Project Design Document

Transkript

CDM-PDD-FORM
Project design document form for
CDM project activities
(Version 05.0)
Complete this form in accordance with the Attachment “Instructions for filling out the project design
document form for CDM project activities” at the end of this form.
PROJECT DESIGN DOCUMENT (PDD)
Title of the project activity
Yalova Wind Power Plant
Version number of the PDD
1.00
Completion date of the PDD
1/03/2016
Project participant(s)
N/A
Host Party
Republic of Turkey
Sectoral scope and selected
methodology(ies), and where
applicable, selected standardized
baseline(s)
1- Energy industries (renewable - / non-renewable
sources)
ACM0002: Consolidated baseline methodology for gridconnected electricity generation from renewable sources
--- Version 16.0.0
Estimated amount of annual average
112,000 tonnes of CO2e
GHG emission reductions
Appendix 1- Contact information of project participants and responsible persons/ entities
Appendix 2- Affirmation regarding public funding
Appendix 3- Applicability of methodology and standardized baseline
Appendix 4- Further background information on ex ante calculation of emission reductions
Appendix 5- Further background information on monitoring plan
Appendix 6- Summary of post registration changes
Appendix 7- The Legal Framework of the Host Country That Binds the Project Activity
Appendix 8- Certification of the Project Related to EIA
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SECTION A.
A.1.
Description of project activity
Purpose and general description of project activity
The Yalova Wind Power Plant (will be refered to as Yalova WPP from this point forward) is a wind
farm that is planned to be constructed by “AROVA RES Elektrik Üretim A.Ş.(AROVA A.Ş. in short)”
in the vicinity of Mecidiye Village of Armutlu town of Yalova Province. The wind farm is going to
convert the potential energy of the wind into electricity by means of 36 wind turbines with 1.5 MW
capacity each. The total generation capacity of the power plant will be 54 MW.
The project is a large scale, Voluntary Emission Reduction. The host Country is the Republic of
Turkey, which is an Annex-1 Party to the UNFCCC. Although Turkey has ratified the Kyoto
Protocol, due to its special circumstances, Turkey is not listed in Annex-B of the protocol and does
not have a binding emission reduction target. Therefore projects hosted by Turkey are eligible
under the Gold Standard voluntary regime. The type of the project activity fits in the ‘Renewable
Energy Supply” category and this category is defined as “Generation and Delivery of Energy
Services” from “non-fossil” and “non-depleatable” energy sources. The wind turbines will be
imported from abroad (China) whereas, the cabling, transformers and other electromechanical
equipment will be obtained from within country.
To be able to produce and sell electricity to the Turkish national electricity grid the project has
obtained electricity production licence from the Energy Market Regulatory Agency (EMRA) with the
licence number EÜ/3301-11/1991. This licence allows the project owner to produce electricity
using the potential energy of the wind for 49 years.
As shown on the EMRA approved electricity production license the established capacity of Yalova
WPP is 54 MW. The project is expected to produce a total of 145,400.00 MWh of electricity per
year, therefore the plant load factor of the project calculates to be, 30.73 %, as shown in the below
calculation:
The wind farm that will be established in the project site is expected to generate an annual amount of up to
145,400 MWh of electricity per year. The produced electricity will then be connected to the Turkish National
Grid.
The project was developed by AROVA A.Ş. .It was first designed as 54 MW with 60 turbines having 900 KW
each, later the design was improved to allocate 36 units with 1.5 MW capacity each. The project feasibility
studies were finalized in June 2011 . The project construction is expected to start in October 2012 and the
construction is expected to be completed in about one year. The project history in the chronological order is
given as follows (Table 1):
Table 1:Chronological history of the project development .
Date
05/July/2011
23/02/2012
1
11/02/11
August, 2008
16/06/2012
18/06/2012 to
1
Event
Emra Granted project license for the following 49 years
Bird Survey Report No:1 Issued (Preliminary Bird Survey)
Sinovel Wind Group is contracted as the turbine supplier
Yalova WPP Project Introductory File submitted to Yalova Provincial Directorate of
Ministry of Environment and Urban Planning
Mecidiye Village Head (Muhtar) is visited to seek help for the organization of the
LSC Meeting
Invitation letters was sent to relevant stakeholders
This date is onsidered to be the investmet decision date
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21/06/2012
23/6/12
Local Stakeholder Consultation Meeting is announced in Local News Papers
23/6/12
Local Stakeholder Consultation Meeting is announced in Hurriyet News Paper
29/06/2012
Local Stakeholder Consultation Meeting is held in Mecidiye
29/06/2012
Women of the village is visited seperately and they were given information about the
project and their opinion is collected.
The project was granted EIA Not Needed Certification.
31/August/2012
How the project activity will be operating, and the boundary of the project activity (indicated in
broken red line) is outlined in the following figure (Figure 1).
Figure 1: The Schematic representation of the Yalova WPP Project.
In absence of the project activity (same as pre project scenario) equivalent amount of electricity
would have been generated in the national grid which is electricity deficient. The project
contributes to sustainable development by lowering energy costs and the dependency on imported
resources like natural gas and oil. Turkey, being in a region where continuous and powerful wind
resources exist, has great potential to utilise renewable resources for electricity generation2.
One of the Millennium Development Goals of Turkey is defined as “Target.9. Integrate the
principles of sustainable development into country policies and programs and reverse the loss of
environmental resources”. Air pollution is one of the concerns under the heading defined with three
indicators:
• Energy use per $1 Gross Domestic Product: Energy production and consumption have not
reached the desired levels and total energy supply per $1 GDP is below OECD average.
Turkey’s GDP decreased due to the unstable economic environment, however unit price of
energy increased.
• Carbon dioxide emissions (per capita) and consumption of ozone depleting CFCs: CO2
emissions are the highest among the other greenhouse gas (GHG) emissions. 10%
increase in CO2 emissions per capita has been observed between1995-2003.
2
http://www.yesilekonomi.com/yayinlar/yesilkose/yenilenebilir-enerji-kaynaklari.htm (Last visited on 28.10.2010)
http://www.eie.gov.tr/duyurular/YEK/YEKrepa/REPA-duyuru_01.html
http://www.cumhuriyet.com.tr/?hn=149076
http://www.alternaturk.org/turkiyede-ruzgar-enerjisi.php
http://www.solar-santral.com/menu_detay.asp?id=326
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• Proportion of the population using solid fuels.3
The project will contribute to these targets in Millennium Development Goals by:
• Utilising local renewable resources for electricity production and lowering the unit price of
energy,
• Lowering CO2 emissions by promoting clean energy production instead of fossil fuel fired
power plants.
The project also stimulates the economic development as wind power, being an infinite and natural
resource, is ecologically more sustainable than other fossil fuel based choices.
From a local perspective, the project will provide job opportunities for local people and create
household income for them. Associated works such as wiring will be done by local companies and
this will increase their technological capacity in renewable energy projects and will stimulate the
local economy as well.
A.2.
Location of project activity
A.2.1. Host Party
The host party is the Republic of Turkey4.
A.2.2. Region/State/Province etc.
Eastern Mediterranean Geographical Region/ Hatay Province
A.2.3. City/Town/Community etc.
Yalova /Armutlu Town
A.2.4. Physical/Geographical location
The following are the coordinates of the wind Turbines that will constitute the Yalova Wind Farm
(Table 2):
Table 2: The coordinates of the turbines in groups of 6
Turbines
1
2
3
4
5
Latitude
40°35'6.20"N
40°35'3.22"N
40°35'2.75"N
40°34'57.54"N 40°34'53.42"N
6
40°34'52.80"N
Longitude 28°55'26.65"E 28°55'42.76"E 28°55'57.69"E
28°56'7.44"E
28°56'19.32"E 28°56'33.38"E
Turbines
7
10
11
Latitude
40°34'47.38"N 40°34'44.28"N 40°34'39.92"N 40°34'29.45"N 40°34'19.99"N 40°34'49.43"N
8
9
12
Longitude 28°56'45.23"E 28°56'57.27"E
28°57'7.64"E
28°57'36.07"E
28°57'57.67"E 28°57'30.69"E
Turbines
13
15
16
17
Latitude
40°34'45.33"N 40°34'42.51"N 40°34'35.27"N 40°34'41.34"N 40°34'58.55"N 40°35'2.11"N
14
18
Longitude 28°57'44.07"E 28°57'57.38"E 28°58'5.65"E
28°58'26.34"E 28°58'6.11"E
28°57'51.17"E
Turbines
19
20
21
22
24
Latitude
40°35'8.47"N
40°33'2.89"N
40°32'57.21"N 40°32'52.80"N 40°32'49.35"N 40°32'45.31"N
Longitude 28°57'34.84"E 28°54'8.35"E
23
28°54'19.81"E 28°54'31.38"E 28°54'45.01"E
28°54'55.18"E
3
Millennium Development Goals Report, Turkey 2005
The host country Turkey is an Annex 1 country under UNFCCC, and a party to Kyotoprotocol without a binding emission reduction
target. For more detail please visit : http://www.mfa.gov.tr/united-nations-framework-convention-on-climate-change-_unfccc_-and-thekyoto-protocol.en.mfa
4
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Turbines
25
26
27
28
29
30
Latitude
40°32'39.58"N 40°32'32.43"N 40°32'23.85"N 40°32'35.81"N 40°32'36.71"N 40°32'59.31"N
Longitude 28°55'5.24"E
28°55'12.36"E 28°55'25.07"E 28°55'51.61"E
28°55'35.02"E 28°55'9.85"E
Turbines
31
32
34
35
36
Latitude
40°31'19.28"N 40°31'13.13"N 40°31'8.36"N
40°30'58.69"N
40°31'8.25"N
40°31'16.57"N
Longitude 28°50'53.90"E 28°51'1.38"E
33
28°51'12.12"E 28°51'53.80"E
28°51'47.09"E 28°51'37.36"E
The following Figure (Figure 2) shows the project location on Satelite image via Google Earth.
Figure 2: Satelite image showing project location in Turkey
A.3. Technologies and/or measures
The project aims to generate electricity by utilising wind power to supply the increasing national
electricity demand in a more cleaner and sustainable manner. It will reduce the air pollution caused
by the grid connected power plants which are mostly fossil fuel fired.
The project involves installation of 36 wind turbines, each having 1.5 MW capacity, which will be
located in Armutlu, Yalova, Turkey. The total installed capacity is designed to be 54 MW and the
annual electricity generation will be 145,400 MWh. The project is a green field project and in the
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absence of the project activity an equivalent amount of electricity would have been generated in
the fossil fuel based national grid.
The Yalova WPP project will be utilizing Sinovel SL1500-82 turbines that are calculated to provide
outmost yield of electricity in the conditions that are present at the project site.
The characteristics of the Sinovel SL1500-82 type turbines can be listed as follows5:
General data
Rotor
Generator
• Nominal power: 1,500 kW
• Start-up wind speed: 3 m/s
• Output voltage: 690 V
• Rotor diameter: 82.9 m
• Nominal wind speed: 10,5
• Manufacturer: Pitch
• Available model
m/s
Tower
• Minimum hub height: 65 m
• Wind class: IEC II/III
• Maximum wind speed: 20
• Maximum hub height: 100 m
• Offshore model: no
m/s
• Swept area: 5,398 m²
Gear box
• Gear box: yes
• Power density: 3.6 m²/kW
• Speed number: 2
• Number of blades: 3
The following table (Table 3) is a list of the equipment that will be installed to the Yalova Wind
Power Plant:
Table 3: List of Equipments that will be installed to the Yalova Wind Power Plant.
Name of Part
Unit
Anchor Parts
36
Tower Groups
36
Tower Equipment
36
Tower Bolts
36
Blade 1
36
Blade 2
36
Blade 3
36
Nacelle
incl.
36
Accessories
Drive Train
36
Cooling Hood
36
Hub
36
Converter Cabinet
36
Accessory
and
36
Consumable Container
Scada Equipment
1
6
Electricity Meters
2
The project provides sustainable means of electricity generation compared to the fossil fuel fired
thermal power plants. The majority of the electricity generated in the grid is from natural gas fired
power plants and there are no incentives or future targets defined for wind energy by the
government. The know-how and technology will be imported from European countries in the
context of the project which will stimulate the development of wind energy sector in the country.
Thus, the project uses an environmentally safe and sound technology in the project activity.
5
6
Information is taken from the following link: http://www.thewindpower.net/turbine_en_281_sinovel_1500.php (Last visited on 26/02/16)
The electricity meters belong to TEİAŞ, and will be sealed and locked as they will be installed in the main control room.
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A.4. Parties and project participants
Party involved
(host) indicates host Party
AROVA RES Elektrik Üretim
A.Ş. see Annex.1 for contact
details.
Private and/or public
entity(ies) project
participants
(as applicable)
Private entity
Indicate if the Party involved
wishes to be considered as
project participant (Yes/No)
No
A.5. Public funding of project activity
There is no public funding involved in the project activity
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SECTION B.
B.1.
Application of selected approved baseline
methodology and standardized baseline
and
monitoring
Reference of methodology and standardized baseline
The following UNFCCC methodology and its related tools are utilised:
Approved consolidated baseline and monitoring methodology ACM0002 “Consolidated
baseline methodology for grid-connected electricity generation from renewable sources.”
Version 16.0.0.
The Approved Methodology refers to the following tools:
•
•
•
“Tool for the demonstration and assessment of additionality” (Version 07.0.0;
EB 70 -Annex 8 )
“Tool to calculate the emission factor for an electricity system” (Version
04.0.0;EB 75-Annex 15)
“Methodological tool: Investment analysis” (Version 06.0; EB 85-Annex 12)
In addition to this the following tools are utilized:
•
“Methodological Tool: Common practice” (Version 03.1; EB 84 Annex 7)
•
“Methodological Tool to determine the remaining lifetime of equipment”
(Version 01; EB 50 Report Annex 15)
B.2.
Applicability of methodology and standardized baseline
The ACM0002 (version 16.0.0) methodology is applicable to grid-connected renewable power
generation project activities that: (a) install a new power plant at a site where no renewable power
plant was operated prior to the implementation of the project activity (greenfield plant); (b) involve a
capacity addition; (c) involve a retrofit of (an) existing plant(s); or (d) involve a replacement of (an)
existing plant(s).
The choice of methodology ACM0002, Version 16.0.0, is justified as the project activity meets the
following applicability criteria:
Reference
Applicability Criteria
Justification
page
in
ACM0002
(version
16.0.0)
4 paragraph ((a)
The project activity may include The Yalova WPP project activity is the
4
renewable energy power plant/unit of one of Installation of a new wind power plant at
the following types: hydro power plant/unit a site where no renewable power plant
with or without reservoir, wind power was
operated
prior
to
the
plant/unit, geothermal power plant/unit, solar implementation of the project activity
power plant/unit, wave power plant/unit or (Greenfield plant)
tidal power plant/unit;
(b)
In the case of capacity additions,
retrofits, rehabilitations or replacements
(except for wind, solar, wave or tidal power
capacity addition projects the existing
plant/unit started commercial operation prior
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to the start of a minimum historical reference
period of five years, used for the calculation
of baseline emissions and defined in the
baseline emission section, and no capacity
expansion, retrofit, or rehabilitation of the
plant/unit has been undertaken between the
start of this minimum historical reference
period and the implementation of the project
activity.
5 paragraph In case of hydro power plants:
5
One of the following conditions shall apply:
(a) The project activity is implemented in an
existing single or multiple reservoirs, with no
change in the volume of any of reservoirs; or
(b) The project activity is implemented in an
existing single or multiple reservoirs, where
the volume of any of reservoirs is increased
and the power density is increased and the
power density calculated using equation (3),
is greater than 4 W/m2; or
(c)
The project activity results in new
single or multiple reservoirs and the power
density, calculated using equation (3), is
greater than 4 W/m2; or
(d)
The project activity is an integrated
hydro power project involving multiple
reservoirs, where the power density for any of
the reservoirs, calculated using equation (3),
is lower than or equal to 4 W/m2, all of the
following conditions shall apply:
(i)
The power density calculated using
the total installed capacity of the integrated
project, as per equation (4), is greater than 4
W/m2;
(ii)
Water flow between reservoirs is not
used by any other hydropower unit which is
not a part of the project activity;
(iii)
Installed capacity of the power
plant(s) with power density lower than or
equal to 4 W/m2 shall be:
a.
Lower than or equal to 15 MW; and
b.
Less than 10 per cent of the total
installed capacity of integrated hydro power
project.
5 paragraphs In the case of integrated hydro power
6 to 8
projects, project proponent shall:
Demonstrate that water flow from upstream
power plants/units spill directly to the
downstream reservoir and that collectively
constitute to the generation capacity of the
integrated hydro power project; or
Provide an analysis of the water balance
covering the water fed to power units, with all
possible combinations of reservoirs and
without the construction of reservoirs. The
purpose of water balance is to demonstrate
the requirement of specific combination of
reservoirs constructed under CDM project
activity for the optimization of power output.
This demonstration has to be carried out in
the specific scenario of water availability in
different seasons to optimize the water flow
at the inlet of power units. Therefore this
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Not Applicable as the project activity is
not hydro power.
the addition of a new “wind” power plant
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water balance will take into account seasonal
flows from river, tributaries (if any), and
rainfall for minimum five years prior to
implementation of CDM project activity.
5-6
The methodology is not applicable to:
paragraph 9 (e)
Project
activities
that
involve
switching from fossil fuels to renewable
energy sources at the site of the project
activity, since in this case the baseline may
be the continued use of fossil fuels at the site;
(f)
Biomass fired power plants/units.
6 paragraph In the case of retrofits, rehabilitations,
10
replacements, or capacity additions, this
methodology is only applicable if the most
plausible baseline scenario, as a result of the
identification of baseline scenario, is “the
continuation of the current situation, that is to
use the power generation equipment that was
already in use prior to the implementation of
the project activity and undertaking business
as usual maintenance”.
6 paragraph In addition, the applicability conditions
11
included in the tools referred to below apply7.
B.3.
The Project activity is eligible as :
It does not involve switching from fossil
fuels
It is not a biomass fired power plant.
the addition of a new wind power plant ,
and it is not a retrofit, replacement or a
capacity addition project.
Not applicable as the tools referred does
not have additional requirements and is
not used in the case of the project
activity.
Project boundary
Source
Baseline
Scenario
Project
scenario
Electricity
generation
in baseline
(Turkey’s
Grid)
Emission
from the
reservoir
of
the
proposed
project
GHGs
Included?
CO2
CH4
N 2O
Other
Yes
No
No
Main emission source
Minor emission source
Minor emission source
N.A.
N.A.
CO2
No
No
No
N.A.
N.A.
N.A.
N.A.
N.A.
CH4
N 2O
Other
Justification/Explanation
CO2 emission is included in the baseline but the project activity does not emit any of the gases
listed, above .
The project boundary includes net electricity generated and supplied to the Turkish national grid.
B.4.
Establishment and description of baseline scenario
Since the proposed project activity is the installation of a new grid-connected wind power plant,
that is renewable power plant and therefore, the baseline scenario is defined as the following
based on ACM0002 (Version 16.0.0):
7
The condition in the “Combined tool to identify the baseline scenario and demonstrate additionality” that all potential alternative
scenarios to the proposed project activity must be available options to project participants; does not apply to this methodology, as this
methodology only refers to some steps of this tool.
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“Electricity delivered to the grid by the project activity would have otherwise been generated
by the operation of grid-connected power plants and by the addition of new generation
sources, as reflected in the combined margin (CM) calculations described in the. Tool to
calculate the emission factor for an electricity system (v.04.0.0; EB 75-Annex 15).”
Since the proposed project activity is going to be connected to the Turkish national grid, the
baseline scenario of the proposed project is the supply of the equivalent amount of annual power
output by the existing Turkish national grid which is the continued operation of existing power
plants and the addition of new sources to meet electricity demand.
