.2006

ALARKO ALTEK GR-III 21.89 SERBEST ÜRETİM ŞTİ. BUHAR 23.02.2006

AYDIN ÖRME GR-I 7.52 OTOPRODÜKTÖR DOĞALGAZ 25.02.2006

32 Generation Units Put Into Operation and Out of Operation in 2006,(http://www.teias.gov.tr/ist2006/index.htm) 33 Türkiye Elektrik Enerjisi 10 yıllık Üretim Kapasite Projeksiyonu, (2007-2016) (http://www.teias.gov.tr/projeksiyon/projeksiyon%20Temmuz2007.pdf)

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NUH ENERJİ-2 GR II 26.08 SERBEST ÜRETİM ŞTİ. BUHAR TÜRBİNİ 02.03.2006

MARMARA ELEKTRİK (Çorlu) GR I 8.73 SERBEST ÜRETİM ŞTİ. DOĞALGAZ 13.04.2006

MARMARA PAMUK (Çorlu) GR I 8.73 OTOPRODÜKTÖR DOĞALGAZ 13.04.2006

ENTEK (Köseköy) GR IV 47.62 SERBEST ÜRETİM ŞTİ. DOĞALGAZ 14.04.2006

ELSE TEKSTİL (Çorlu) GR I - II 3.16 OTOPRODÜKTÖR DOĞALGAZ 15.04.2006

BARES IX GRUP 13.5 SERBEST ÜRETİM ŞTİ. RÜZGAR 20.04.2006

SÖNMEZ ELEKTRİK (Çorlu) GR I - II 17.46 SERBEST ÜRETİM ŞTİ. DOĞALGAZ 03.05.2006

DENİZLİ ÇİMENTO(DÜZELTME) 0.445 OTOPRODÜKTÖR DOĞALGAZ 04.05.2006

MENDERES ELEKTRİK GR I 7.951 SERBEST ÜRETİM ŞTİ. JEOTERMAL 10.05.2006 KASTAMONU ENTEGRE (Balıkesir) GR I 7.52 OTOPRODÜKTÖR DOĞALGAZ 24.05.2006