Based on ACM002, baseline emissions are equal to power generated by the project activity that is
delivered to the Turkish national grid, multiplied by the baseline emissions factor. This baseline
emissions factor (EFy) is calculated as the Combined Margin (CM), of which the breakdown and
detailed description is given below in section B.6.
B.5.
Demonstration of additionality
The proposed project activity reduces GHG emissions by substituting fossil fuel based electricity
generation by renewable resources (hydro) based electricity generation.
This part refers to the “Tool for the Demonstration and Assessment of Additionality Version 7.0.0”
and the numbering in this section reflects the Tool’s Guidelines provided at EB 70, Annex 8.
Step 1 - Identification of Alternatives to the project activity consistent with current laws and
regulations
Sub-step 1a - Define alternatives to the project activity:
The tool notifies that “Project activities that apply this tool in context of approved consolidated
methodology ACM0002, only need to identify that there is at least one credible and feasible
alternative that would be more attractive than the proposed project activity.”
The project alternative can be defined as follows:
Continuation of the current situation (No project activity or other alternatives undertaken). This
alternative is the most likely scenario, since there are no legal obligation to implement such a
project and without VER support the project implementation is financially not attractive.
Outcome of Step 1a: The only realistic and credible alternative scenario to the project
activity is Continuation of the current situation, without any project undertaken .
Sub-step 1b. Consistency with mandatory laws and regulations:
The project alternative, the baseline scenario, which is the continuation of the existing situation, is
in compliance with all mandatory applicable and legal and regulatory requirements. Also the
alternative scenario of addition of a new power generation capacity to the grid is regulated by
Energy Market Regulatory Authority (EMRA) who issues the licenses for electricity generation and
is responsible for ensuring that new capacity applies with its rules and regulations. The list of the
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rules and regulations of the host country that a new electricity generation project has to comply
with is given in Appendix 7 .
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
At this step it will be demonstrated that “the proposed project activity is not the most
economically or financially attractive" option. Please note that, at this step, the “Methodological
tool: Investment analysis” Version 06.0 is followed.
Sub-step 2a - Determine appropriate analysis method
There are three options for investment analysis method:
Simple Cost Analysis
Investment Comparison Analysis and
Benchmark Analysis
“Simple Cost Analysis” is not applicable for this project activity as the project generates economic
benefits from sale of electricity to the Turkish national grid”. Investment Comparison Analysis is
also eliminated since the baseline for the project is “the generation of electricity by the existing
grid” and no similar investment alternatives exist. Therefore, Benchmark Analysis is the most
appropriate approach for the evaluation of the project activity.
Sub-step 2b - Option III-Apply benchmark analysis
Internal Rate of Return (IRR) on equity is taken for this project to be the financial indicator for
assessing the financial viability of the project activity..
Equity IRR is the cash flow return to equity shareholders after debt repayments. And therefore also
takes into account the debt repayments. Equity IRR takes into consideration that you use debt for
the project, so the inflows are the cash flows required minus any debt that was raised for the
project. The outflows are cash flows from the project minus any interest and debt repayments.
To be able to assess the financial viability of the project a benchmark to compare the equity IRR is
needed.
The Tool for the Demonstration and Assessment of Additionality Version 7.0.0 (EB 70, Annex 8)
and “the Methodological tool on Investment analysis Version 06.0 state that “...Discount rates
and benchmarks shall be derived from: Government bond rates, increased by a suitable risk
premium to reflect private investment and/or the project type, as substantiated by an
independent (financial) expert or documented by official publicly available financial data”
The “Methodological tool on Investment analysis Version 06.0” , provides the default values for the
expected return on equity as an appendix, and Moody’s index values of most of the CDM
Countries. At the time of investment decision (See Table 1, 11/02/2011) Turkey’s Moody’s index
(Ba2) was comparable to country’s with the same Moody’s index, and same default benchmark
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value from this point of view a reasonable and appropriate benchmark to compare the Equity IRR
can be taken as 12.508 %.
Sub-step 2c - Calculation and comparison of financial indicators
The following parameters are taken into account for the assessment of the investment (Table 4)
and supplementary parameters are provided in the “YalovaFinancialAnalysis” workbook and
submitted to the validating DOE.
Table 4:Major parameters taken into account for the financial analysis and determination of the Equity IRR of
the Yalova Project:
Parameter
Installed Capacity
Expected Annual
Electricity Generation
Expected Average
Annual Emission
Reduction (ER)
Total Investment
Annual Operation Costs
Loan
Loan Period
Electricity Sales Price
VAT
Income Tax
Value
54.00
Unit
MWe
145,400
MWh
85,664
tCO2e
References
EMRA approved Electricity Generation
License of the project activity.
P90 value reported in Site-related Wind
Potential Analysis and Energy Yield
Assessment at the Site Yalova Report by
DEWI
Calculated (see Section B.6 for details)
based on the electricity production data.
49,821,860
Euro
967,098
Euro
40,000,000
Euro
Loan Term Sheet
10
years
Loan Term Sheet
0.55 Euro/KWh Price Guaranteed by the renewable energy
law number 5346
18
%
V.A.T. Law No:3065
20
%
Income Tax Law number 5281
The value of the investment has been depreciated on a reducing balance basis over 20 years,
70 % of the long lasting assets are depreciated over 45 years and the residual book value
(20,781,889.23 €) is added back to the cash flow. The economic life time of a wind power plant
investment is assumed to be about 25 years, based on the default technical life time of a wind
turbine, as listed in Methodological Tool to determine the remaining lifetime of equipmentî
(Version 01; EB 50 Report Annex 15). Even if the facility can last longer years the major
equipment needs to be replaced in every 25 years. As a result the project lifetime is estimated
to be about 25 years, but the investment analysis is done for a time frame of 20 years, as
suggested by "Guidelines on the assessment of investment analysis (Version 05)" of EB 62
Annex 5.
For the assessment of the viability of the project activity the Equity IRR is compared to the
benchmark. The equity IRR is worked out as 10.06%, which is below the benchmark of 12.50%.
Sub-step 2d - Sensitivity Analysis
To be able to conclude if the investment decision is the financially the most attractive alternative or
not, a sensitivity analysis is performed. Three parameters that affect the equity IRR are examined
for the sensitivity analysis:
8
The Moody’s index for turkey at the time of investment decision (September 2010) was assigned to Ba2 see
http://countryeconomy.com/ratings/turkey
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Investment Cost
Operating and Maintenance Cost
Electricity Revenue
The sensitivity analysis is performed for a range of ±10% fluctuations in the above parameters. The
figures in the following table (Table 4) are obtained. Following the "Guidelines on the assessment
of investment analysis (Version 05)" of EB 62 Annex 5 when any of the key variables are increased
or decreased by at least 10%, and the benchmark is not exceeded (also see Figure 5).
Table 5: Sensitivity analysis for the Equity IRR without carbon revenue for the project (Benchmark:
11.55%)
Change
-10%
-5%
5%
10%
Exceed Benchmark?
Investment Cost
12.20%
11.04%
9.22%
8.49%
No
Operating Cost
10.24%
10.15%
9.98%
9.89%
No
Electricity Revenue
8.60%
9.33%
10.78%
11.49%
No
Figure 3: Sensitivity analysis: Fluctuation of the Equity IRR without the carbon revenue, by
changing major parameters that effect the Equity IRR by ±10%
To exceed the benchmark, the electricity revenue must increase by about 17.30 % over the life of
the project, or the investment cost must be reduced by about 11.10 %. The Renewable energy law
only guaranties a minimum price of EURO 0.055 per kWh for renewable energy, and the price that
was announced at the EMRA web site was approximately 6.4 US cents9, indicating that our
estimation for the renewable energy price was reasonable. However, we do not expect an increase
in the electricity revenue related to a price increase and since the project’s electricity production
licence and the design of the project is based on the maximum available capacity of the Yalova
Areas wind stream, and since our entire financial analysis is based on the maximum net electricity
output of the project, a number which was also certified by the project activities electricity
production licence, such an increase based on an increased amount of electricity generation is
also very unlikely.
The investment costs we have considered in our financial analysis was based on a project owner’s
estimates that is baked up by the construction and E&M contracts signed prior to project start. And
as some parameters such as turbine costs was already known the numbers we have considered
are realistic. Therefore these numbers are reasonable and reflect the average market conditions
but are unlikely to go down, as the focus of the project developer is to secure and improve the
electricity yield and therefore they will not be able to cut costs. Therefore it is very unlikely for the
investment cost to finalize below the amounts estimated and shown in the financial analysis.
Outcome of Step 2:
Without the VER revenue the Internal Rate of Return of the project cannot get close to the
benchmark of 12.50 %, with an equity internal rate of return of 10.06%. A fluctuation of ± 10% in
the key parameters also does not make the project exceed the benchmark.
Step 3 - Barrier Analysis
9
The officially announced price for the time of investment decision was 9.67 ykrs/ kWh this converts to approximately 6.4 Dolar Cents.
http://www.epdk.gov.tr/documents/elektrik/mevzuat/kurul_karar/elektrik/Elk_Tarife_Top_Sts_Tetas_2007.zip
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As the investment analysis concludes that the proposed project activity is unlikely to be the most
financially attractive option, the sub step 3- Barrier analysis is optional to be applied and barrier
analysis is not considered for the Yalova WPP.
Step 4: Common Practice Analysis
This step is performed in accordance with the stepwise approach in the Methodological tool:
Common practice (Version 03.1; EB 84 Annex 7). This methodological tool provides a stepwise approach for the conduction of the common practice analysis as referred to in
methodological tool “Tool for the demonstration and assessment of additionality”, the
methodological tool "Combined tool to identify the baseline scenario and demonstrate
additionality", or baseline and monitoring methodologies that use the common practice test for
the demonstration of additionality.
Common Practice Step 1: calculate applicable capacity or output range as +/-50% of the total
design capacity or output of the proposed project activity.
As a renewable energy project, the installed capacity is chosen as an appropriate proxy for “similar
scale”. The power generation capacity of 54 MW of the proposed project activity is selected as the
total design capacity. Therefore, the range from 27 MW to 81 MW is considered as applicable
capacity.
Outcome of Step 1: Applicable capacity range is 27 MW to 81 MW.
Step 2: identify similar projects (both CDM and non-CDM) which fulfill all of the following
conditions:
(a) The projects are located in the applicable geographical area;
(b) The projects apply the same measure as the proposed project activity;
(c) The projects use the same energy source/fuel and feedstock as the proposed project
activity, if a technology switch measure is implemented by the proposed project activity;
(d) The plants in which the projects are implemented produce goods or services with
comparable quality, properties and applications areas (e.g. clinker) as the proposed
project plant;
(e) The capacity or output of the projects is within the applicable capacity or output range
calculated in Step 1;
(f) The projects started commercial operation before the project design document (CDMPDD) is published for global stakeholder consultation or before the start date of
proposed project activity, whichever is earlier for the proposed project activity.10.
The host country is considered as the applicable geographical area, and the facilities that are
identified to be operational as part of the year 2012 grid (the data for years 2013 and 2014 does
not provide a detailed list of the individual power plants) are listed below on Table 6:
10
While identifying similar projects, project participants may also use publicly available information, for example from government
departments, industry associations, international associations on the market penetration of different technologies, etc.
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Table 6: Renewable Energy Power Plants that are operational within the borders of Turkey based on the
Addendum 1 of the TEIAŞ Capacity Projection report that enlist all the operational power units of
11
the Turkish Electricity Grid(http://www.teias.gov.tr/KAPASITEPROJEKSIYONU2012.pdf ).
Name of Facility
Fuel Type
VER Status
Hydro
Ownership Capacity
(MW)
EUAS
27
1.
Almus
2.
3.
Yamanli Iii Himmetli (Mem)
Hydro
Private
27
VCS 1015
Burçbendi (Akkur En.)
Hydro
Private
27.3
VCS 419
4.
Çamlica Iii
Hydro
Private
27.6
VCS 759
5.
Selen El.(Kepezkaya Hes)
Hydro
Private
28
VCS
6.
Cindere Denizli
Hydro
Private
28.2
7.
Günder Reg.(Arik)
Hydro
Private
28.2
VCS 912
8.
Yamanli Iii Gökkaya (Mem)
Hydro
Private
28.5
VCS 1014
9.
Akçay
Hydro
Private
28.8
10.
Alize Enerji (Sarikaya Şarköy)
Wind
Private
28.8
GS577
11.
Feke I (Akkur En.)
Hydro
Private
29.4
VCS 533
12.
Ceykar Bağişli
Hydro
Private
29.6
VCS 657
13.
Datça Res
Wind
Private
29.6
ID: 103000000002478
14.
Çanakkale Res (Enerji-Sa)
Wind
Private
29.9
ID: 103000000002023
15.
Mazi 3
Wind
Private
30
ID: 103000000002528
16.
Wind
Private
30
GS?
17.
Sebenoba (Deniz
Elek.)Samandağ
Seyitali Res (Doruk En.)
Wind
Private
30
ID: 103000000002338
18.
Söke Çatalbük Res (Abk En.)
Wind
Private
30
ID ID: 103000000002274
19.
Ütopya Elektrik
Wind
Private
30
ID: 103000000002255
20.
Bilgin Elek. (Hazar 1-2)
Hydro
ORT
30.1
21.
Tüm En. Pinar
Hydro
Private
30.1
22.
Anemon Enerji (İntepe)
Wind
Private
30.4
23.
Kalen Ener. (Kalen I-Ii)
Hydro
Private
31.3
24.
Ayen Enerji (Akbük)
Wind
Private
31.5
25.
Çamligöze
Hydro
EUAS
32
26.
Karacaören-1
Hydro
EUAS
32
27.
Arpa Hes (Mck El.)
Hydro
Private
32.4
28.
Bağiştaş Ii (Akdeniz El.)
Hydro
Private
32.4
29.
Kepez I-Ii
Hydro
EUAS
32.4
30.
Akdeniz Elek. Mersin Res
Wind
Private
33
31.
Tefen Hes (Aksu)
Hydro
Private
33
32.
Sefaköy (Pure)
Hydro
Private
33.1
33.
Narinkale Hes (Ebd En.)
Hydro
Private
33.5
34.
Kale Hes
Hydro
Private
34.1
VCS 893
35.
Sayalar Rüzgar (Doğal Enerji)
Wind
Private
34.2
ID: 103000000002542
36.
Bares (Bandirma)
Wind
Private
35
GS1072
37.
Murat I-Ii Reg.
Hydro
Private
35.6
PL 1193
38.
Lamas Iii-Iv (Tgt En.)
Hydro
Private
35.7
39.
Belen Hatay
Wind
Private
36
40.
Tuna Hes (Nisan)
Hydro
Private
37.2
11
ID: 103000000002564
ID: 103000000002480
ID:103000000002175
ID: 103000000002526
Please note that in more recent capacity projection reports the detailed list of facilities is not provided since 2012.
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Name of Facility
Fuel Type
VER Status
Hydro
Ownership Capacity
(MW)
Private
37.5
41.
Bereket (Dalaman)
42.
Otluca I Hes (Beyobasi)
Hydro
Private
37.5
VCS755
43.
Muratli Hes (Armahes Elek.)
Hydro
Private
37.7
44.
Hydro
Private
37.8
45.
Ceyhan Hes (Berkman HesEnova)
Yenice
Hydro
EUAS
37.9
46.
Dim Hes (Diler Elek.)
Hydro
Private
38.3
47.
Hydro
Private
38.6
VCS565
48.
Değirmenüstü
(Kahramanmaraş)
Dağpazari Res (Enerji Sa)
Wind
Private
39
ID: 103000000001896
49.
Kayadüzü Res (Baktepe En.)
Wind
Private
39
ID: 103000000001979
50.
Metristepe (Can En.)
Wind
Private
39
ID: 103000000001863
51.
Mare Manastir
Wind
Private
39.2
ID: 103000000002543
52.
Bereket (Mentaş)
Hydro
Private
39.9
53.
Killik Res (Pem En.)
Wind
Private
40
ID: 103000000001982
54.
Hydro
Private
40.2
VCS905
55.
Kalkandere-Yokuşlu Hes(Akim
En.)
Niksar (Başak Reg.)
Hydro
Private
40.2
VCS 1019
56.
Kilavuzlu
Hydro
EUAS
40.5
57.
Tektuğ-Andirin
Hydro
Private
40.5
58.
Ayrancilar Hes Muradiye El.)
Hydro
Private
41.5
59.
Bereket (Koyulhisar)
Hydro
Private
42
60.
Eşen-Ii (Göltaş)
Hydro
Private
43.4
61.
Akres (Akhisar Rüzgar)
Wind
Private
43.8
62.
Diğerleri
Hydro
EUAS
45
63.
Erenler Reg.(Bme Birleşik En.)
Hydro
Private
45
64.
Susurluk (Alantek En.)
Wind
Private
45
65.
Karacaören Ii
Hydro
EUAS
46.4
66.
Bayramhacili (Senerji En.)
Hydro
Private
47
67.
Gürmat En.
Geothermal Private
47.4
68.
Kemer
Hydro
EUAS
48
69.
Manavgat
Hydro
EUAS
48
70.
Enerji-Sa Birkapili
Hydro
Private
48.5
71.
Poyraz Res
Wind
Private
50
72.
Şanli Urfa
Hydro
EUAS
51
73.
Kovada-Ii(Batiçim En.)
Hydro
ORT
51.2
74.
Kapulukaya
Hydro
EUAS
54
75.
KAPULUKAYA
Hydro
EUAS
54
76.
KADINCIK II
Hydro
EUAS
56
77.
DERBENT
Hydro
EUAS
56.4
78.
Hydro
Private
56.8
79.
SEYRANTEPE HES
(SEYRANTEPE BARAJI)
İNNORES ELEK. YUNTDAĞ
Wind
Private
57.5
ID: 103000000002559
80.
ZİYARET RES
Wind
Private
57.5
ID: 103000000002310
Version 05.0
VCS 810
VCS (Listed in GTE'sWeb
Page:http://www.gte.com.tr/hy
dro_above_20MW.asp)
VCS 713
ID: 103000000001974
ID: 103000000002075
VCS (Listed in GTE'sWeb
Page:http://www.gte.com.tr/hy
dro_above_20MW.asp)
ID: 103000000002341
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Name of Facility
Fuel Type
Wind
Ownership Capacity
(MW)
Private
60
81.
BANDIRMA RES (BORASKO)
82.
VER Status
ID: 103000000002183
ERTÜRK ELEKT. (ÇATALCA)
Wind
Private
60
ID: 103000000002544
83.
EŞEN-I (GÖLTAŞ)
Hydro
Private
60
84.
SEYHAN I
Hydro
EUAS
60
85.
ADIGÜZEL
Hydro
EUAS
62
86.
Hydro
Private
62.2
87.
KARADENİZ
ELEK.(UZUNDERE I HES)
BÜYÜKDÜZ HES (AYEN EN.)
Hydro
Private
68.9
88.
DEMİRKÖPRÜ
Hydro
EUAS
69
89.
SUAT UĞURLU
Hydro
EUAS
69
90.
FEKE 2 (AKKUR EN.)
Hydro
Private
69.3
91.
KADINCIK I
Hydro
EUAS
70
92.
AKSU RES (AKSU TEMİZ EN.)
Wind
Private
72
93.
DOĞANKENT
Hydro
EUAS
74.5
94.
KESİKKÖPRÜ
Hydro
EUAS
76
ID: 103000000001796
Outcome of Common Practice Tool Step 2:
There are 94 projects within the comparison range of the project activity, within the selected
geographical boundary.
Step 3: within the projects identified in Step 2, identify those that are neither registered CDM
project activities, project activities submitted for registration, nor project activities undergoing
validation. Note their number Nall.
The above list covers all the renewable energy power plants within the geographical boundary
defined above (host country). Checking all the power plants within the capacity range determined
in Step 1, and looking projects that have started commercial operation before the start date of the
project, and eliminating the ones that do claim VER credits, We end up with the following table
(Table 7):
Table 7 : The list of power plants that are identified to be counted in the Nall list.
NO:
1.
2.
3.
4.
5.
6.
7.
8.
9.
10.
11.
12.
13.
Name of Facility
Almus
Cindere Denizli
Akçay
Bilgin Elek. (Hazar 1-2)
Tüm En. Pinar
Kalen Ener. (Kalen I-Ii)
Çamligöze
Karacaören-1
Arpa Hes (Mck El.)
Bağiştaş Ii (Akdeniz El.)
Kepez I-Ii
Tefen Hes (Aksu)
Sefaköy (Pure)
Version 05.0
Fuel Type
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Ownership
EUAS
Private
Private
ORT
Private
Private
EUAS
EUAS
Private
Private
EUAS
Private
Private
Capacity (MW)
27
28.2
28.8
30.1
30.1
31.3
32
32
32.4
32.4
32.4
33
33.1
Page 18 of 78
14.
15.
16.
17.
18.
19.
20.
21.
22.
23.
24.
25.
26.
27.
28.
29.
30.
31.
32.
33.
34.
35.
36.
37.
38.
Narinkale Hes (Ebd En.)
Lamas Iii-Iv (Tgt En.)
Tuna Hes (Nisan)
Bereket (Dalaman)
Muratli Hes (Armahes Elek.)
Yenice
Dim Hes (Diler Elek.)
Bereket (Mentaş)
Kilavuzlu
Tektuğ-Andirin
Eşen-Ii (Göltaş)
Diğerleri
Erenler Reg.(Bme Birleşik En.)
Karacaören Ii
Gürmat En.
Kemer
Manavgat
Enerji-Sa Birkapili
Şanli Urfa
Kovada-Ii(Batiçim En.)
Kapulukaya
KAPULUKAYA
KADINCIK II
DERBENT
SEYRANTEPE HES (SEYRANTEPE
BARAJI)
EŞEN-I (GÖLTAŞ)
SEYHAN I
ADIGÜZEL
KARADENİZ ELEK.(UZUNDERE I HES)
BÜYÜKDÜZ HES (AYEN EN.)
DEMİRKÖPRÜ
SUAT UĞURLU
FEKE 2 (AKKUR EN.)
KADINCIK I
DOĞANKENT
KESİKKÖPRÜ
39.
40.
41.
42.
43.
44.
45.
46.
47.
48.
49.
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Geothermal
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Private
Private
Private
Private
Private
EUAS
Private
Private
EUAS
Private
Private
EUAS
Private
EUAS
Private
EUAS
EUAS
Private
EUAS
ORT
EUAS
EUAS
EUAS
EUAS
Private
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Private
EUAS
EUAS
Private
Private
EUAS
EUAS
Private
EUAS
EUAS
EUAS
CDM-PDD-FORM
33.5
35.7
37.2
37.5
37.7
37.9
38.3
39.9
40.5
40.5
43.4
45
45
46.4
47.4
48
48
48.5
51
51.2
54
54
56
56.4
56.8
60
60
62
62.2
68.9
69
69
69.3
70
74.5
76
Therefore the number of Nall is 49.
Nall=49
Step 4: within similar projects identified in Step 3, identify those that apply technologies that are
different to the technology applied in the proposed project activity. Note their number Ndiff.
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When we consider the wind power plants listed in Step 3, and comparing their electricity
production technologies to the other projects amongst all 49 in table 7 (See Table 7), non of them
utilises wind turbines and wind power to produce electricity (there is 1 geothermal power plants
and 48 hydroelectric power planst listed in table 7). As the tool suggests the proposed project
activity is utilizing a diferent technology compared to those projects identified as Nall.
Outcome of Common Practice tool Step 4 is Ndiff=49
Step 5: calculate factor F=1-Ndiff/Nall representing the share of similar projects (penetration rate
of the measure/technology) using a measure/technology similar to the measure/technology
used in the proposed project activity that deliver the same output or capacity as the proposed
project activity.
F=1-Ndiff/Nall
F=1-(49/49)
F=0
Conclusion of Common Practice tool version 3.01 (EB 84 Report Annex 7):
The proposed project activity is a “common practice” within a sector in the applicable geographical
area if the factor F is greater than 0.2 and Nall-Ndiff is greater than 3.
Factor F is calculated to be 0 < 0.2.
And,
Nall-Ndiff =49-49=0 <3 in that case the YALOVA WPP is not common practice.
Conclusion: In conclusion the proposed project is deemed to be additional according to ACM0002
and the tool and guideline for the demonstration and assessment of additionality.
B.6.
Emission reductions
B.6.1. Explanation of methodological choices
According to the latest version (version 16.0.0) of ACM0002 and the tool to calculate the emission
factor for electricity system, since the project activity is the installation of a new grid-connected
renewable power plant/unit, the baseline scenario is the following:
Electricity delivered to the grid by the project activity would have otherwise been generated
by the operation of grid-connected power plants and by the addition of new generation
sources, as reflected in the combined margin (CM) calculations described in the “Tool to
calculate the emission factor for an electricity system” (version 04.0.0 (EB 75, Annex 15)).
The Project therefore applies the combined margin (CM) calculations described in the “Tool to
calculate the emission factor for an electricity system” (version 04.0.0 (EB 75, Annex 15)).
Step 1 -Identify the relevant electricity systems
As the host country is not participating in the compliance markets hence does not have a DNA, a
delineation of the project electricity system and connected electricity systems has not been
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CDM-PDD-FORM
published yet. For such cases, the tool suggests using the following criteria to determine the
existence of significant transmission constraints:
1. “In case of electricity systems with spot markets for electricity: there are differences in
electricity prices (without transmission and distribution costs) of more than 5 percent
between the systems during 60 percent or more of the hours of the year.” This criteria is
not applicable as there is no spot electricity market in the host country.
2. “The transmission line is operated at 90% or more of its rated capacity during 90%
percent or more of the hours of the year”: The transmission line operator (TEIAS) or any
other official source has not published the capacity usage figures for the Turkish grid,
hence this criterion can not be proved.
According to the tool, where the application of these criteria does not result in a clear grid
boundary, a regional grid definition in the case of large countries with layered dispatch systems
(e.g. provincial / regional / national) shall be used. A provincial grid definition may indeed in many
cases be too narrow given significant electricity trade among provinces that might be affected,
directly or indirectly, by a CDM project activity. In other countries, the national (or other largest) grid
definition should be used by default.
Therefore, for the case of the subject project activity “the project electricity system” and “the
connected system” are same, and the Turkish National Grid is used as the “project electricity
system”. It is also confirmed by TEIAS that the Turkish grid is interconnected. There isn’t any
independent or regional grid system in any region of Turkey. The map of the Turkish Electricity
Grid is given in the below figure (Figure 7):
Figure 4: The Map showing the boundaries of Turkish Electricity Grid (Source Electricity Market
Report 2010, by Electricity Market Regulatory Authority
http://www.epdk.gov.tr/documents/10157/48dd12d4-74da-4dcf-9f48-86983146c0d8)
All the calculations details of which are given below are made for the entire Turkish Grid.
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For the purpose of determining the operating margin emission factor, the tool directs us to use one
of the following options to determine the CO2 emission factor(s) for net electricity imports from a
connected electricity system:
(a) 0 t CO2/MWh; or
(b) The simple operating margin emission rate of the exporting grid, determined as
described in Step 4 section 6.4.1, if the conditions for this method, as described in Step 3
below, apply to the exporting grid; or
(c) The simple adjusted operating margin emission rate of the exporting grid, determined as
described in Step 4 section 6.4.2 below; or
(d) The weighted average operating margin (OM) emission rate of the exporting grid,
determined as described in Step 4 section 6.4.4 below.
For imports from connected electricity systems located in Annex I country(ies), the emission factor
is 0 tons CO2 per MWh.
The tool also notes that the …”Electricity exports should not be subtracted from electricity
generation data used for calculating and monitoring the electricity emission factors.”
In our case the host country (imports electricity mainly from Annex -1 countries, so the emission
factor related to imports is considered to be zero”0”.
Step 2 - Choose whether to include off-grid power plants in the project electricity system
The tool requires Project participants to choose between the following two options to calculate the
operating margin and build margin emission factor:
Option I: Only grid power plants are included in the calculation.
Option II: Both grid power plants and off-grid power plants are included in the calculation.
In our case, “Option I” has been selected for the calculation of grid emission factor, and only grid
power plants are included in the calculation.
Step 3 – Select an operating margin (OM) method
According to the “Tool to calculate the emission factor for an electricity system‟, version 03.0.0 in
calculating the Operating Margin grid emission factor for a given year y (EFgrid,OM,y), project
developers have the option of selecting from four methods:
(a) Simple OM,
(b) Simple adjusted OM,
(c) Dispatch Data Analysis OM, or
(d) Average OM.
As the share of “low cost/must run” resources are below 50% for the five most recent years (Table
8), therefore, in accordance with the Tool, (a) Simple OM method will be used in the calculations.
Table 8: Share of primary sources in electricity generation, 2010 – 201412
Thermal
Hydro
Wind
&
2010
73.78 %
24.52 %
1.70 %
2011
74.82%
22.81%
2.36%
2012
73.02%
24.16%
2.82%
2013
71.54%
24.74%
3.71%
2014
79.54%
16.13%
4.33%
12
Annual Development of Installed Capacity Generation in Turkey (1970-2013)
http://www.teias.gov.tr/TürkiyeElektrikİstatistikleri/istatistik2014/kgucunkullanım(14-23)/14.xls (File 14)
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Geothermal
Total
100 %
100 %
100%
100%
100%
Since the Simple OM calculation (option (A)) is selected, the emission factor is calculated by the
generation-weighted average emissions per electricity unit (tCO2/GWh), and averaged over the
past three years of all generating sources serving the system, not including low-cost / must run
power plants. The tool gives two options for the calculation of EFgrid, OM, y;
•
Ex-ante option
A 3-year generation-weighted average, based on the most recent data available at the time of
submission of the VER-PDD to the DOE for validation, without the requirement to monitor and
recalculate the emissions factor during the crediting period, or
•
Ex-post option
The year in which the project activity displaces grid electricity, with the requirement that the
emission factor be updated annually during monitoring.
For the calculation of the Simple OM, the “Ex-Ante” option is selected, at the time of PDD
submission to the DOE, the data vintages that were most recent at the start of validation,
belongs to the years 2011, 2012 and 2013. All the data used in calculation of the Simple OM
are taken from the TEIAS website, details of which are given below.
Step 4 - Calculate the operating margin emission factor according to the selected method
The Simple OM emission factor is calculated as the generation-weighted average CO2 emissions
per unit of net electricity generation (tCO2/MWh) for all generating power plants serving the
system, not including low-cost / must run plants / units. It may be calculated:
•
•
Option A: Based on the net electricity generation and a CO2 emission factor of each power unit;
or
Option B: Based on the total net electricity generation of all power plants serving the system
and the fuel types and total fuel consumption of the project electricity system.
The following data are available from the Turkish Electricity Transmission Company (TEİAŞ)
web site:
• Annual fuel consumption by fuel type13,
• Annual heating values for fuels consumed for electricity generation14,
• Annual electricity generation by fuel type, import and export15
Taking into consideration the available data Simple OM method Option B is the applicable method
for the project activity. Option A requires data on net electricity generation of each power plant /
unit and a CO2 emission factor of each power unit, both of which are not publicly available, for the
Turkish electricity grid.
13
Fuel Consumed in thermal P.P.in Turkey by the Electric Utilities (2007-2014)
http://www.teias.gov.tr/TürkiyeElektrikİstatistikleri/istatistik2014/yakıt49-54/50.xls
14
Heating Values Of Fuels Consumed In Thermal P.Ps In Turkey By The Electric Utilities (2012-2014),
http://www.teias.gov.tr/TürkiyeElektrikİstatistikleri/istatistik2014/yakıt49-54/52.xls
15
Annual Development of Turkey’s Gross Electricity Generation by Primary Energy Resources and The Electricity Utilities (2006-2013))
/ (Source: http://www.teias.gov.tr/TürkiyeElektrikİstatistikleri/istatistik2014/uretim%20tuketim(24-48)/43(06-14).xls / Annual Development
of Electricity Generation-Consumption and Losses in Turkey (1984-2014),
(http://www.teias.gov.tr/TürkiyeElektrikİstatistikleri/istatistik2014/uretim%20tuketim(24-48)/35(1984-2014).xls)
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EFgrid,OMsimple,y, using option B is calculated based on the net electricity supplied to the grid by all
power plants serving the system, not including low-cost / must-run power plants / units, and based
on the fuel type(s) and total fuel consumption of the project electricity system, as follows:
(7)
Where:
EFgrid, OM simple,y = Simple operating margin CO2 emission factor in year y (tCO2/MWh)
FCi,y = Amount of fossil fuel type i consumed in the project electricity system in year y
(mass or volume unit)
NCVi,y = Net calorific value (energy content) of fossil fuel type i in year y (GJ/mass or
volume unit)
EFCO2,i,y = CO2 emission factor of fossil fuel type i in year y (tCO2/GJ)
EGy = Net electricity generated and delivered to the grid by all power sources serving the
system, not including low-cost/must-run power plants/units, in year y (MWh)
i = All fossil fuel types combusted in power sources in the project electricity system in year
y
y = The relevant year as per the data vintage chosen in Step 3
Step 5 - Calculate the build margin (BM) emission factor:
The tool indicates that, in terms of vintage of data, project participants can choose between one of
the following two options:
Option 1: For the first crediting period, calculate the build margin emission factor ex ante
based on the most recent information available on units already built for sample group m at
the time of CDM-PDD submission to the DOE for validation. For the second crediting
period, the build margin emission factor should be updated based on the most recent
information available on units already built at the time of submission of the request for
renewal of the crediting period to the DOE. For the third crediting period, the build margin
emission factor calculated for the second crediting period should be used. This option does
not require monitoring the emission factor during the crediting period.
And ,
Option 2: For the first crediting period, the build margin emission factor shall be updated
annually, ex post, including those units built up to the year of registration of the project
activity or, if information up to the year of registration is not yet available, including those
units built up to the latest year for which information is available. For the second crediting
period, the build margin emissions factor shall be calculated ex ante, as described in Option
1 above. For the third crediting period, the build margin emission factor calculated for the
second crediting period should be used.
We prefer the Option 1, calculating the Build Margin Emission factor, “ex ante”, for the first
crediting period.
The sample group of power units m used to calculate the build margin are determined as per the
following procedure, consistent with the data vintage selected above:
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a) Identify the set of five power units, excluding power units registered as CDM project
activities, that started to supply electricity to the grid most recently (SET5-units) and
determine their annual electricity generation (AEGSET-5-units, in MWh);
b) Determine the annual electricity generation of the project electricity system; excluding
power units registered as CDM project activities (AEGtotal, in MWh). Identify the set of
power units, excluding power units registered as CDM project activities, that started to
supply electricity to the grid most recently and that comprise 20% of AEGtotal (if 20%
falls on part of the generation of a unit, the generation of that unit is fully included in the
calculation) (SET≥20%) and determine their annual electricity generation (AEGSET-≥20%, in
MWh);
c) From SET5-units and SET≥20% select the set of power units that comprises the larger
annual electricity generation (SETsample); Identify the date when the power units in
SETsample started to supply electricity to the grid. If none of the power units in SETsample
started to supply electricity to the grid more than 10 years ago, then use SETsample to
calculate the build margin.
According to the tool in terms of vintage of data, project participants can choose either the ex-ante
option or the ex-post option. Between these two options, Option 1 is selected. For the first crediting
period, the build margin emission factor is calculated ex-ante based on the most recent information
available on units already built for sample group m at the time of CDM-PDD submission to the
DOE for validation. For the second crediting period, the build margin emission factor will be
updated based on the most recent information available on units already built at the time of
submission of the request for renewal of the crediting period to the DOE. For the third crediting
period, the build margin emission factor calculated for the second crediting period will be used.
This option does not require monitoring the emission factor during the crediting period.
The build margin emissions factor is the generation-weighted average emission factor (tCO2/MWh)
of all power units m during the most recent year y for which power generation data is available,
calculated as follows:
Where:
EFgrid,BM,y
= Build margin CO2 emission factor in year y (tCO2/MWh)
EGm,y
= Net quantity of electricity generated and delivered to the grid by power unit
m in year y (MWh)
EFEL,m,y
= CO2 emission factor of power unit m in year y (tCO2/MWh)
m
= Power units included in the build margin
y
= Most recent historical year for which electricity generation data is available
According to the tool, the CO2 emission factor of each power unit m (EFEL,m,y) should be determined
as per the guidance in step 4 (a) for the simple OM, using options A1, A2 or A3, using for y the
most recent historical year for which power generation data is available, and using for m the power
units included in the build margin. Taking into consideration the available data on the capacity
additions, the formula given under Option A2 of the Simple OM option A is used to calculate
EFEL,m,y.
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The CO2 emissions from the most recent capacity additions are calculated by multiplying the
EFEL,m,y values calculated for each fuel source by the annual generation of that fuel source (Table
15). The emission factor has been taken as “zero” for the renewable and wastes and the
generation efficiencies for the thermal power plants type of which are not known are taken as 60%
which is generation efficiency for the combined cycle natural gas power plants. The Build Margin
Emission Factor for each year is calculated by dividing the total CO2 Emissions of the subject year
by the total generation from the capacity additions of the same year.
The Build Margin Emission Factor of the grid is then calculated as an average for the years 2010,
2011 and 2012 (the detailed information about the Grid as of years 2013 and 2014 is not
published, so year 2012 data is the most recently available data), as explained in the part where
the actual calculations are shown, the assessed capacities added in these two years constitutes
our SETsample.
Step 6 - Calculation of the combined margin emissions factor
Finally, the combined margin grid emission factor (EFgrid,CM,y) is expressed as the weighted average
of the Operating Margin emission factor (EFgrid,OM,y) and the Build Margin emission factor
(EFgrid,BM,y):
Where:
EFgrid,BM,y
Build margin CO2 emission factor in year y (tCO2/MWh)
EFgrid,OM,y
Operating margin CO2 emission factor in year y (tCO2/MWh)
wOM
Weighting of operating margin emissions factor (%)
wBM
Weighting of build margin emissions factor (%)
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.
Then baseline emissions (BEy) are obtained as:
Where:
BEy
=
Baseline emissions in year y (tCO2/yr)
EGPJ,y
=
Quantity of net electricity generation that is produced and fed into the
grid as a result of the implementation of the CDM project activity in
year y (MWh/yr)
EFgrid,CM,y
=
Combined margin CO2 emissions factor in year y (tCO2/MWh)
And
EG PJ , y = EG facility , y
EGfacility,y
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=
Quantity of net electricity generation supplied by the project plant to the
grid in year y (MWh/yr)
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The ex-ante emission reductions (ERy) are calculated as follows:
ER y = BE y − PE y
Where:
ERy
=
Emission reductions in year y (tCO2)
BEy
=
Baseline emissions in year y (tCO2)
PE,y
=
Project Emissions in year y (tCO2)
As methodology states the PEy in case of a wind power project to be zero hence ERy = BEy
Project Emissions
As the methodology states the PEy in case of a wind power project is considered zero.
Although there will be an emergency/back up diesel generator installed within the project
boundary, the emissions from these have been deemed negligible as per the ACM0002 (version
16.0.0) methodology, since it will be solely utilized in case of an emergency, such as a complete
power outage.
Leakage
There are no leakage emissions related to project activity.
B.6.2. Data and parameters fixed ex ante
(Copy this table for each piece of data and parameter.)