BARES X. ve XX. GRUPLAR 16.5 SERBEST ÜRETİM ŞTİ. RÜZGAR 26.05.2006

BOZ ENERJİ GR I 8.73 SERBEST ÜRETİM ŞTİ. DOĞALGAZ 09.06.2006

ADANA ATIK SU ARITMA TESİSİ 0.803 OTOPRODÜKTÖR BİOGAZ 09.06.2006

AMYLUM NİŞASTA (ADANA) -6.2 OTOPRODÜKTÖR FUEL-OİL 09.06.2006

AMYLUM NİŞASTA (ADANA) 14.25 OTOPRODÜKTÖR DOĞALGAZ 09.06.2006

ŞIK MAKAS (Çorlu) GR I 1.58 OTOPRODÜKTÖR DOĞALGAZ 22.06.2006

ELBİSTAN B GR III 360 EÜAŞ LİNYİT 23.06.2006

ANTALYA ENERJİ GR I - II - III - IV 34.92 SERBEST ÜRETİM ŞTİ. DOĞALGAZ 29.06.2006

HAYAT TEM. VE SAĞLIK GR I - II 15.04 OTOPRODÜKTÖR DOĞALGAZ 30.06.2006

EKOLOJİK EN. (Kemerburgaz) GR I 0.98 SERBEST ÜRETİM ŞTİ. ÇÖP GAZI 31.07.2006

EROĞLU GİYİM (Çorlu) GR I 1.165 OTOPRODÜKTÖR DOĞALGAZ 01.08.2006

CAM İŞ ELEKTRİK (Mersin) GR I 126.1 SERBEST ÜRETİM ŞTİ. DOĞALGAZ 13.09.2006

ELBİSTAN B GR II 360 EÜAŞ LİNYİT 17.09.2006

YILDIZ ENT. AĞAÇ (Kocaeli) GR I 6.184 OTOPRODÜKTÖR DOĞALGAZ 21.09.2006

ÇERKEZKÖY ENERJİ GR I 49.164 SERBEST ÜRETİM ŞTİ. DOĞALGAZ 06.10.2006

ENTEK (Köseköy) GR V 37 SERBEST ÜRETİM ŞTİ. DOĞALGAZ 03.11.2006

ITC-KA EN. MAMAK TOP.M. GR I-II-III 4.239 SERBEST ÜRETİM ŞTİ. ÇÖP GAZI 03.11.2006

ELBİSTAN B GR IV 360 EÜAŞ LİNYİT 13.11.2006

MARE MANASTIR RÜZGAR (X GRUP) 8 SERBEST ÜRETİM ŞTİ. RÜZGAR 08.12.2006

ÇIRAĞAN SARAYI GR I 1.324 OTOPRODÜKTÖR DOĞALGAZ 01.12.2006

ERTÜRK ELEKTRİK Tepe RES GR I 0.85 SERBEST ÜRETİM ŞTİ. RÜZGAR 22.12.2006

AKMAYA (Lüleburgaz) GR I 6.91 OTOPRODÜKTÖR DOĞALGAZ 23.12.2006

BURGAZ (Lüleburgaz) GR I 6.91 SERBEST ÜRETİM ŞTİ. DOĞALGAZ 23.12.2006

VAN-2 -24.7

TERMİK TOPLAM 1562.294

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page 43

Table.9. Default CO2 Emission Factors for Combustion34

Effective CO2 Emission Factor (kg/TJ) Fuel type Default Carbon Content (kg/GJ)

Default carbon Oxidation Factor Default 95% Confidence interval

A B C=A*B*44/12*1000 Lower Upper Residual Fuel Oil 21.1 1 77,400 75,500 78,800 Gas/diesel Oil 20.2 1 74,100 72,600 74,800 Liquefied Petroleum Gases

17.2 1 63,100 61,600 65,600

Naptha 20.0 1 73,300 69,300 76,300 Anthracite 26.8 1 98,300 94,600 101,000 Lignite 27.6 1 101,000 90,900 115,000 Natural Gas 15.3 1 56,100 54,300 58,300

34

Table 1.4.Default CO2 emission factors for Combustion,Vol.2. Energy, 2006 IPCC Guidelines for National Greenhouse Gas Inventories, (http://www.ipcc-nggip.iges.or.jp/public/2006gl/pdf/2_Volume2/V2_1_Ch1_Introduction.pdf)

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page 44

30 TabloX.3.1. Türkiyedeki termik santrallerin adları, bulunduğu yer ve diğer bilgiler, Türkiye Çevre Atlası, MoEF, Ankara 2004, pg.197, (http://www.cedgm.gov.tr/dosya/cevreatlasi/atlasin_metni.pdf

Table.10

. The

nam

es, places and ba

sic inform

ation abou

t The

rmal Pow

er Plants in Turkey3

0


page 45

Data and parameters those are available at validation: Data / Parameter: F i,j y Data unit: Tonnes or cubic meter Description: Amount of fuel i consumed by relevant power plants in Turkey in years 2004, 2005,

2006 Source of data used: Turkish Electrical Distribution Company Web Site (www.teias.gov.tr) Value applied: Data used in calculation of OM emission factor. Justification of the choice of data or description of measurement methods and procedures actually applied :

Data used comply with ACM0002 methodology.

Any comment: Data / Parameter: EG Data unit: MWh Description: Electricity delivered to the grid by corresponding primary energy source Source of data used: Turkish Electrical Distribution Company Web Site (www.teias.gov.tr) Value applied: Data used in calculation of electricity generation by thermal plants. Justification of the choice of data or description of measurement methods and procedures actually applied :


Any comment: Data / Parameter: COEFi, j, y Data unit: tCO2/TJ Description: CO2 emission coefficient of fuel i Source of data used: Revised IPCC Guidelines for National GHG inventories p.2.16, 2.17, Table 2.2. Value applied: See Annex 2 Justification of the choice of data or description of measurement methods and procedures actually applied :