Data / Parameter
FCi,y
Unit
Volume Unit (cubic meter)
Description
Amount of fuel i consumed by relevant power plants in Turkey in
years, 2012, 2013, 2014.
Official publications at the Turkish Electricity Transmission Company
(TEIAŞ) Web Site Fuel Consumed in thermal P.P.in Turkey by the
Source of data
Electric
Utilities
(2007-2014)
http://www.teias.gov.tr/TürkiyeElektrikİstatistikleri/istatistik2014/yakıt4954/50.xls
Value(s) applied
Please Appendix-4-Table-1
Choice of data
or
Measurement
methods
and
procedures
Purpose of data
Additional comment
Data used is taken from the TEİAŞ website, which is the website of
the Turkish Electricity Distribution Company. The data published on
the TEİAŞ website is the most up-to date and reliable data available
for the Turkish grid.
Data / Parameter
NCVi,y
Unit
GJ/Mass or Volume Unit
Description
Net Calorific Values for fossil fuel type i in year, for the years 2012,
2013 and 2014
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Data used for the calculation of EFgrid,OM,Simple,y
-
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Source of data
Regional or national average default values
that are reliable and documented in national
energy statistics of the Turkish Electricity Transmission Company
Web Site
Value(s) applied
Please see Appendix-4-Table-5
Choice of data
or
Measurement
methods
and
procedures
Purpose of data
the TEİAŞ website is the most up-to date and reliable data available
for the Turkish grid.
Additional comment
Data used for the calculation of EFgrid,OM,Simple,y. As data on the NCV
is not published directly on the TEİAŞ website, this data is
calculated using the heating values of fuels and the volume or mass
of fuels consumed for each year.
-
Data / Parameter
EFCO2,i,y
Unit
tCO2/GJ
Description
CO2 emission factor of fossil fuel type i in year y
Source of data
Value(s) applied
IPCC default values at the lower limit of the uncertainty at a 95%
confidence interval as provided in table 1.4 of Chapter1 of Vol. 2
(Energy) of the 2006 IPCC Guidelines on National GHG
Inventories
Please see Appendix-4-Table-2.
Choice of data
or
Measurement
methods
and
procedures
Purpose of data
Additional comment
According to the “Tool to calculate the emission factor for an
electricity system” version 03.0.0 , if values provided by the fuel
supplier of the power plants in invoices or regional or national
average defaults values are not available the IPCC default values
at the lower limit of uncertainty must be used.
Data used both for the calculation of EFgrid,OM,Simple,y and EFEL,m,y
-
Data / Parameter
EGy
Unit
MWh
Description
Net electricity generated in the project electricity system in other
words, net electricity generated and delivered to the grid by all
power sources serving the system, not including low-cost / mustrun power plants / units, in year y
Turkish Electricity Transmission Company Web Site
Source of data
hhttp://www.teias.gov.tr/TürkiyeElektrikİstatistikleri/istatistik2014/uretim%20tuketim(2448)/35(1984-2014).xls
Value(s) applied
Please see Appendix-4-Table 3 and Table 4.
Choice of data
or
Measurement
methods
and
procedures
Purpose of data
Additional comment
the TEİAŞ website is the most up-to-date and reliable data
available for the Turkish grid.
Version 05.0
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Data / Parameter
EGm,y
Unit
MWh
Description
Net electricity generated and delivered to the grid by power unit m
in year y
Turkish
Electricity
Transmission
Company
Web
Site
(www.teias.gov.tr). Data is extracted from the relevant annexes of
the capacity projection reports for the years 201016, 2011 17 and
201218.
Please see Appendix-4-Table 8.
Source of data
Value(s) applied
Choice of data
or
Measurement
methods
and
procedures
Purpose of data
Additional comment
the TEİAŞ website is the most up-to-date and reliable data
available for the Turkish grid.
Data / Parameter
ηm,y
Unit
-
Description
Average net energy conversion efficiency of power unit m in year y
Source of data
The default values provided at the Annex 1 of the “Tool to calculate
emission factor for an electricity sector (Version 03.0.0)” are used
Please see Annex 1 of the “Tool to calculate emission factor for an
electricity sector (Version 03.0.0)”
According to the “tool to calculate emission factor for an electricity
system if documented manufacturer’s specifications or data from
the utility, the dispatch centre or official records are not available
then the default values given in Annex 1 of the tool shall be used.
The first two options are not available for the power plants
supplying the Turkish grid, therefore the default values are used.
Data used for the calculation of EFgrid,BM,y
Value(s) applied
Choice of data
or
Measurement
methods and
procedures
Purpose of data
Additional comment
Data used for the calculation of EFgrid,BM,y
-
-
B.6.3. Ex ante calculation of emission reductions
Ex-ante calculation of emission reductions:
Simple Operating margin (OM)
As also explained above, for the computation of the Simple OM, the Ex-Ante option is selected, at
the time of PD submission to the DOE, the data vintages that were most recent, belongs to the
years 2012, 2013 and 2014. All the data used in calculation of the Simple OM are taken from the
TEİAŞ website, details of which are given below. Taking into account the available data “Simple
OM” method “Option B” is the appropriate method for the project activity. TEİAŞ publishes the
annual heating values of the fuels consumed in the power plants, the heating values are directly
16
17
18
http://www.teias.gov.tr/projeksiyon/KAPASITE%20PROJEKSIYONU%202010.pdf
http://www.teias.gov.tr/projeksiyon/KAPASITEPROJEKSIYONU2011.pdf
http://www.teias.gov.tr/KAPASITEPROJEKSIYONU2012.pdf
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related to fuel consumption and are used to calculate average Net Calorific Values (TJ/kt) (Table
10).
The heating values of fuels consumed in thermal power plants are announced by
TEİAŞ, the unit of the heating values are Tcal. Tcal is converted to GJoule by using the
conversion factor 1cal = 4.1868 Joule. Then the heating values in GJ are divided by
Fuel Consumption (FCi,y) to get the Net Calorific Values of the fuels consumed in TJ/kt
as follows:
Table 9: Net Calorific Values for each fuel type for Turkey
Fuel Type
Hard Coal+ Imported Coal
Lignite
Fuel Oil
Diesel Oil
LPG
Naphtha
Natural Gas
2012
24.34
7.03
10.15
41.70
44.71
0.00
0.00
NCV (TJ/kt)
2013
23.79
7.26
10.64
42.61
44.12
1.00
0.00
2014
23.93
7.11
10.48
41.32
43.44
0.00
0.00
The emission factors of fuels required are taken from IPCC 2006 guidelines for GHG
inventories19. All data used for the calculations can be found in Annex-2 (See Table 1
and Table 2 in Annex -2). Table 11 shows total CO2 emission by fuel types calculated
using lower IPCC emission factors and available data from the TEİAŞ website.
Table 10: Calculation of emission by electricity generation (2012-2014)
Default CO2 Emissions (tCO2)
2012
2013
Hard
Coal+Imported
Coal
Lignite
Fuel Oil
Diesel Oil
LPG
Naphtha
Natural Gas
TOTAL
2014
27,690,951.75
35,617,213.92
1,778,007.02
572,555.90
0.00
0.00
46,324,907.21
26,725,289.53
31,084,353.22
47,561,233.71
1,774,296.67
351,585.88
0.00
0.00
32,199,452.90
37,264,883.03
57,148,333.69
2,262,690.75
321,094.07
0.00
0.00
111,983,635.80
107,496,759.01
129,196,454.43
Net electricity generated and supplied to the grid by thermal power plants has been
calculated using data obtained from TEİAŞ web page. The 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
19 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.ipccnggip.iges.or.jp/public/2006gl/pdf/2_Volume2/V2_2_Ch2_Stationary_Combustion.pdf)
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generation with the imported electricity, total supply excluding low cost / must run
sources for each year is determined and given in Table 12.
Table 11: Net Electricity Generation from thermal power plants (units in GWh)
2012
Net Generation (GWh)
Gross Generation (GWh)
Net/Gross Ratio
Net Thermal Generation (GWh)
Electricity Imports (GWh)
EGy (GWh)
EGy (MWh)
2013
2014
227,707.30
239,496.80
0.9507739
163,189.21
0.00
228,977.00
240,153.95
0.9534592
166,733.04
0.00
239,448.83
251,962.75
0.9503342
190,462.76
0.00
163,189.21
166,733.04
190,462.76
163,189,211.17
166,733,036.25
190,462,758.41
The OM Emission Factor for the years 2012, 2013 and 2014 are calculated by dividing
the total CO2 emissions for those years (Table10) to the Net Electricity Generation
(Table 12) for the subject year. The annual OM emission factors are calculated as
follows (Table 13):
Table 12: Annual OM Emission Factors
Year
2012
2013
2014
OM Emission Factor
0.67353
0.65620
0.67833
Finally, OM emission factor is calculated as a generation weighted average for the three
most recent years. The resulting OM Emission Factor is;
EFgrid,OMsimple =0.66983
Build Margin (BM)
As mentioned above we have preferred the Option 1, calculating the Build Margin Emission
factor, “ex ante”, for the first crediting period.
The sample group of power units m used to calculate the build margin are determined as per
the following procedure, consistent with the recent most data available (year 2009 to 2012 in
case of Build margin as the annual development report published by the host country
authorities lack the necessary power plant data):
Identify the set of five power units, excluding power units registered as CDM project activities
that started to supply electricity to the grid most recently (SET5-units) and determine their annual
electricity generation (AEGSET-5-units, in MWh);
Determine the annual electricity generation of the project electricity system; excluding power
units registered as CDM project activities (AEGtotal, in MWh). Identify the set of power units,
excluding power units registered as CDM project activities, that started to supply electricity to
the grid most recently and that comprise 20% of AEGtotal (if 20% falls on part of the generation
of a unit, the generation of that unit is fully included in the calculation) (SET≥20%) and determine
their annual electricity generation (AEGSET-≥20%, in MWh);
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From SET5-units and SET≥20% select the set of power units that comprises the larger annual
electricity generation (SETsample); Identify the date when the power units in SETsample started to
supply electricity to the grid. If none of the power units in SETsample started to supply electricity
to the grid more than 10 years ago, then use SETsample to calculate the build margin.
From a source by the host country licencing body we have determined the commissioning
dates of the units in 2012. Accordingly the amount of electricity produced by the newly added
5 units or the SET5-units are shown in the below table (Table 14):
Table 13: The List of the recently added five units to the host country that makes up the SET5units.
Name of Unit
Fuel
Acarsoy NGCCP20
Natural
Gas
Natural
Gas
Hydro
Hydro
Ales NGCCP
Bağıştaş II HPP
Fındık I HPP
Tuğra
Weir
and
HPP
Hydro
Capacity
(MW)
Project
Production
Potential (GWh)
Firm
Date of
Production
Commissioning
GWh
50
375
375
49
370
370
32.4
11.25
122
48
69
27
4.9
18
10
Total
851
27/12/12
29/12/12
23/12/12
27/12/2012
29/12/12
Source: http://www.enerji.gov.tr/yayinlar_raporlar/2012_Yili_Enerji_Yatirimlari.xls
The net electricity generation in year 2012 is taken as reference for determination of plants that
comprise 20% of the system generation. Based on Turkey’s Annual Electricity statistics
published on the TEIAŞ web site (www.teias.gov.tr) , the net generation in year 2012 was
227,707.3 GWh (See Table 11, in 2012, out of this amount 13,629.40 GWh was identified21 to
be produced by projects that claimed VERs, excluding this number from the net generation we
end up with 214,077.90 GWh of electricity which is determined as AEGTOTAL and 20% of that
amount is calculated as 42,815.58 GWh.
As AEGSET-5-units only produces 851 GWh, a number which is much less than 20% of AEGTOTAL,
it is therefore obvious that 20% of AEGTOTAL, is higher than AEGSET-5-units.
Therefore the 20% of AEGTOTAL with a value of 42,815.58 GWh is to be compared to the
capacity additions in the recent years, and used as AEGSAMPLE to calculate Build Margin
Emission Factor.
Summing up the electricity generations of all the plants added to the Turkish National Grid in
2012, 2011, and adding up those power plant units added in 2010 between 7th of October to
31st of December 2010 to reach the 20% of AEGTOTAL , but excluding the projects that claimed
VERs, the total generation in this period (7 October 2010 to 31 December 2012) up to
46,608.08 GWh.
The total generation by the power plants added in year 2012 is 13,787.45 GWh. This number
is still smaller than the AEGSET 20% value of 46,608.08 GWh. Therefore, to reach the AEGSET 20%
all the units added in year 2011 are also added, which is 15,454.53 GWh. Yet the sum of year
2012 and 2011 generation is still less than the AEGSET 20% (13,787.45 +15,454.53= 29,241.98
GWh< 42,815.58 GWh). So when we start adding the units added in year 2010, starting with
20
NGCCP: Natural gas combined cycle plant
A list of units providing electricty to the year 2011 Turkish Electricity Grid is provided as an Annex 1 to the most recent Capacity
Projection report published by TEIAS (http://www.teias.gov.tr/KAPASITEPROJEKSIYONU2012.pdf). We have checked and identified
the
units
that
have
claimed
VERs
by
comparing
the
list
to
the
Gold
Standard
registry
(https://gs2.apx.com/myModule/rpt/myrpt.asp?r=111) and VCS Project Database (http://www.vcsprojectdatabase.org). This list is
provided to the validating DOE.
21
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the recent most ones we come up to 9,826.11 GWh, which is less than the gap to fill the gap
up to AEGSET 20%, so we added a natural gas powered power plant, producing 7540 GWh (which
is more than the amount needed [3746.91 GWh] but we needed to take the entire units
generation as implied by the tool) that was commissioned on October 7, 2010 and As a result,
the AEGSET Sample value we are using in our BM calculation reached up to 46,608.08 GWh and
this number is greater than the 20% of the total generation, So only the power plants added in
the last 27 months, excluding those claiming VER credits, are used in the calculations. As there
is no power unit older than 10 years this number is being used for Build Margin Calculations.
The lists of most recent capacity additions to the grid by year and their average and firm
generation capacities for the years 2010, 2011 and 2012 are available as Annex-2 to the
capacity projection reports published in the TEIAS web page. Although the annual generation
capacity data for each plant is not available on the statistics page of TEİAŞ. The data for the
years 201222, 201123 and 201024 are taken from the TEİAŞ Capacity Projection Reports which
are also available in another section of the TEİAŞ website. For the capacity additions, the firm
generation capacities of the power plants are used. The units that are taken out of the grid are
not taken into consideration. All the data used for calculations can be found in Annex-2 (see
Table 8a and Table8b).
According to the tool in terms of vintage of data, a project participant can choose either the exante option or the ex-post option. As explained above, out of these two options, Option 1 is
selected. For the first crediting period, the build margin emission factor is calculated ex-ante
based on the most recent information available on units already built for sample group m at the
time of CDM-PDD submission to the DOE for validation. For the second crediting period, the
build margin emission factor will be updated based on the most recent information available on
units already built at the time of submission of the request for renewal of the crediting period to
the DOE. For the third crediting period, the build margin emission factor calculated for the
second crediting period will be used. This option does not require monitoring the emission
factor during the crediting period.
Electric efficiency rates
There is no complete and up-to-date data regarding the electrical efficiency of thermal power
plants that supply electricity to the Turkish National Grid system. Therefore the default values
provided in Annex 1(Default efficiency factors for power plants) of the Methodological Tool to
calculate the emission factor for an electricity system (Version 04.0.0) (EB 75; Annex 15) is
utilised, in a very conservative manner, considering that we are unable to differentiate the units
that were commissioned before year 2000, and we cannot differentiate their technologies, all
the coal and lignite fired thermal power plants are considered to operate with 50% efficiency, all
the oil fired power plants are considered to operate with 46% efficiency, and all the Natural Gas
fired power plants are considered to operate at 60 % efficiency. For the diesel powered thermal
power plants the efficiency is considered to be 46%. Since the default values are not provided
for Naphtha, it is considered to behave like oil and its efficiency is considered as 46%, and
Bitumen is considered to behave like coal and its efficiency is considered to be 50%. The
efficiency values considered in BM calculations can be summarized as follows (Table 14):
Table 14: Default Electric efficiency rates taken from Annex 1 of the Methodological Tool to
calculate the emission factor for an electricity system (Version 04.0.0) (EB 75 Report Annex
15).
Fuel Type
Average Electric efficiency rate
Coal
50.0%
Lignite
50.0%
Fuel Oil
46.0%
22
TEIAŞ Capacity Projection Report 2013- 2017
(http://www.teias.gov.tr/YayinRapor/APK/projeksiyon/KAPASITEPROJEKSIYONU2013.pdf)
23
TEİAŞ Capacity Projection Report 20010-2019 (http://www.teias.gov.tr/projeksiyon/KAPASITE%20PROJEKSIYONU%202010.pdf)
24
http://www.teias.gov.tr/projeksiyon/KapasiteProjeksiyonu2011.doc
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Diesel
Naphtha
Natural Gas
Bitumen
46.0%
46.0%
60.0%
50.0%
The parameters for the calculation of EFEL,m,y, and its calculation is shown in Table 16 below:
Table 15: Calculation of EFEL generation efficiency based on the default values provided in
Annex 1 of the Methodological Tool to calculate the emission factor for an electricity system
(Version 4.0.0) (EB 75 Report Annex 15)
Fuel Type
EF
(EF*3.6)
Generation
EFEL,m,y
(tCO2/TJ)
Efficiency %
tCO2/MWh
Coal
92.80
334.080
50.0%
0.668
Lignite
90.90
327.240
50.0%
0.654
Fuel Oil
Diesel
Naphtha
Natural Gas
Bitumen
75.50
72.60
69.30
54.30
73.00
271.800
261.360
249.480
195.480
262.800
46.0%
46.0%
46.0%
60.0%
50.0%
0.591
0.568
0.542
0.326
0.526
The CO2 emissions from the most recent capacity additions are calculated by multiplying the
EFEL,m,y values calculated for each fuel source by the annual generation of that fuel source
(Table 17). The emission factor has been taken as “zero” for the renewable and wastes. The
Build Margin Emission Factor for each year is calculated by dividing the total CO2 Emissions of
the subject year by the total generation from the capacity additions of the same year.
Table 16 Annual CO2 Emissions for Capacity Additions and Annual BM Emission Factors
Capacity Additions in 2010 (GWh)
CO2 Emissions
EFgrid,BM,2010
Coal
Lignite
Natural Gas
Renewables and Wastes
TOTAL
8,011.76
0.0
8,963.60
390.75
17,366.11
Fuel Oil
Coal
Lignite
Naphtha
CO2 Emissions
922.67
4.32
180.78
-
Natural Gas
TOTAL
12,301.75
2,045.00
15,454.53
Fuel Oil
48
Coal
202
Lignite
145.00
Naphtha
Natural Gas
9,192.53
4,199.92
Version 05.0
5,353.14
0.00
2,920.34
0.00
8,273.48
0.47642
EFgrid,BM,2011
545.18
2.89
98.05
0.00
4,007.91
0.00
4,654.02
0.30114
CO2 Emissions
28.36
134.97
94.90
0.00
2,994.93
0.00
EFgrid,BM,2012
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TOTAL
13,787.45
3,253.16
0.23595
The Build Margin Emission Factor of the grid is then calculated as a generation weighted
average for the years 2010, 2011 and 2012. The resulting BM Grid is:
EFgrid,BM = 0.34716 tCO2e/MWh
Combined margin emission factor
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;
EFgrid,CM,y= EFOM X WOM+ EFBM X WBM=(0.66983X 0.75)+(0.34716X0.25)= 0.589166 tCO2e/MWh
Emission reductions
ERy = BEy = EGfacility,y * EFy
= 145,400 MWh* 0.589166 tCO2e/MWh = 85,664 tCO2e for each year.
B.6.4. Summary of ex ante estimates of emission reductions
Year
2017
(1 June to 31 Dec.)
2018
2019
2020
2021
2022
2023
2024
(1 Jan. to May 31)
Total
Total number of
crediting years
Annual average
over the crediting
period
B.7.
Baseline
emissions
(t CO2 e)
Project
emissions
(t CO2 e)
Leakage
(t CO2 e)
Emission
reductions
(t CO2 e)
50,225
85,664
85,664
85,664
85,664
85,664
85,664
0
0
0
0
0
0
0
0
0
0
0
0
0
0
50,225
85,664
85,664
85,664
85,664
85,664
85,664
35,439
35,439
599,648
0
0
599,648
85,664
0
0
85,664
7
Monitoring plan
B.7.1. Data and parameters to be monitored
(Copy this table for each piece of data and parameter.)
Data / Parameter
EGPP-Gross Generation, y
Unit
MWh
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Description
Source of data
Value(s) applied
Measurement
methods
and
procedures
Monitoring
frequency
QA/QC procedures
Purpose of data
Additional comment
Data / Parameter
Unit
Description
Source of data
Value(s) applied
Measurement
methods
and
procedures
Monitoring
frequency
CDM-PDD-FORM
Quantity of electricity exported by the power plant to the Grid in year
y
The Primary source of data will be the TEIAS meter readings
recorded remotely and accessible via the PMUM/MFRC web site25.
Will be determined at the monitoring stage
Measurements are to be made by an electricity meter that belongs
to the grid operator, TEIAŞ. It is planned to be one main meter that
will record the electricity import and export. The meter will be in
compliance with the collected data. The meter readings will be
accessible via an Automatic Meter Reading Software remotely by
the project owner. The data is also automatically recorded to the
PMUM/MFRC servers to be obtained as monthly screen outputs. As
a general practice, only the main meter readings are accessible but
there is going to be one back up meter to ensure that data recording
in case of main meter failure, will not be interrupted.
Recorded continuously, read remotely by TEIAS, and accessible
monthly via the PMUM/MFRC web site , Reported annually on the
Monitoring Report.
Measurements will be carried out in compliance with the
communiqué for Metering Devices to be used in the Electricity
Market. The monthly reported meter reading by the main meter, will
be cross-checked against the Main back up meter by a technician
that will visit and record the back up meter readings on a monthly
basis.
Data will be used to calculate the net electricity supplied to the grid.
Both the main meter and the back up meter will be in compliance
with the communiqué for Metering Devices to be used in the
Electricity Market26.
EGPP-self consumption, y
MWh
Quantity of electricity imported by the power plant from the Grid for
self consumption, in year y
The Primary source of data will be the TEIAS meter readings
recorded remotely and accessible via the PMUM/MFRC web site27.
Will be determined at the monitoring stage
Measurements are to be made by an electricity meter that belong to
the grid operator, TEIAŞ. It is planned to install one bidirectional
meter that record the electricity imported from the grid. The meter
will be in compliance with the collected data. The meter reading will
be accessible via an Automatic Meter Reading Software remotely by
the project owner. The data is automatically recorded to the
PMUM/MFRC servers to be obtained as monthly screen outputs. As
a general practice, only the main meter readings are accessible but
there is going to be one back up meter to ensure that data recording
in case of main meter failure, will not be interrupted.
Recorded continuously, read remotely by TEIAS, and accessible
monthly via the PMUM/MFRC web site , Reported annually on the
Monitoring Report.
25
PMUM/MFRC Piyasa Mali Uzlaştırma Merkezi / Market Financial Reconciliation Center.
The latest version of the communiqué (in Turkish) can be found in the following link: http://www.epdk.gov.tr/web/elektrik-piyasasidairesi/44
27
PMUM/MFRC Piyasa Mali Uzlaştırma Merkezi / Market Financial Reconciliation Center.
26
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QA/QC procedures
Purpose of data
Additional comment
CDM-PDD-FORM
Both the main meter and the back up meter will be in compliance
with the communiqué for Metering Devices to be used in the
Electricity Market28.
Data will be used to calculate the net electricity supplied to the grid.
Measurements will be carried out in compliance with the
communiqué for Metering Devices to be used in the Electricity
Market. The monthly reported meter reading by the main meter, will
be cross-checked against the Main back up meter by a technician
that will visit and record the back up meter readings on a monthly
basis.
B.7.2. Sampling plan
The electricity will be continuously measured by the grid operators meters that are inline with the
host country regulations. This data is going to be recorded on a monthly basis.
Monitoring procedures
The monitoring will be conducted by the Emission Reduction (ER) Monitoring Team. The ER Team
Members, and their position and duties for the monitoring is outlined in the following table (Table
16):
Table 17: Positions and responsibilities of the ER monitoring team members.
Position
Yalova WPP Manager
Chief
Technician
Electrical
Accounts Manager based
in Ankara HQ.
Chief
Mechanical
Technician
Carbon Consultant
Responsibility
• Day to day operation of the Yalova WPP,
• Compliance of the project activity with the host
country rules and regulations
• Coordination of the data collection and recording
for the VCS monitoring report.
• Day to day follow up of electrical equipment
• Recording and monitoring of the electricity
generation data
• Data keeping for power sales
• Keeping the track record of PMUM/MFRC data
• Day to day operation of the power plant
• Keeping records of malfunctions and repairs
• Emission reduction calculations
• Scripting of the periodic monitoring report
• Follow up of the verification process
The power generation meter readings will be performed by using the main metering devices and
the back-up metering devices for accuracy checks only. Data from metering devices will be
recorded by TEİAŞ on monthly agreed protocols and will form the basis for invoicing and emissions
calculations. In addition to the readings of the two metering devices, generation data of the Yalova
WPP can be cross checked, via the TEİAŞ – PMUM web site (http://pmum.teias.gov.tr ) which is
accessible by a password available to the electricity generation companies. The monthly screen
shot print outs of the PMUM data will be available to the verifying DOE during the verification
process for cross checking. Electricity generation data at the Market Financial Reconciliation
Centre (MFRC/PMUM) web page will exhibit the net electricity generated less transmission loss, to
28
The latest version of the communiqué (in Turkish) can be found in the following link: http://www.epdk.gov.tr/web/elektrik-piyasasidairesi/44
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be able to produce comparable numbers, the figures taken from PMUM web site needs to be
multiplied by the transmission loss factor of the grid.
Data to be monitored
Given that the emission factor is calculated on an ex-ante basis, the first data to be monitored is
the electricity net supplied to the grid. For this purpose the gross generation and the internal
consumption of the power plant will be monitored, using bi-directional electricity meters.
Monitoring equipment
Electricity meters
The main and back-up electricity meters will be bi-directional for quantifying the electricity delivered
by the Project Activity to the grid.
The meters will be in compliance with the standards of the Turkish Standards Institute and will
have obtained a “Type and System Approval” certificate from the Ministry of Trade and Industry. In
case there are modifications to the standards, the modified standard shall be valid; and in case a
valid standard is cancelled or abolished, the new standard shall be valid. The standards that will be
used are TS-620 EN 60044-1 and TS718 IEC60044.2 for main and back-up meters, respectively.
The sensitivity of the main and secondary meters are CI = 0.2S for active and reactive energy. The
meters shall be factory calibrated by the manufacturer before installation. Records of the meter
(type, made, model and calibration documentation) will be retained in the quality control system.
Data management
The indices are read and recorded (by hand) hourly. The person who records the last entry of the
day inputs all readings into an electronic spread sheet and then sends this report to HQ where it is
being stored.
At the end of each month, electricity supplied to the grid will be entered into an electronic spread
sheet titled raw data, so that it can be processed for verified emission reduction calculations. The
data to be measured for installed capacity and reservoir area will be entered into an electronic
spread sheet at the end of each year. The electronic files will be backed up on both hard drives
and on a Compact Discs (CD).
Quality Control and Assurance (QC/QA)
All of the main and back-up meters are owned and installed by the grid operator, TEIAS. The
Project Owner has signed an agreement with the grid operator to specify the QA procedure for
measurement and calibration to ensure the measurement accuracy of the main and back-up
meters are in compliance with national regulations. The Calibrations of the electricity meters are
valid for the next 10 years after calibration,
The grid operator's Metering Officer should be notified of any failure of one of the meters. TEIAS is
the only one entity, authorized to deal with fixing, calibrating, or changing the meters, which will be
done either by the grid operator or by a company authorized by the grid operator. The Project
Owner will keep electricity sale and purchase records, to which the recorded data will be
compared.
All written documentation such as maps, drawings, the EIA and the Feasibility study, will be stored
and will be made available to the verifier so that the reliability of the information may be checked.
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All the data and documentation related to the verification will be archived for minimum two years
after the end of the first crediting period.
B.7.3. Other elements of monitoring plan
Data to be monitored
Given that the emission factor is calculated on an ex-ante basis, the main data to be monitored is
the electricity net supplied to the grid.
Monitoring equipment
Electricity meters
The main and back-up electricity meters will be bi-directional for quantifying the electricity delivered
by the Project Activity to the grid.
The meters will be in compliance with the standards of the Turkish Standards Institute and will
have obtained a “Type and System Approval” certificate from the Ministry of Trade and Industry. In
case there are modifications to the standards, the modified standard shall be valid; and in case a
valid standard is cancelled or abolished, the new standard shall be valid. The standards that will be
used are TS-620 EN 60044-1 and TS718 IEC60044.2 for main and back-up meters, respectively.
The sensitivity of the main and secondary meters are CI = 0.2S for active and reactive energy. The
meters shall be factory calibrated by the manufacturer before installation. Records of the meter
(type, made, model and calibration documentation) will be retained in the quality control system.
Data management
The indices are read and recorded (by hand) hourly. The person who records the last entry of the
day inputs all readings into an electronic spread sheet and then sends this report to HQ where it is
being stored.
At the end of each month, electricity supplied to the grid will be entered into an electronic spread
sheet titled raw data, so that it can be processed for verified emission reduction calculations. The
data to be measured for installed capacity and reservoir area will be entered into an electronic
spread sheet at the end of each year. The electronic files will be backed up on both hard drives
and on a Compact Discs (CD).
Quality Control and Assurance (QC/QA)
All of the main and back-up meters are owned and installed by the grid operator, TEIAS. The
Project Owner has signed an agreement with the grid operator to specify the QA procedure for
measurement and calibration to ensure the measurement accuracy of the main and back-up
meters are in compliance with national regulations. The Calibrations of the electricity meters are
valid for the next 10 years after calibration,
The grid operator's Metering Officer should be notified of any failure of one of the meters. TEIAS is
the only one entity, authorized to deal with fixing, calibrating, or changing the meters, which will be
done either by the grid operator or by a company authorized by the grid operator. The Project
Owner will keep electricity sale and purchase records, to which the recorded data will be
compared.
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All written documentation such as maps, drawings, the EIA and the Feasibility study, will be stored
and will be made available to the verifier so that the reliability of the information may be checked.
All the data and documentation related to the verification will be archived for minimum two years
after the end of the first crediting period.
B.7.4. Date of completion of application of methodology and standardized baseline and
contact information of responsible persons/ entities
This application of the Methodology was completed on 15/11/2015
By Dr. G. Aslı Sezer Özçelik
Ekobil Çevre Hizmetleri Danışmanlık Eğitim Tarım Hayvancılık Madencilik İnşaat İthalat
İhracat Turizm ve Ticaret Limited Şirketi
(www.ekobil.com and e-mail:[email protected])
Please note that the party that prepared the PDD and applied the methodology is not a project
participant.
SECTION C. Duration and crediting period
C.1.
Duration of project activity
C.1.1. Start date of project activity
The Construction of the project started on 01/06/2011, as indicated by the National Health and
Security records startup document provided to the validating DOE.
C.1.2. Expected operational lifetime of project activity
The project is expected to have a lifetime of 25 years based on default values stated in
“Methodological Tool: Tool to determine the remaining lifetime of equipment”
(Version 01)”
C.2.
Crediting period of project activity
C.2.1. Type of crediting period
7 years renewable twice
C.2.2. Start date of crediting period
The project started to produce electricity after the commissioning of its first group of turbines on 4
May 2012, later on 15/08/2014 the other units have also become operational. According to the
relevant rules of Gold Standard, one consider starting date of the crediting period a date 2 years
prior to the registration dte of the project. For Practicality resaons we considered 1/1/2014 as the
start date of the project crediting period.
C.2.3. Length of crediting period
7 years
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SECTION D. Environmental impacts
D.1.
Analysis of environmental impacts
According to the Environmental Impact Assessment regulation of the host contry, wind power
plants that exceed 10 MW of capacity needs to submit a Project Introductory File (PIF) to the local
branch of the Ministry of Environment and Urban Planning (MoEUP). In case of the project activity
this is the Hatay Governership’s General Directorate of Environment and Urban Planning. The PIF
is evaluated by this division, and it is decided that the project does not need to undergo an
Environmental Impact Assessment Process and thus the project activity is granted with an
Environmental Impact Assessment not needed certification, which is presented on Appendix 8.
D.2.
Environmental impact assessment
In the context of the PIF submitted within the project documents to the local branch of MoEUP, the
following measures will be adopted in order to minimise the impacts during construction and
operational periods:
Air Quality: Necessary precautions, such as watering roads, careful loading and unloading and
covering the top of loaded trucks by tarpaulin; will be taken in order to minimize the dust formed
during excavation.
Water & Wastewater Management: Water for domestic use will be supplied by tankers to the site
and wastewater will be collected in septic tanks which will be emptied regularly. The wastewater
will be discharged in accordance with Water Pollution Control regulations.
The waste oil will be collected in impermeable containers and transferred to recycling centres in
accordance with Hazardous Waste Control Regulations and Waste Oil Control Regulations.
Solid Waste: Solid waste will be collected and recyclables will be separated to be sent to recycling
centres. The rest will be disposed to the nearest landfill site in coordination with Yalova
Municipality.
Biodiversity: Necessary precautions will be taken for the species under conservation by
international conventions, if any found on the site. Also, the security patrol of the wind farm, will
look for any dead bird and bat body, any incident will be recorded
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SECTION E. Local stakeholder consultation
E.1.
Solicitation of comments from local stakeholders
To be able to reach out the Mecidiye Village, which is locates at the closest proximity to the project, and the
nearby Armutlu town citizens on 16th of June we have visited the Muhtar who is a very well known person in
the region and an opinion leader. We asked his opinion to be able to chose most widely read local news
paper and asked him to help us to announce the meeting to the public. Also the other local institutions are
chosen according to Gold Standard guidelines and considering most relevant governmental institutions that
has a stake in a wind power plant. In addition to this the local NGOs that are most active in the region have
been reached out.
The women living in the village didn’t attend the meeting so they were visited seperately and we had the
oportunity to talk to a group of women. We have provided information about the project and we have
collected their opinion. They have also signed a separate sheet of attendance to indicate that we had that
small meeting.
In addition to this the NGOs that we have sent invitation by e-mail have been called by phone and they are
informed thay are welcome to send us their information during the course of the project at any stage, and
they are informed about the continous grievance process of Gold Standard.
The Local Stake Holder Meeting was held in Mecidiye Village Tea House on 29.June 2012 at 16:00 . The
Agenda of the meeting was as follows:
•
Introduction and Opening of the meeting
•
Information on Climate Change
•
Information on the Yalova WPP project
•
Information on concepts of sustainability and millennium development goals
•
Questions for clarification about the project
•
Blind Sustainable Development exercise
•
Discussion on how the project’s compliance to the Sustainable Development criteria will be
monitored
•
How the continous grievance mechanism would work was explained.
•
Closure of the meeting
Minutes of the Meeting:
The meeting started by introducing the project owner Arova Ltd. and the presenter of the project Ekobil Ltd.
and Aslı Özçelik. We have than provided information on the purpose of the meeting and explained the basic
principles of wind energy production. We have also provided information on the concept of climate change
and how the voluntary carbon markets are operating and how this project would contribute to the mitigation
of climatechange.
We have than provided basic information about the project without using complex technical terms. Explained
the rules and regulations we have to comply and the issues project owner needs to take into consideration in
order to comply with the Gold Standard rules. We have also explained that we were conducting a research to
survey storks and soaring bird migration routes to make sure that they are not impacted from the project, or
the impacts are minimized as much as possible.
We have explained the audience that we would be taking their questions and answering them and
afterwards we would need them to look at the blind sustainable development exercise.
After answering their questions and discussing how they could help to the monitoring of the sustainability
related parameters, we have explained them Gold standard’s continous Grieviance mechanisms and
explained them that they could give their feedbacks via internet or we could leave them a book that they
would be filling their thoughts and ideas about the project. We have also assured them that this book would
be checked periodically and the requests/questions recorded in the book would be addressed.
The Mecidiye Village Council member Emin Şimşek suggested that it would be better for them to have a
telephone number to call and direct their questions related to the project and book to note their opinions, for
this, and it is aggreed upon to leave a book to the village and a telephone number is provided to be
contacted .
Here are the questions that was asked by the audience and their answers:
−
Q [Deputy Governor]: How many turbines will there be?
−
A [Dr. Özçelik] There wil be in total 36 turbines with 1.5 MW electricity generation capacity each and
the total capacity will therefore be 54 MW.
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−
Q [Deputy Governor]: Except EMRA where else do you need to get permits?
−
A [Dr. Özçelik] : Upto 500KW capacity it is enough to get a permits from TEDAş and from the special
provincial authority, but since the project capacity is 54 MW there are many permits that you need to get
including TEİAŞ, Ministry of Environment and Urban Planning, Military, forestry and more. The permit taken
from the ministry is appliad via TUBITAK, (the Turkish Sience and Research League).
−
Q [Anonymous]: Is the Kyoto Protocol being implemented.
−
A [Dr. Özçelik] : Well our country has ratified Kyoto Protocol, and we are listed within the list of
developed countries so as a result we do not have a emission reduction target under annex B of the
Protocol, the emission reductions that this project is going to produce are only possible to be marketed in the
voluntray markets.
−
Q [Anonymous]: Is the price of one ton of carbon known?
−
A [Dr. Özçelik] : Not really. We cannot say that there is a fixed price.
−
Q [Anonymous]: Does the turbines have a radioactive effect?
−
A [Dr. Özçelik]: Absolutely no. Wind turbines are not emitting any radioactivity.
−
Q [Anonymous]: Where does the turbines manufactured
−
A [Dr. Özçelik]: In China
−
Q [Kamil Gündüz]: Where will be the connection point to the national grid?
−
A [Dr. Özçelik]: The connection point will be Orhan Gazi TM.
−
Q [Deputy Governor]: Will there be employment opportunities?
−
A [Dr. Özçelik]: The construction is estimated to take 1,5 years long. During this and operational
phase the technical people are going to be employed from the center of the mother company. Also if there
are local people with technical capabilities they will be given priority at all times. All the non technical
workforce will be employed locally. People learning from this project will also have possibility to work in other
projects of the mother company with the experience they will gain from this project.
−
Q [Kadir Karaduman]: Why the turbines are not selected from Turkey?
−
A [Dr. Özçelik]: The turbines are high technology turbines. They are imported from abroad as we do
not have this technology in our country.
−
Q [Kadir Karaduman]: What is the percent price difference of the electricity produced from that of the
unit price paid by the household?
−
A [Özgür Erol/CFO of Arova]: There is a general anounced trif by the EMRA, and the price is same
all over the country. However, the private distributors are able to sell to bigger users such as Ziraat Bank,
Vakıfbank, Şok Grossary chain, are buying form a distribution company under our mother company and they
make different agreements to benefit both parties.
−
A [Dr. Özçelik]: The electricity price at the production point is in general a trade secret as there may
be two hydro power plants on the same river next to each other and they can charge different prices.
−
Q [Kadir Karaduman]: I think people around the facility should benefit
−
A [Özgür Erol/CFO of Arova]: The project does not have the legal authority and to sell or provide
electricity to the local citizens or individuals. It is also technically not possible.