Any comment: Data / Parameter: OXIDi Data unit: - Description: Oxidation factor of fuel i Source of data used: Revised IPCC Guidelines for National GHG inventories p.1.23 Table 1.4. Value applied: 1 Justification of the choice of data or description of measurement methods



page 46

and procedures actually applied : Any comment: Data / Parameter: EFCO2 Data unit: tCO2/Tj Description: CO2 emission factor per unit of fuel i consumed Source of data used: Revised IPCC Guidelines for National GHG inventories p.1.23 Table 1.4. Value applied: In Justification of the choice of data or description of measurement methods and procedures actually applied :


Any comment: Data / Parameter: Capacity additions Data unit: MWh Description: Most recently build power plants for electricity generation to Turkish grid that comprise

20% of the annual generation in most recent year. Source of data used: Turkish Electrical Distribution Company Web Site (www.teias.gov.tr) Value applied: See Annex 2 Justification of the choice of data or description of measurement methods and procedures actually applied :


Any comment: Plants dismantled have been considered as negatively contributed to generation capacity and emission

Data / Parameter: FDy Data unit: liter Description: Amount of diesel fuel consumed by the auxiliary power equipment (Diesel Generator) Source of data used: Counter on the equipment showing the operation hour which can be used to calculate

volume consumed. Data Can be cross checked with invoices of diesel fuel. Value applied: Consumption data will be calculated from equipment’s counter. During the crediting

period and until two years after the last issuance of VERs for the Belen WPP project activity for that crediting period.

Justification of the choice of data or description of measurement methods and procedures actually applied :

Data will be measured continuously using counter on the equipment.

Any comment:


page 47

Data / Parameter: Electrical(generation) efficiency Data unit: - Description: Electrical energy produced compared to the input fuel energy provided Source of data used: MoEF of Turkey, Türkiye Çevre Atlası and EIPPCB Reference Document on Best

Available Techniques for Large Combustion Plants Value applied: See Annex 2 Justification of the choice of data or description of measurement methods and procedures actually applied :


Any comment: Best efficiency values are applied in most case as a conservative approach Data / Parameter: EGy Data unit: MWh Description: Electricity Source of data to be used:

Amount of Electricity supplied to the Grid by the proposed project

Value of data applied for the purpose of calculating expected emission reductions in section B.5

658 GWh from October 2009 till October 2016

Description of measurement methods and procedures to be applied:

Data will be monitored continuously by redundant metering devices, which will provide the data for the monthly invoicing to TEİAŞ. The collected data will be kept by Belen Elektrik Üretim A.Ş. During the crediting period and until two years after the last issuance of VERs for the Belen WPP project activity for that crediting period.

QA/QC procedures to be applied:

There will be two ammeters that will backup each other. Generated electricity will also be monitored by the operator using software for internal monitoring. The invoice of electricity sales will also be a proof for quality and reliability of data.

Any comment:


page 48

Annex 3

MONITORING PLAN

The Monitoring Plan (MP) used for determining the emission reduction by the project is based on the approved methodology ACM0002. MP will be implemented by Belen Elektrik Üretim A.Ş. during all stages of the project activity in conjunction with the PDD of the project. The Project owner will be able to update or revise the MP during operation stage if needed. Project owner will show the best effort to maximise the electricity generation and emission reduction by the project activity. All relevant data will be recorded and kept by the project owner until two years after the completion of the crediting period by project owner. Emission reduction by the project activity will be calculated using electricity generated by Belen WPP. This electricity will displace the power generated by other plants in the grid. A spreadsheet prepared in excel will be used in order to calculate emission reduction. It will be measured monthly through two high precision measuring devices sealed and controlled by TEİAŞ according to the regulations issued of the TEIAS. Data can also be checked from electricity sales invoices and records kept by Belen Üretim A.Ş. for cross-checking. On the other hand, the fuel consumption of the generator will be monitored by invoices together with hours of usage tracked by a counter on the equipment. After cross-checking the two sets of data, the emission from the generator will be calculated by multiplying the annual fuel consumption with NCV and EF values for diesel. Environmental Impacts (mentioned in Section.F) will be monitored by Belen Elektrik Üretim A.Ş. as well. The number of trees to be cut during the construction period will be reported to MoEF and new plantations in return of cut trees will be fully paid in accordance with the Plantation Fees announced by the MoEF35 by Belen Elektrik Üretim A.Ş. The new plantation will be done and monitored by Belen Forestry Management. The bird species under protection in the region has been listed by MoEF. Any bird mortality of those birds should be reported to MoEF and any mitigation measures requested by the Ministry should be implemented by Belen Elektrik Üretim A.Ş. Those measures could be, but not limited to:

• Spikes to the transmission lines • Bird deterrent systems such as visual bird scare repellers

Any damage given to the social buildings and areas (including the garage at the entrance of the road to the site and the cemetery wall) will be mitigated by Belen Elektrik Üretim A.Ş. in cooperation with Belen Municipality.

35Plantation Fees 2008 (http://www.agm.gov.tr/haber_detay.asp?id=84)


page 49

Annex 4

INITIAL STAKEHOLDER CONSULTATION MEETING INVITATION LIST

• Ministry of Environment and Forestry (MoEF) • Ministry of Energy and Natural Resources • Directorate of EIA, MoEF • Provincial Directorate of Hatay, MoEF • Special Provincial Administration of Hatay • Provincial Directorate of Hatay, Ministry of Agriculture and Rural Affairs • Special District Administration of Belen • Forestry Management • Governor of Belen • Belen Municipality • Environmental Protection and Research Foundation • Chamber of Environmental Engineers, Adana • Protection of Natural Life Association • WWF TURKEY • Greenpeace TURKEY • Turkish Foundation for Combating Soil Erosion (TEMA) • Hatay Provincial Environmental Protection • Secretariat of Environmental NGOs of East Mediterranean Region • Foundation for Hatay • Mediterranean Consumers Union • Ahlat Cultural and Environmental Protection Association • İskenderun Environmental Protection Association • Yunus Arıkan (Regional Environmental Centre, REEEP Representative)


page 50

INITIAL STAKEHOLDER CONSULTATION MEETING ATTENDEE LIST

No Name, Surname

Organization/Occupation Contact Details

1 Şemsittin ESER

İskenderun Environmental Protection Association

+90532-2275620

2 Mustafa Seydi Evren

Mayor +90542-2613408

3 Ekrem Kaplan District Governor +90537-5963494

4 Cengiz Erarslan

Provincial Directorate of Hatay, MoEF +90326-2137743

5 Mürüvet Turan

Belen Elektrik Üretim A.Ş. +90542-2431937

6 İsmet Gümüş Ahlat Cultural and Environmental Protection Association

+90505-2474298

7 İsmet Karahan

Forestry Management +90535-5561356

8 Ö. Faruk Kılınç

AKCEV Cultural and Environmental Protection Association

+90535-7133789

9 İbrahim İncecik

Justice and Development Party +90536-4304375

10 Mustafa Saklar

Member of the Municipal Assembly +90537-8402312

11 Fehmi Diker Belen Municipality +90543-3332084

12 Mahmut Kurnaz

Farmer +90533-5443289

13 Ömer Sağlam Belen Municipality +90543-441 76 32

14 Mustafa Sevinir

Provincial Directorate of Hatay, Ministry of Agriculture and Rural Affairs

+90543-441 7632

15 Aslı Özçelik JPMorgan ClimateCare

[email protected]

16 Pınar Öztürk JPMorgan ClimateCare

[email protected]


page 51

Annex 5

EIA EXEMPTION LETTER

Translation: According to the article 17 of the Regulation on Environmental Impact Assesment which is issued on 16 December 2003 and published on official gazette # 25318, EIA is not requested for the project “Belen Wind Power Plant” by Belen Elektrik Uretim A.S. (issued on 18 June 2007 with the number 121 by the Directorate of Environment and Forestry in Hatay).

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grid-connected electricity generation from renewable sources

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