−
Q [Şevket Atlı/Qaimaqam]: There will be 36 turbines and there will be road constructions in the
forested area will there be tree cuttings during these affairs?
−
A [Özgür Erol/CFO of Arova]: We plant more than we cut. As the MWs of the turbines are larger the
footprint of the project is relatively smaller, and there will be relatively less roads. We are in cooperation with
the forest authority and we will know how many trees will be cut exactly and we will be doing tree plantation
and rehabilitation works with them. For example we have planted fruit trees in one of our projects in Düzce
upon the request from the local inhabitants.
−
Q [Şevket Atlı/Qaimaqam]: What is the possibility of forest fires when suring the operation of the
wind turbines?
−
A [Özgür Erol/CFO of Arova]: The height of the trees are 8 to 10 m, whereas the turbine towers are
110 m. It is not witnessed anywhere a wind turbine to cause a fire. In addition to this we are checked for
these by TEIAŞ and if we do not comply with their saftey standards they do not commision the project.
Regarding the transmission lines it is the responsibility of TEIAŞ to take necessary precautions against fire
and we know that they are doing their best. Also some of our access roads will serve as fire barriers in case
of a forest fire.
−
Q [Şevket Atlı/Qaimaqam]: You said you would be watching migratory birds and how will other living
beings be affected?
−
A [Dr. Özçelik]: Based on the preliminary environmental studies we are not seing any danger to
other living beings as there will be no extensive landuse change of habitat fragmentation.
−
Q [Anonymous]: What will be the benefit to the public?
−
A [Dr. Özçelik]: We may not talk about benefits to individuals but the economy of this village and its
surrounding will be activated. Especially during the construction stage there will be employment
opportunities, and during the operation stage there will be more visitors curious to see the turbines.
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−
A [Özgür Erol/CFO of Arova]: Other than that it will have contribution to the country as the energy will
be produced from local renewable sources instead of expensive imported fossil fuels. About 40% of
household electricity price is going abroad to pay Turkey’s natural gas bills.
−
Q [Anonymous]: What are the examples from the world
−
A [Dr. Özçelik]: The wind power plants projects have their first examples in USA where there were
plants with numerous 200 to 500 KW turbines that were placed closed to each other and therefore caused
some harm to bird life. These are not the best examples. There are many wind power plants in China,
Denmark and Germany that will be similar to te one that will be constructing here. Also in Bandırma, İzmir
there are similar ones that are up and running and supplying electricity to our National electricity grid.
A project site has to get enough and steady wind and also it has to have means of connectibility to the
national grid. Such sites are suitable for wind power plant construction.
−
Q [Anonymous]: Is there any negative interaction with humans?
−
A [Dr. Özçelik]: The turbines don’t have negative interaction with humans. Only the areas where
there will be electricity cannot be accessed and these areas are fenced. Other than that all the precautions
are being tried in orther to protect birds, such that in order not to attract birds the turbines will be painted to
the most appropriate color.
−
Comment From Audience [Mustafa Çınar]: Actually animals don’t go to that region. There were no
wind turbines in the old days but these days their numbers are increasing and they are not bothering
animals. I have seen in another place there were animals grazing around them.
−
Q [Kadir Karaduman}: What is the investment cost for a Hydro or wind Project?
−
A [Özgür Erol/CFO of Arova]: for a wind project it is about 1.5 million Euro per turbine. Actually the
investment cost of a natural gas project is lower and the investment or setting up such a project is a lot
easier but we are dependent to imports in that resource. Therefore it is the policy of our mother company to
invest on Hyro and wind.
−
Q [Kadir Karaduman}: How does the electricity is sold.
−
A [Özgür Erol/CFO of Arova]: There are meeters at the end of the transmission line and via these
meters electricity is sold to TEIAŞ
−
Q [Anonymous]: Is it harmful to nature?
−
A [Dr. Özçelik]: No it si not.
−
Q [Anonymous]: Is there going to be any other projects around hear?
−
A [Özgür Erol/CFO of Arova]: As the production license belongs to us no one else can produce
electricity within our project boundaries and similarly we cannot produce outside of our project boundary. In
addition to that there are constraints due to the capacity of the transformer substations.
−
Q [Anonymous]: What will be done with the produced electricity?
−
A [Özgür Erol/CFO of Arova]: We are obiged to give it to te national power grid system. The system
than sells it to the end users via the distributors.
−
Q [Anonymous]: Would the project will have any help to this village?
−
A [Özgür Erol/CFO of Arova]: There will be a lot of people coming from outside of the village and
these people will be shoping from your market. So it will vibe the economy. Try not to think on individual
benefits.
−
Q [Armutlu Mayor]: How will the roads be effected?
−
A [Özgür Erol/CFO of Arova]: The turbine blades will arrive from the back side of Armutlu. To fit the
large trucks the roads will be improved and widened. There will be significant road works.
−
Q [Şevket Atlı/Qaimaqam]: The construction will take place approximately two years you will be
employing plain workers and mid-level technicians from the local sources, but what will happen after the
project construction will be completed and the project will strat producing electricity?
−
A [Dr. Özçelik]: It is expected that during the construction the number of people to be employed can
be up to 45 people. During the operation phase this number can be as low as 8 up to 10, but please also
remember that similar power plants are running fully automated in most part of the Europe and only a team
of mobile maintenance and repair is visiting the power plants periodically. However in Turkey such power
plates employ at least 8 personnel and in addition to that service providing companies also do their regular
visits. In Turkey, some turbine manufacturing companies started to train Turkish engineers and technicians
for the repair and maintenance purposes of the Turkish wind industry and these Turkish teams started to
work in the neighborhoods of Turkey such as Balkans and Middle East. As this facility going to be in place for
the next 49 years, your kids can study Mechanical or Electrical engineering and can be one of the technitions
in the power plant in the coming decades.
−
Q [Anonymous]: What will the is project going to bring us up and what will it take from us.
−
A [Dr. Özçelik]: You will have a new neighbour for the next 45 years or even more. Especially during
the construction phase there will be employment opportunities and other technical and capable people that
will come to your village will liven up your economy as they will be buying goods from your village or from
Armutlu. Those who will start as plain workers will have an opportunity to improve themselves and learn from
the others and will have opportunity to work in similar projects in the future. In addition to that as therewill be
earth movers especially during the construction period the project can help village in some public benefitting
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small works, like improving the school etc. Also during the operation phase the turbines will atract curious
people who would like to see them in close proximity and this will atract more people to your local organic
vegetables market. The project will be very cautious to its environment and you will help us monitor this and
inform us if there are any environmetal problems.
−
Q [Suheyla Uzuneser/Soroptimist]: Could a microcrediting system be established for women so that
they can buy livestock and increase their income?
−
A [Dr. Özçelik] Company can not provide support to individuals, such as cannot donate money to buy
a bee hive but can provide the bee hives and can distribute but we are willing to explore ways of contributing
household income especially by the help of women.
Minutes of the Meeting with Women:
Right after the meeting we got together with most of the women in the village as they were gathering for a
wedding event. We sat together and explained them the particulars of the project chosing a nontechnical
simple language. We asked if they had any questions. They inquired if there would be employment
opportunity for their man and young, we replied the same as we did in the meeting and explained them that
the plain workers would be chosen primarily from their village.
We have also asked them if they had any social demands. Or would they like to see any social programs
happenning in their village. They mentioned us about their organic and good agricultural practice activities
and that they needed some improvements for their market place, and some help to carry them to the market
place, like a shutlle bus.
In addition to that they alo explained that they would be happy to have a gathering place for themselves like
a women’s tea house.
We have explained them that we will evaluate their requests and will address them within the capabilities
and resources of the project. We have also explained them about the continious grievance mechanism and
provided them the same number for them to call, and informed them about the book we will be leaving to
Muhtarship.
Than we thanked them for their time and farewelled them to the wedding wishing luck and happiness to the
marying couple.
Following are the figures from the local stakeholders consultation meetings held at the project site (Figure 6).
Figure 5: Pictures from the local stakeholders consultation meeting held in Yalova Project site.
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E.2.
Summary of comments received
Itisunderstoodfromthecommentsthatafterbeingpresentedtheprojectmostofthegovernment(local
and central) related stakeholders were reacting to the project on a constructive manner. Regarding the
villagers it can be said that the situation is also like that except minor concerns or suspicion. During the
constructionandoperationphasesoftheprojectthecarbonmanagementteamwillbefollowingupwith
the concerns of the local stakeholders and will be doing their best to answer any questions or address
potentialproblems.
It is also understood that some of the village citizens were happy to be given information via the
stakeholdersconsultationreportandtheywerehappywiththelevelofinformationgiveninthemeeting,
exceptonecommentstatingthatthenecessaryinformationwasnotgivenwepredictthatthatnecessary
informationthatparticularindividualwasseekingwasrelatedtowho’slandwouldbeexpropriated,who
wouldbeemployedandwhatparticularbenefitsthevillagewouldget.Astheprojectwasatanearlystage
atthetimeofLSCmeetingthiswasimpossibletoaddressthesequestions,howevertroughthecontinous
grieveanceprocesswebelievetherewillbemeanandgraoundstoanswersuchquestions.
E.3.
Report on consideration of comments received
Stakeholdercomment
Was comment taken into Explanation(Why?How?)
account(Yes/No)?
Will the project have an impact
Y
Birds (both diurnal and
onbirdlife?
nocturnalbirds)andbatswillbe
Willtherebejobopportunities
Y
Can the locals benefit from free
orcheapelectricity
Y
Howthelandacquisitionwillbe
Y
WilltherebeNoiseimpact
Y
Are all the environmental and
forestry related permits taken
fromtherelevantauthorities?
Y
monitored, to make sure they
arenotnegativelyeffected.Also
the turbines will be paint in a
particularcolourtodeterbirds.
Local recruitment is told to be
prioritised. More opportunities
areexplainedtooccuralongthe
lifespanoftheproject.
It is explained that this is
impossible both technically and
as a result of rules set forth by
thegovernment.
It is explained that most of the
land was going to be rent from
the forest but in places where
the land would be expropriated
maximum care would be spent
in order not to upset any land
owner within legal and
reasonablelimits.
Noisemodelshaven’tshownany
impacts and we will make sure
toobeynationallysetlimits
It is explained that most of the
permits were in place and the
construction could not start
before completing all the legal
procedures.
SECTION F. Approval and authorization
The host country Turkey is an Annex 1 country under UNFCCC, and a party to Kyoto protocol
without a binding emission reduction target. For more detail please visit :
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http://www.mfa.gov.tr/united-nations-framework-convention-on-climate-change-_unfccc_-and-thekyoto-protocol.en.mfa
As a result there is no established DNA at the host country and thus no approval process.
Therefore we have informed the UNFCCC focal point and we will be registering the project to the
host country’s registry system as it will get validated and/or verified.
-----
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Appendix 1. Contact information of project participants and
responsible persons/ entities
Project participant
and/or responsible
person/ entity
Organization name
Street/P.O. Box
Building
City
State/Region
Postcode
Country
Telephone
Fax
E-mail
Website
Project participant
Responsible person/ entity for application of the selected
methodology (ies) and, where applicable, the selected standardized
baselines to the project activity
AROVA RES ELEKTRİK ÜRETİM A.Ş.
Gazi Mustafa Kemal Bulvarı 15 Mayıs Mah. 832 sk.
No:2 75.Yıl Esnaf Sarayı K:2
DENİZLİ
TURKEY
+90 258 2422776
+90 258 2651585
[email protected]
www.bereketenerji.com.tr
Contact person
Title
Salutation
Last name
Middle name
First name
Project coordinator
Ms.
Gül Koparan
Özgün
Department
Mobile
Direct fax
Direct tel.
Personal e-mail
Project participant
and/or responsible
person/ entity
Organization name
Street/P.O. Box
Building
City
State/Region
Postcode
Country
Telephone
Fax
Version 05.0
[email protected]
Project participant
Responsible person/ entity for application of the selected
methodology (ies) and, where applicable, the selected standardized
baselines to the project activity
Ekobil Çevre Hizmetleri Danışmanlık Eğitim Tarım Hayvancılık
Madencilik İnşaat İthalat İhracat Turizm ve Ticaret Limited Şirketi
Ahlatlıbel Mah. Güneykent Sitesi 1839 sokak
No 56
ANKARA
Çankaya
06805
TURKEY
+903124891338
-
Page 48 of 78
CDM-PDD-FORM
E-mail
Website
[email protected]
www.ekobil.com
Contact person
Title
Salutation
Last name
Middle name
First name
Partner
Dr.
Sezer Özçelik
Aslı
Ganime
Department
Mobile
Direct fax
Direct tel.
Personal e-mail
Version 05.0
+905057089098
[email protected]
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Appendix 2. Affirmation regarding public funding
The Project is not benefitting from any public funds and this is evidenced by the ODA declaration
signed and uploaded to the Gold Standard Foundation Registry
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Appendix 3. Applicability of methodology and standardized
baseline
The project activity is Construction and operation of a power plant that uses renewable energy
sources and supplies electricity to the grid (greenfield power plant). Therefore ACM0002 - Gridconnected electricity generation from renewable sources is the appropriate methodology. Please
find below the production license of the project activity:
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Appendix 4. Further background information on ex ante
calculation of emission reductions
The following Tables provide the data used for the calculation of “Combined Margin Emission
Factor”:
Table 1:
Source: http://www.teias.gov.tr/TürkiyeElektrikİstatistikleri/istatistik2014/yakıt49-54/50.xls
52
Table-2: IPCC Default CO2 Emission Factors
Fuel Type:
Coal
Lignite
Fuel Oil
Diesel
EF (tCO2/TJ)
92.80
90.90
75.50
72.60
Fuel Type:
LPG
Naphtha
Natural Gas
Bitumen
EF (tCO2/TJ)
61.60
69.30
54.30
73.00
53
Table 3:
Source: http://www.teias.gov.tr/TürkiyeElektrikİstatistikleri/istatistik2014/yakıt49-54/52.xls
54
Table 4:
Source: Computation based on Table 3 (in Appendix-4) provided above.
55
Table 5:
Source: Computation based on Table 3 (in Appendix-4) provided above.
56
Table 6: Source: http://www.teias.gov.tr/TürkiyeElektrikİstatistikleri/istatistik2014/uretim%20tuketim(24-48)/43(06-14).xls
57
Table 7: Source: http://www.teias.gov.tr/TürkiyeElektrikİstatistikleri/istatistik2014/uretim%20tuketim(24-48)/35(1984-2014).xls
58
Table 8a:Source:
http://www.teias.gov.tr/projeksiyon/KAPASITE%20PROJEKSIYONU%202010.pdf
Project
Production
Capacity Potential
Firm Production
Unit Name
Type
Fuel
(MW)
(GWh)
(GWh)
Enerji-Sa
1,000.00 7,540.00
7,540.00
Private
Natural
(Bandirma)
Gas
Uğur
Enerji
Ür. 12.00
100.86
100.86
Private
Natural
Tic.Ve San. A.Ş.
Gas
(İlave)
Ziyaret Res (Ziyaret 22.50
0.00
0.00
Private
Wind
Res Elek.)(İlave)
Kahta
I
Hes 7.12
0.00
0.00
Private
Hydro
(Erdemyildiz Elek.
Ürt.)
Rotor
Elektrik 2.50
0.00
0.00
Private
Wind
(Gökçedağ
Res)
(İlave)
Azmak-Ii Reg. Ve -18.07
0.00
0.00
Private
Hydro
Hes (Düzeltme)
Itc Adana Biokütle 0.00
0.00
0.00
Private
LFG
Sant. (Düzeltme)
Enerji-Sa
-69.20
0.00
0.00
Private
Natural
(Bandirma)
Gas
(Düzeltme)
Uluabat
Kuvvet 48.51
0.00
0.00
Private
Hydro
Tüneli Ve Hes
Sabunsuyu Ii Hes 7.35
21.00
12.00
Private
Hydro
(Ang Enerji Elk.)
Eren Enerji Elektrik 600.00
4,005.88
4,005.88
Private
Coal
Ür. A.Ş. (İlave)
Burç Bendi Ve Hes 27.33
0.00
0.00
Private
Hydro
(Akkur Enerji)
Karadeniz
El. 31.08
82.44
46.46
Private
Hydro
(Uzundere-1
Hes)(İlave)
Güzelçay-Ii Hes (İlk 4.96
26.33
14.70
Private
Hydro
Elektrik Enerji)
Murgul
Bakir 19.60
40.50
31.59
Private
Hydro
(Ç.Kaya) (İlave)
Kuyucak Res (Alize 8.00
0.00
0.00
Private
Wind
Enerji Üret.)
Soma Res (Bilgin 30.00
0.00
0.00
Private
Wind
Wind San.)(İlave)
Uluabat
Kuvvet 48.51
0.00
0.00
Private
Hydro
Tüneli
Ve
Hes
(İlave)
Marmara Pamuklu 26.19
203.45
203.45
Autoprod Natural
Mensucat (İlave)
ucer
Gas
Fritolay
Gida 0.33
3.00
3.00
Autoprod Biogas
San.Ve Tic A.Ş.
ucer
(İlave)
Egemen
1
Hes 8.82
0.00
0.00
Private
Hydro
(Enersis Elektrik)
Reşadiye 1 Hes 15.68
0.00
0.00
Private
Hydro
(Turkon Mng Elekt.)
Date
of
Commissionin
g
7-Oct-10
7-Oct-10
13-Oct-10
14-Oct-10
15-Oct-10
25-Oct-10
25-Oct-10
25-Oct-10
27-Oct-10
28-Oct-10
1-Nov-10
4-Nov-10
7-Nov-10
11-Nov-10
11-Nov-10
11-Nov-10
11-Nov-10
25-Nov-10
25-Nov-10
26-Nov-10
26-Nov-10
26-Nov-10
59
Unit Name
Aliağa Çakmaktepe
Enerji (İlave)
Yedigöze
Hes
(Yedigöze Elektrik)
Sönmez
Enerji
Üretim
(Uşak)
(İlave)
AK-ENERJİ (UŞAK
OSB)(Uşak-Ak.En.)
Ak-Enerji(Dg+N)
(Deba-Denizli)
Kuyucak Res (Alize
Enerji Ür.) (İlave)
Umut Iii Reg. Ve
Hes (Nisan Elektr.)
Tüpraş
Rafineri
(İzmit) (İlave)
Polyplex
Europa
Polyester Film
Altek Alarko Elektrik
Santrallari
Aksa
Enerji
(Demirtaş/Bursa)
Sares Res (Garet
Enerji Üretim)
Feke 2 Baraji Ve
Hes (Akkur Enerji)
Egemen 1b Hes
(Enersis Elektrik)
Eren Enerji Elektrik
Ür. A.Ş. (İlave)
Rasa Enerji (Van)
(İlave)
Kalkandere Reg. Ve
Yokuşlu Hes
Turguttepe
Res
(Sabaş Elektrik Ür.)
AK
TEKSTİL-1
(G.Antep)
Silopi Elektrik Ür.
A.Ş. (Esenboğa)
International
Hospital İstanbul Aş.
Tüpraş
Rafineri
(İzmit) (Düzeltme)
Yalova Elyaf
Capacity
(MW)
69.84
Project
Production
Potential
(GWh)
557.92
Firm Production
(GWh)
557.92
Type
Private
155.33
474.00
268.00
Private
2.56
19.77
19.77
Private
Natural
Gas
7-Dec-10
-15.24
0.00
0.00
Private
9-Dec-10
-15.60
0.00
0.00
Private
17.60
0.00
0.00
Private
Natural
Gas
Natural
Gas
Wind
12.00
26.00
15.00
Private
Hydro
13-Dec-10
40.00
258.82
258.82
61.00
61.00
21.89
151.36
151.36
-1.40
0.00
0.00
Private
Natural
Gas
Natural
Gas
Natural
Gas
Waste
15-Dec-10
7.81
Autoprod
ucer
Autoprod
ucer
Private
15.00
0.00
0.00
Private
Wind
22-Dec-10
69.34
0.00
0.00
Private
Hydro
24-Dec-10
11.10
0.00
0.00
Private
Hydro
28-Dec-10
600.00
4,005.88
4,005.88
Private
Coal
29-Dec-10
10.12
64.41
64.41
Private
29-Dec-10
14.54
0.00
0.00
Private
Natural
Gas
Hydro
22.00
0.00
0.00
Private
Wind
30-Dec-10
-13.04
0.00
0.00
0.00
0.00
0.77
6.00
6.00
-39.14
0.00
0.00
-12.30
0.00
0.00
FUELOİL
FUELOİL
Natural
Gas
Natural
Gas
Natural
Gas
31-Dec-10
-44.78
Autoprod
ucer
Private
Autoprod
ucer
Autoprod
ucer
Autoprod
ucer
Fuel
Natural
Gas
Hydro
Date
of
Commissionin
g
26-Nov-10
2-Dec-10
9-Dec-10
9-Dec-10
16-Dec-10
18-Dec-10
21-Dec-10
30-Dec-10
31-Dec-10
31-Dec-10
31-Dec-10
31-Dec-10
Table 8b:
Source: http://www.teias.gov.tr/KAPASITEPROJEKSIYONU2011.pdf
60
Unit Name
Akim Enerji Başpinar (Süper Film)
Aksa Akrilik (İthal Köm.+D.G)
Aksa Enerji (Antalya)
Aksa Enerji (Antalya) (İlave)
Aldaş Altyapi Yönetim Danişmanlik
Aliağa Çakmaktepe Enerji (İlave)
Aliağa Çakmaktepe Enerji (İlave)
Bekirli Tes (İçdaş Elektrik En.)
Bosen Enerji Elektrik Üretim Aş.
Boyteks Tekstil San. Ve Tic. A.Ş.
Cengiz Çift Yakitli K.Ç.E.S.
Cengiz Enerji San.Ve Tic.A.Ş.
Eti Bor (Borik Asit)(Emet) (Düzeltme)
Fraport Ic İçtaş Antalya Havalimani
Global Enerji (Pelitlik)
Gordion Avm (Redevco Üç Emlak)
Goren-1 (Gaziantep Organize San.)
Gülle Enerji(Çorlu) (İlave)
Hamitabat (Lisans Tadili)
Hasirci Tekstil Tic. Ve San. Ltd. Şti.
Hg Enerji Elektrik Üret. San.Tic. A.Ş.
Isparta Mensucat (Isparta)
İstanbul Sabiha Gökçen Ul.Ar. Hav.
Karkey (Silopi 1)
Knauf İnş. Ve Yapi Elemanlari Sn.
Lokman Hekim Engürü Sağ.(Sincan)
Mardin-Kiziltepe (Aksa Enerji)
Mosb Enerji Elektrik Üretim Ltd. Şti.(İlave)
Nuh Enerji El. Ürt.A.Ş. (Enerji Sant.-2)
Odaş Doğalgaz Kçs (Odaş Elektrik)
Polyplex Europa Polyester Film
Samsun Tekkeköy En. San. (Aksa En.)
Samur Hali A.Ş.
Saray Hali A.Ş.
Şanliurfa Osb (Rasa Enerji Ür. A.Ş.)
Aksu Reg. Ve Hes (Kalen Enerji)
Değirmendere (Kadirli) (Ka-Fnih Elek.)
Derme (Kayseri Ve Civari Enerji)
Erkenek (Kayseri Ve Civari Enerji)
Balkondu I Hes (Bta Elektrik Enerji)
Batman
Girlevik (Boydak Enerji)
Berdan
Boğuntu Hes (Beyobasi Enerji)
Hakkari (Otluca) (Nas Enerji A.Ş.)
Hasanlar
Bünyan (Kayseri Ve Civari El. T.A.Ş)
Çakirman Reg. Ve Hes (Yusaka En.)
Capacity
(Mw)
25.32
25.00
300.00
300.00
1.95
130.95
8.73
600.00
93.00
8.60
131.34
35.00
0.60
8.00
4.00
2.01
48.65
3.90
36.00
2.00
52.38
4.30
4.00
100.44
1.56
0.51
32.10
43.50
119.98
54.96
3.90
131.34
4.30
4.29
116.76
5.20
0.50
4.50
0.32
9.19
0.48
3.04
10.20
3.80
1.28
9.35
1.16
6.98
Project
Production
Potential
(Gwh)
177.00
175.00
1,800.00
1,800.00
15.00
986.25
67.76
4.32
698.09
67.00
985.00
281.29
4.47
64.00
29.91
15.00
277.00
18.43
244.15
15.00
366.00
33.00
32.00
697.67
12.00
44.00
225.00
351.86
900.00
415.00
31.45
980.00
33.00
33.00
800.00
16.00
1.20
14.00
1.23
33.00
1.16
21.00
47.20
17.00
6.00
39.90
3.40
22.00
Firm
Production
(Gwh)
177.00
175.00
1,800.00
1,800.00
15.00
986.25
67.76
4.32
698.09
67.00
985.00
281.29
4.47
64.00
29.91
15.00
277.00
18.43
244.15
15.00
366.00
33.00
32.00
697.67
12.00
44.00
225.00
351.86
900.00
415.00
31.45
980.00
33.00
33.00
800.00
12.00
0.80
7.00
0.74
20.00
1.08
19.00
15.00
10.00
5.00
29.60
3.20
15.00
Type
Private
Private
Private
Private
Autoproducer
Private
Private
Private
Private
Private
Private
Private
Autoproducer
Autoproducer
Private
Autoproducer
Private
Private
Government
Autoproducer
Private
Autoproducer
Autoproducer
Private
Autoproducer
Autoproducer
Private
Private
Private
Private
Autoproducer
Private
Autoproducer
Autoproducer
Private
Private
Op.Rights Transfer
Op.Rights Transfer
Op.Rights Transfer
Private
Private
Op.Rights Transfer
Private
Private
Op.Rights Transfer
Government
Private
Private
61
Fuel
Natural G
Natural G
Natural G
Natural G
Natural G
Natural G
Natural G
Imported
Natural G
Natural G
Natural G
Natural G
Natural G
Natural G
Natural G
Natural G
Natural G
Natural G
Natural G
Natural G
Natural G
Natural G
Natural G
F.Oil
Natural G
Natural G
F.Oil
Natural G
Natural G
Natural G
Natural G
Natural G
Natural G
Natural G
Natural G
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Unit Name
İnegöl(Cerrah) (Kent Solar Elektrik)
İznik (Dereköy) (Kent Solar Elektrik)
Çamardi (Kayseri Ve Civari El. T.A.Ş)
Karaçay (Osmaniye) (Ka-Fnih Elektrik)
Çamlica Iii Hes (Çamlica Elektrik)
Çamlikaya Reg.Ve Hes (Çamlikaya En)
Çanakçi Hes (Can Enerji Entegre)
Çanakçi Hes (Can Enerji Entegre)
Çeşmebaşi Reg. Ve Hes (Gimak En.)
Kayadibi (Bartin) (İvme Elektromek.)
Kernek (Kayseri Ve Civari Enerji)
Çukurçayi Hes (Aydemir Elektrik Ür.)
Daren Hes Elektrik (Seyrantepe)
Duru 2 Reg. Ve Hes (Durucasu Elek.)
Kovada-I (Batiçim Enerji Elektrik)
Kovada-Ii (Batiçim Enerji Elektrik)
Erenköy Reg. Ve Hes (Nehir Enerji)
Eşen-1 Hes (Göltaş Enerji Elektrik)
Eşen-1 Hes (Göltaş Enerji Elektrik)
Gökmen Reg. Ve Hes (Su-Gücü Elekt.)
Kuzuculu (Dörtyol) (Ka-Fnih Elektrik)
M.Kemalpaşa (Suuçtu) (Kent Solar)
Malazgirt (Mostar Enerji Elektrik)
Tekirdağ-Çorlu Teks.Tes.(Nil Örme)
Tirenda Tire Enerji Üretim A.Ş.
Toros Tarim (Mersin) (Nafta+D.Gaz)
Tüpraş O.A. Rafineri (Kırıkkale) (İlave)
Yeni Uşak Enerji Elektrik Santrali
Zorlu Enerji (B.Karıştıran)
Adilcevaz (Mostar Enerji Elektrik)
Ahlat (Mostar Enerji Elektrik)
Hacininoğlu Hes (Enerji-Sa Enerji)
Hacininoğlu Hes (Enerji-Sa Enerji)
Hasanlar Hes (Düzce Enerji Birliği)
İncirli Reg. Ve Hes (Laskar Enerji)
Karasu 4-3 Hes (İdeal Enerji Üretimi)
Karasu 5 Hes (İdeal Enerji Üretimi)
Bayburt (Boydak Enerji)
Karasu I Hes (İdeal Enerji Üretimi)
Besni Kayseri Ve Civari Enerji)
Kazankaya Reg. Ve İncesu Hes (Aksa)
Kesme Reg. Ve Hes (Kivanç Enerji)
Kesme Reg. Ve Hes (Kivanç Enerji)
Çağ-Çağ (Nas Enerji A.Ş.)
Kiran Hes (Arsan Enerji A.Ş.)
Koruköy Hes (Akar Enerji San. Tic.)
Köyobasi Hes (Şirikoğlu Elektrik)
Kozdere Hes (Ado Madencilik Elkt. )
Capacity
(Mw)
0.27
0.24
0.07
0.40
27.62
2.82
4.63
4.63
8.20
0.46
0.83
1.80
49.70
4.49
8.25
51.20
21.46
30.00
30.00
2.87
0.27
0.47
1.22
2.68
58.38
12.14
12.00
8.73
7.20
0.39
0.20
71.14
71.14
4.68
25.20
4.60
4.10
0.40
3.84
0.27
15.00
2.31
2.31
14.40
9.74
3.03
1.07
3.15
Project
Production
Potential
(Gwh)
1.00
1.00
0.01
2.30
43.00
6.71
19.43
19.43
28.00
2.30
0.80
8.00
181.13
22.00
4.10
36.20
87.00
120.00
120.00
13.00
1.30
1.50
4.00
21.00
410.00
96.00
84.78
65.00
54.07
0.80
0.60
180.00
180.00
21.00
126.00
22.00
24.00
1.90
19.00
0.50
48.00
8.02
8.02
25.00
41.00
22.00
5.00
14.00
Firm
Production
(Gwh)
0.80
0.90
0.01
2.00
25.00
3.88
10.96
10.96
17.00
2.00
0.60
4.00
140.88
13.00
1.60
24.40
49.00
65.00
65.00
8.00
1.00
1.30
3.00
21.00
410.00
96.00
84.78
65.00
54.07
0.50
0.50
102.00
102.00
12.00
71.00
12.00
14.00
1.70
11.00
0.20
27.00
4.51
4.51
22.00
23.00
13.00
3.00
8.00
Type
Op.Rights Transfer
Op.Rights Transfer
Private
Op.Rights Transfer
Private
Private
Private
Private
Private
Op.Rights Transfer
Op.Rights Transfer
Private
Private
Private
Op.Rights Transfer
Op.Rights Transfer
Private
Private
Private
Private
Op.Rights Transfer
Op.Rights Transfer
Op.Rights Transfer
Autoproducer
Private
Autoproducer
Autoproducer
Private
Private
Op.Rights Transfer
Op.Rights Transfer
Private
Private
Private
Private
Private
Private
Op.Rights Transfer
Private
Op.Rights Transfer
Private
Private
Private
Op.Rights Transfer
Private
Private
Private
Private
62
Fuel
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Natural G
Natural G
Naphta
Naphta
Natural G
Natural G
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Unit Name
Kulp I Hes (Yildizlar Enerji Elk.Ür.)
Çemişkezek (Boydak Enerji)
Molu Enerji (Zamantı-Bahçelik Hes)
Muratli Reg. Ve Hes (Armahes El.)
Narinkale Reg. Ve Hes (Ebd Enerji)
Ören Reg. Ve Hes (Çelikler Elektrik)
Otluca Ii Hes (Beyobasi Enerji Ür.)
Pinarbaşi (Kayseri Ve Civari El.T.A.Ş)
Poyraz Hes (Yeşil Enerji Elektrik)
Saraçbendi Hes (Çamlica Elektrik)
Sarikavak Hes (Eser Enerji Yat. Aş.)
Sayan Hes (Karel Elektrik Üretim)
Sefaköy Hes (Pure Enerji Üretim Aş.)
Seyrantepe Hes (Düzeltme))
Sizir (Kayseri Ve Civari El. T.A.Ş)
Söğütlükaya (Posof Iii) Hes
Tefen Hes (Aksu Madencilik San.)
Tefen Hes (Aksu Madencilik San.)
Turunçova(Finike) (Turunçova En.)
Tuztaşi Hes (Gürüz Elektrik Ür.)
Uludere (Nas Enerji A.Ş.)
Üzümlü Hes (Akgün Enerji Üretim)
Varto (Mostar Enerji Elektrik)
Yamaç Hes (Yamaç Enerji Üretim A.Ş.)
Yaprak Ii Hes (Nisan Elektromek.)
Yaprak Ii Hes (Nisan Elektromek.)
Yaşil Hes (Yaşil Enerji Elektrik)
Yaşil Hes (Yaşil Enerji Elektrik)
Yedigöl Reg. Ve Hes (Yedigöl Hidr.)
Yedigöze Hes (Yedigöze Elek.) (İlave)
Ayrancilar Hes (Muradiye Elektrik)
Ayrancilar Hes (Muradiye Elektrik)
Bayramhacili Baraji Ve Hes
Cevher I-Ii Reg. Ve Hes (Özcevher En.)
Karasu Ii Hes (İdeal Enerji Üretimi)
Bandirma Enerji (Bandirma Res)
Capacity
(Mw)
22.92
0.12
4.17
26.70
30.40
6.64
6.36
0.10
2.66
25.48
8.06
14.90
33.11
7.14
5.76
6.13
11.00
22.00
0.55
1.61
0.64
11.36
0.29
5.46
5.40
5.40
1.52
2.28
21.90
155.33
13.38
18.72
47.00
16.36
3.08
3.00
Project
Production
Potential
(Gwh)
78.00
0.80
30.00
94.00
108.00
29.00
27.00
0.40
10.00
101.00
43.00
47.00
121.00
26.02
46.00
31.00
47.00
94.00
1.50
10.00
3.20
41.00
0.80
17.00
16.00
16.00
6.00
9.00
77.00
474.83
53.34
74.64
175.00
65.00
13.00
10.50
Firm
Production
(Gwh)
44.00
0.50
30.00
55.00
61.00
16.00
15.00
0.30
6.00
57.00
24.00
27.00
68.00
20.24
35.00
18.00
26.67
53.33
0.80
6.00
2.60
23.00
0.60
10.00
10.50
10.50
3.20
4.80
42.00
133.95
31.16
43.73
95.00
32.00
8.00
9.50
Table 8c
Source:http://www.teias.gov.tr/KAPASITEPROJEKSIYONU2012.pdf
Project
Production
Ownershi Capacity
Potential
Name Of Unit
Fuel
p
(MW)
(Gwh)
Acarsoy
Termik Natural Private
50
375
Kom.Çev.Sant. (Acarsoy Gas
En.)
Afyon
Dgkç
(Dedeli Natural Private
126.1
945
Doğalgaz Elektrik Ür.)
Gas
Age Doğalgaz Kom. Çev. Natural Private
94
1057
Type
Private
Op.Rights Transfer
Private
Private
Private
Private
Private
Op.Rights Transfer
Private
Private
Private
Private
Private
Private
Op.Rights Transfer
Private
Private
Private
Op.Rights Transfer
Private
Op.Rights Transfer
Private
Op.Rights Transfer
Private
Private
Private
Private
Private
Private
Private
Private
Private
Private
Private
Private
Private
Firm
Production
Gwh
375
Fuel
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Hydro
Wind
Date
of
Commissioni
ng
27/12/12
945
705
63
Name Of Unit
Sant. (Age Denizli)
Age Doğalgaz Kom. Çev.
Sant. (Age Denizli)
Akdeniz Kimya San. Ve
Tic. A.Ş.
Akdeniz Kimya San. Ve
Tic. A.Ş.
Akköprü (Dalaman)
Akköprü (Dalaman)
Akköy Ii Hes (Akköy Enerji
A.Ş.)
Akköy Ii Hes (Akköy Enerji
A.Ş.)
Akköy-Espiye Hes (Koni
İnşaat San. A.Ş.)
Aksa Akrilik Kimya San.
A.Ş. (İthal Köm.+D.G)
Aksu Res (Aksu Temiz
Enerji Elektrik Üretim)
Alabalik Reg. Ve Hes
Santrali I-Ii (Darboğaz Elk.
Ür. San.)
Ales Doğalgaz Kom. Çev.
Sant. (Ales Elekt.)
Alpaslan I (Elektrik Üretim
A.Ş.)
Alpaslan I (Elektrik Üretim
A.Ş.)
Altinyildiz Mensucat Ve
Konf. Fab. (Tekirdağ)
Anak
Hes
(Kor-En
Korkuteli Elek. Üret. San.)
Arakli-1
Reg.
Ve
Hes(Yüceyurt
Enerji
Üretim)
Arakli-1
Reg.
Ve
Hes(Yüceyurt
Enerji
Üretim)
Arca Hes (Gürsu Temiz
Enerji Üretim A.Ş.)
Arca Hes (Gürsu Temiz
Arel Enerji Biyokütle Tesisi
(Arel Çevre)
Arel Enerji Biyokütle Tesisi
(Arel Çevre)
Arpa Reg. Ve Hes (Mck
Elektrik Üretim A.Ş.)
Ownershi
p
Capacity
(MW)
Project
Production
Potential
(Gwh)
Private
47
1057
352
Auto
Producer
Auto
Producer
EUAS
EUAS
Private
2.022
15
15
2.022
15
15
57.5
57.5
114.84
171.5
171.5
449.5
88
88
254
Hydro
Private
114.84
449.5
254
Hydro
Private
8.912
40
22
Natural
Gas
Wind
Private
75
525
525
Private
36
0
0
Wind
Private
30
0
0
Wind
Private
6
0
0
Hydro
Private
13.84
0
0
Natural
Gas
Hydro
Private
49
370
370
EUAS
80
244
209
Hydro
EUAS
80
244
209
Natural
Gas
Hydro
Auto
Producer
Private
5.5
38
38
3.76
15
9
Hydro
Private
10.203
39
21.84
Hydro
Private
13.067
50
28
Hydro
Private
5.45
0
0
Hydro
Private
10.9
0
0
Solid
Waste
Solid
Waste
Hydro
Private
1.2
9
9
Private
1.2
9
9
Private
32.412
78
44
Fuel
Gas
Natural
Gas
Natural
Gas
Natural
Gas
Hydro
Hydro
Hydro
Firm
Production
Gwh
Date
of
Commissioni
ng
29/12/12
64
Name Of Unit
Asaş Alüminyum Sanayi
Ve Ticaret A.Ş.
Ataköy
(Zorlu
Doğal
Elektrik Üretimi A.Ş.)
Avcilar Hes (Avcilar Enerji
Elektrik Üret.)
Ayancik Hes (İlk Elektrik
Enerji Üretimi Sn.)
Ayrancilar Hes (Muradiye
Elektrik Üretim)
Bağiştaş Ii Hes (Akdenizli
Elektrik Üretim)
Balikesir
Res
(Bares
Balikesir
Res
(Bares
Balikesir Res (Enerjisa
Balkusan Baraji Ve Hes 1
Nolu Sant. (Karen)
Balkusan Baraji Ve Hes 2
Nolu Sant. (Karen)
Balsuyu Mensucat San. Ve
Tic. A.Ş.
Bamen
Kojenerasyon
(Başyazicioğlu Tekstil)
Bandirma Res (Yapisan
Bangal Reg. Ve Kuşluk
Hes (Kudret Enerji)
Bektemur Hes (Diz-Ep
Elektrik Üretim Ltd.)
Bereket Enerji Üretim A.Ş.
(Biogaz)
Beyköy
(Zorlu
Doğal
Beypi Beypazari Tarimsal
Üretim Pz. Sn. A.Ş.
Bilecik
Doğalgaz
Çs.
(Tekno Doğalgaz Çev.)
Bilecik
Doğalgaz
Kçs.
(Dedeli Doğalgaz El.)
Bilecik
Doğalgaz
Kçs.
(Dedeli Doğalgaz El.)
Bilkur Tekstil Boya Tic.
A.Ş.
Binatom Elektrik Üretim
Fuel
Natural
Gas
Hydro
Ownershi
p
Auto
Producer
ORT
Capacity
(MW)
8.6
Project
Production
Potential
(Gwh)
65
5.525
20
11
Hydro
Private
16.743
49
28
Hydro
Private
15.6
65
37
Hydro
Private
9.359
0
0
Hydro
Private
32.4
122
69
Wind
Private
112.8
52.90
45.10
Wind
Private
112.8
63.48
54.12
Wind
Private
112.8
95.23
81.18
Wind
Private
112.8
63.48
54.12
Wind
Private
112.8
74.06
63.14
Wind
Private
112.8
84.65
72.16
Hydro
Private
13
0
0
Hydro
Private
25
0
0
Natural
Gas
Natural
Gas
Wind
Auto
Producer
Auto
Producer
Private
9.73
68
68
2.145
14
14
5
0
0
Hydro
Private
17
0
0
Hydro
Private
3.492
20
11
Solid
Waste
Hydro
Private
0.635
0
0
ORT
16.8
87
87
Natural
Gas
Natural
Gas
Natural
Gas
Natural
Gas
Natural
Gas
Natural
Auto
Producer
Private
8.6
63
63
25.8
190
190
Private
19.4
142
142
Private
107.03
803
803
Auto
Producer
Private
2
14
14
2.145
16
16
Firm
Production
Gwh
65
Date
of
Commissioni
ng
23/12/12
65
Name Of Unit
A.Ş. (Emet/Kütahya)
Bis Enerji(Sanayi/ Bursa)
Bosen
Enerji
Elektrik
Üretim Aş.(Bursa)
Boyabat Baraji Ve Hes
(Boyabat Elektrik)
Bozyaka Res (Kardemir
Haddecilik Ve Elekt.)
Büyükdüz
Hes
(Ayen
Enerji A.Ş.)
Çağlayan Hes (Çağlayan
Hes Enerji Üretim)
Can 1 Hes (Hed Elektrik
Üretim A.Ş.)
Çarşamba Hes (Çarşamba
Enerji Elektrik)
Ceyhan Hes (Berkman
Hes) (Enova En Üret.)
Çildir (Zorlu Doğal Elektrik
Üretimi A.Ş.)
Çinar-1 Hes (Aycan Enerji
Üretim Tic. Ve Sn.)
Çukurçayi Hes (Aydemir
Cuniş Reg. Ve Hes (Rinerji
Rize Elektrik Ür.)
Cuniş Reg. Ve Hes (Rinerji
Rize Elektrik Ür.)
Dağpazari Res (Enerjisa
Dağpazari Res (Enerjisa
Demirciler Hes (Pak Enerji
Üretimi San.)
Demirciler Hes (Pak Enerji
Üretimi San.)
Deniz Jeotermal (Maren
Maraş Elektrik)
Denizli Jeotermal (Zorlu
Doğal Elek. Ür.A.Ş.)
Diğerleri (İzole) (Ereğli
Şeker)
Diğerleri (İzole) (Kirşehir
Şeker)
Dinar Res (Olgu Enerji
Yatirim Üretim)
Ownershi
p
Capacity
(MW)
Project
Production
Potential
(Gwh)
Private
2.145
16
16
Private
4.044
30
30
Private
2.022
15
15
Private
48
361.57
361.57
Private
27.96
209.86
209.86
Private
513
0
0
Wind
Private
12
0
0
Hydro
Private
68.862
192
109
Hydro
Private
6
21
12
Hydro
Private
1.844
10
6
Hydro
Private
11.31
63
36
Hydro
Private
12.605
50.35
31.34
Hydro
ORT
15.36
30
20
Hydro
Private
9.26
34
19
Hydro
Private
1.8
4
2
Hydro
Private
2.8
12
7
Hydro
Private
5.6
24
14
Wind
Private
36
0
0
Wind
Private
3
0
0
Hydro
Private
3.124
0
0
Hydro
Private
5.317
0
0
Geothe
rmal
Lignite
Private
24
0
0
ORT
15
105
105
Fuel Oil
Auto
Producer
Auto
Producer
Private
9.5
30
30
5.9
18
18
16.1
0
0
Fuel
Gas
Natural
Gas
Natural
Gas
Natural
Gas
Natural
Gas
Natural
Gas
Hydro
Fuel Oil
Wind
Firm
Production
Gwh
Date
of
Commissioni
ng
66
Name Of Unit
Doğankaya Hes (Mar-En
Enerji Üret. Tic.)
Dumlu Hes (Dumlu Enerji
Elektrik Üretim)
Durmazlar Makina Sanayi
Ve Ticaret A.Ş.
Durum Gida Termik Kojen.
Sant. (Durum Gida)
Ege
Seramik
Enerji
Santrali
Eger Hes (Eger Elektrik
Üretim Ltd. Şti.)
Ekim Biyogaz (Ekim Grup
Elektrik Üretim)
Enerji-Sa (Çanakkale)
Enerji-Sa (Köseköy)
Enerji-Sa (Mersin)
Enerji-Sa (Zeytinli/Adana)
Erdemir(F.O+K.G+Y.F.G+
Dg)(Ereğli-Zonguldak)
Eren Enerji Elektrik Üretim
A.Ş.
Erik Hes (Elektrik Üretim
A.Ş.)
Ermenek (Elektrik Üretim
A.Ş.)
Ermenek (Elektrik Üretim
A.Ş.)
Erzurum Meydan Avm
(Redevko Bir Emlak)
Es Es Eskişehir Enerji
San. Ve Tic. A.Ş.
Esendurak Hes (Meral
Elektrik Üretim)
Feke 1 Hes (Akkur Enerji
Üretim Tic. Ve San.)
Feke 2 Baraji Ve Hes
(Akkur Enerji Üretim)
Findik I Hes (Adv Elektrik
Üretim Ltd. Şti.)
Gaski Merkez Atik Su
Aritma Tesisi
Gemciler Reg. Ve Hes
(Boztepe Enerji Üret.)
Gökgedik
Hes
(Uhud
Enerji Üretim Tic.)
Gökgedik
Hes
(Uhud
Enerji Üretim Tic.)
Göknur Gida Mad. En. İm.
Fuel
Hydro
Ownershi
p
Private
Capacity
(MW)
20.55
Project
Production
Potential
(Gwh)
98
Hydro
Private
3.982
9
5
Natural
Gas
Natural
Gas
Natural
Gas
Hydro
Auto
Producer
Auto
Producer
Auto
Producer
Private
1.286
10
10
3.6
29
29
13.08
90
90
1.92
10
6
Solid
Waste
Natural
Gas
Natural
Gas
Natural
Gas
Natural
Gas
Natural
Gas
Importe
d Coal
Hydro
Private
1.2
10
10
Private
0.915
7.32
7.32
Private
120
930
930
Private
1.465
66
520
Private
0.83
5.81
5.81
Auto
Producer
Private
53.9
327
327
30
196
196
EUAS
6.48
34
21
Hydro
EUAS
151.2
593.5
408.5
Hydro
EUAS
151.2
593.5
408.5
Natural
Gas
Biogas
2.436
16
16
2.042
15
15
Hydro
Auto
Producer
Auto
Producer
Private
9.33
0
0
Hydro
Private
29.4
0
0
Hydro
Private
69.34
0
0
Hydro
Private
11.25
48
27
Biogas
1.659
12
12
Hydro
Auto
Producer
Private
7.98
35
20
Hydro
Private
20.49
84
63
Hydro
Private
3.776
16
12
Importe
Auto
1.55
6
6
Firm
Production
Gwh
56
Date
of
Commissioni
ng
27/12/2012
67
Name Of Unit
İt. İh. Tic. Ve San. Aş.
Goodyear (İzmit/Köseköy)
Güdül 2 Hes (Yaşam
Güllübağ Baraji Ve Hes
(Senenerji Enerji)
Günaydin Res (Manres
Günder Reg. Ve Hes (Arik
Günder Reg. Ve Hes (Arik
Gürteks İplik Sanayi Ve
Ticaret A.Ş.
Hatipoğlu
Plastik
Yapi
Elemanlari San.
Horu Reg. Ve Hes (Maraş
Enerji Yatirim Sn.)
Horu Reg. Ve Hes (Maraş
Enerji Yatirim Sn.)
Horyan Hes (Horyan Enerji
A.Ş.)
İkizdere
(Zorlu
Doğal
İnnores Elektrik Yuntdağ
Rüzgar (Aliağa-İzmir)
İşbirliği Enerji Üretim San.
Ve Tic. A.Ş.
Itc Adana Enerji Üretim
(Adana Biokütle Snt)
Itc Bursa Enerji Üretim
San. Ve Tic. A.Ş.
San. Ve Tic. A.Ş.
San. Ve Tic. A.Ş.
İzaydaş
(İzmit
Çöp)(Köseköy)
İzmir Büyük Efes Oteli
Kojenerasyon Tes.
Jti Torbali Kojenerasyon
Santr. (Jti Tütün)
Karadağ Res (Garet Enerji
Üretim)
Kartalkaya Hes (Sir Enerji
Üretim San.)
Kayadüzü Res (Baktepe
Enerji A.Ş.)
Enerji A.Ş.)
Enerji A.Ş.)
Fuel
d Coal
Natural
Gas
Hydro
Ownershi
p
Producer
Auto
Producer
Private
Capacity
(MW)
Project
Production
Potential
(Gwh)
5.2
39
39
4.88
20
15
Hydro
Private
96
0
0
Wind
Private
10
0
0
Hydro
Private
28.22
0
0
Hydro
Private
0
0
0
Natural
Gas
Natural
Gas
Hydro
Auto
Producer
Auto
Producer
Private
6.698
53
53
2
14
14
4.24
17
12.5
Hydro
Private
4.24
17
12.5
Hydro
Private
5.68
23
15
Hydro
ORT
18.6
110
100
Wind
Private
5
0
0
Natural
Gas
Solid
Waste
Solid
Waste
Solid
Waste
Solid
Waste
Solid
Waste
Natural
Gas
Natural
Gas
Wind
Private
19.46
146
146
Private
4.245
0
0
Private
7
0
0
Private
1.4
0
0
Private
1.4
0
0
Private
0.33
2.22
2.22
Auto
Producer
Auto
Producer
Private
1.2
9
9
4
30
30
10
0
0
Hydro
Private
8.001
27
15
Wind
Private
7.5
0
0
Wind
Private
25
0
0
Wind
Private
6.5
0
0
Firm
Production
Gwh
Date
of
Commissioni
ng
68
Name Of Unit
Kayaköprü 2 Hes (Arsan
Enerji A.Ş.)
Kayseri Kati Atik Deponi
Sahasi (Her Enerji)
Keskinoğlu Tavukçuluk Ve
Damizlik İşlet.
Kilavuzlu Hes (Elektrik
Üretim A.Ş.)
Kirikdağ Hes (Özenir Enerji
Elektrik Üret.)
Kivanç
Tekstil
San.Ve
Tic.A.Ş.
Kocaeli Çöp Biyogaz (Lfg)
(Körfez Enerji)
Kocaeli Çöp Biyogaz (Lfg)
(Körfez Enerji)
Köknar Hes (Aycan Enerji
Üretim Tic.)
Kozbeyli Res (Doğal Enerji
Elektrik Üretim)
Kozdere
Hes
(Ado
Madencilik Elektrik Ür.)
Küçüker Tekstil San. Ve
Tic. A.Ş.
Kürce Reg. Ve Hes
(Dedegöl Enerji)
Kütahya Ş eker Fabrikasi
(İzole)
Kütahya Ş eker Fabrikasi
(İzole)
Kuzgun
(Zorlu
Doğal
Menge Baraji Ve Hes
(Enerjisa Enerji)
Mercan
(Zorlu
Doğal
Metristepe Res (Can Enerji
Entegre Elekt.)
Metristepe Res (Can Enerji
Entegre Elekt.)
Midilli Reg. Ve Hes (Masat
Enerji Elektrik)
Mosb Enerji Elektrik Üretim
Ltd.
Şti.
(Dg.+M+F.O.)(Manisa)
Murat I-Ii Reg. Ve Hes
(Murat Hes Enerji El.)
Muratli Reg. Ve Hes
(Armahes Elektrik Ür.)
Mursal
I
Hes
(Peta
Mühendislik Enerji)
Mutlu Makarnacilik Sanayi
Ve Ticaret A.Ş.)
Ownershi
p
Private
Capacity
(MW)
10.2
Project
Production
Potential
(Gwh)
36
Solid
Waste
Natural
Gas
Hydro
Private
1.305
0
0
Auto
Producer
EUAS
6
45
45
40.5
150
100
Hydro
Private
16.86
71
40
Natural
Gas
Solid
Waste
Solid
Waste
Hydro
Auto
Producer
Private
2.145
12
12
1.2
0
0
Private
1.063
0
0
Private
8.024
25
15
Wind
Private
20
0
0
Hydro
Private
6.12
9.24
5.28
Lignite
Auto
Producer
Private
5
40
40
12.046
48
36
Fuel
Hydro
Hydro
4.568
4.568
4.568
4.568
Firm
Production
Gwh
36
Hydro
ORT
20.9
36
0
Hydro
Private
44.71
0
0
Hydro
ORT
20.4
0
0
Wind
Private
27.5
0
0
Wind
Private
11.5
0
0
Hydro
Private
20.97
81
45
Date
of
Commissioni
ng
12
Hydro
Private
35.628
0
0
Hydro
Private
11
27
16
Hydro
Private
4.18
17
13
Natural
Gas
Auto
Producer
2
16
16
69
Name Of Unit
Naksan Enerji Elektrik
Üretim A.Ş.
Naksan Enerji Elektrik
Üretim A.Ş.
Niksar Hes (Niksar Enerji
Üretim Ltd. Şti.)
Niksar Hes (Niksar Enerji
Üretim Ltd. Şti.)
Odaş Doğalgaz Kçs (Odaş
Elektrik Üretim)
Odaş Doğalgaz Kçs (Odaş
Elektrik Üretim)
Ofim Enerji Santrali (Ostim
Finans Ve İş Mer.)
Ören
Reg.
Ve
Hes
(Çelikler Elektrik Üretim)
Ortadoğu
Enerji
(Kömürcüoda)
(Şile/İstanbul)
Ortadoğu Enerji (Oda Yeri)
(Eyüp/İstanbul)
Özmaya Sanayi A.Ş.
Pamukova Yen. En. Ve
Elek. Ür. A.Ş.
Pancar Elektrik Üretim
A.Ş.
Pancar Elektrik Üretim
A.Ş.
Papart Hes (Elite Elektrik
Üretim)
Papart Hes (Elite Elektrik
Üretim)
Pisa Tekstil Ve Boya
Fabrikalari (İstanbul)
Polat Hes (Elestaş Elektrik
Üretim A.Ş.)
Polat Hes (Elestaş Elektrik
Üretim A.Ş.)
Poyraz Res (Poyraz Enerji
Elektrik Üretim)
Elektrik Üretim)
Elektrik Üretim)
Samsun Avdan Kati Atik
(Samsun Avdan En.)
Samurlu Res (Doğal Enerji
Elektrik Üret.)
Samurlu Res (Doğal Enerji
Elektrik Üret.)
Sancar Reg. Ve Hes
(Melita Elektrik Üretim)
Ownershi
p
Private
Capacity
(MW)
8
Project
Production
Potential
(Gwh)
60
Private
8
60
60
Private
20.08
0
0
Hydro
Private
20.08
0
0
Natural
Gas
Natural
Gas
Natural
Gas
Hydro
Private
54.96
415
415
Private
18.32
135
135
Private
2.05
16
16
Private
19.932
21.75
12
Solid
Waste
Private
2.83
0
0
Solid
Waste
Natural
Gas
Solid
Waste
Natural
Gas
Natural
Gas
Hydro
Private
4.092
0
0
Auto
Producer
Private
5.354
40
40
1.4
0
0
Private
17.46
130
130
Private
17.46
130
130
Private
22
87.98
66.4
Hydro
Private
4.6
0
0
Natural
Gas
Hydro
Auto
Producer
Private
1.02
7
7
3.28
14
10
Hydro
Private
3.28
14
10
Wind
Private
14
0
0
Wind
Private
20
0
0
Wind
Private
16
0
0
Solid
Waste
Wind
Private
2.4
0
0
Private
12
0
0
Wind
Private
10
0
0
Hydro
Private
0.74
3
2
Fuel
Natural
Gas
Natural
Gas
Hydro
Firm
Production
Gwh
60
Date
of
Commissioni
ng
70
Name Of Unit
Şanliurfa Osb (Rasa Enerji
Üretim A.Ş.)
Sarihidir Hes (Molu Enerji
Üretim A.Ş.)
Selçuk İplik San. Ve Tic.
A.Ş.
Selva Gida San. A.Ş.
Şenköy Res (Eolos Rüzgar
Enerjisi Üretim)
Seyrantepe
Hes
(Seyrantepe Elekt. Üret.)
Sezer
Bio
Enerji
(Kalemirler Enerji Elektr.)
Şifrin
Reg.
Ve
Hes
(Bomonti Elk. Müh. Müş.)
Sinem Jeotermal (Maren
Maraş Elektrik)
Sirakonaklar
Hes
(2m
Soda Sanayi A.Ş. (Mersin)
Söke-Çatalbük Res (Abk
Enerji Elektrik)
Söke-Çatalbük Res (Abk
Enerji Elektrik)
Soma Res (Soma Enerji
Suluköy Hes (Du Elektrik
Üretim A.Ş.)
Tekirdağ-Çorlu Koj. San.
(Ode Yalitim San.)
Teleme Reg. Ve Hes
(Tayen Elektrik Üret.)
Telli I-Ii Hes (Falanj Enerji
Elektrik Üret.)
Tercan
(Zorlu
Doğal
Trakya Yenişehir Cam
San. A.Ş.
Tuğra Reg. Ve Hes (Vira
Tuna
Hes
(Nisan
Elektromekanik Enerji)
Tuzköy Hes (Baten Enerji
Üretimi A.Ş.)
Tuzlaköy-Serge Reg. Ve
Hes (Tuyat Elekt.)
Üçkaya Hes (Şirikçioğlu
Umut I Reg. Ve Hes (Nisan
Elektromekanik)
Vizara Reg. Ve Hes
(Öztürk Elekt. Üret. Ltd.)
Ownershi
p
Private
Capacity
(MW)
11.72
Project
Production
Potential
(Gwh)
82
Private
6
24
18
Natural
Gas
Natural
Gas
Wind
Auto
Producer
Auto
Producer
Private
8.6
65
65
1.712
14
14
26
0
0
Hydro
Private
56.84
207
161
Solid
Waste
Hydro
Private
0.5
4
4
Private
6.744
18
10
Geothe
rmal
Hydro
Private
24
0
0
Private
18
0
0
Wind
252.2
Private
252.2
18
0
0
Wind
Private
12
0
0
Wind
Private
24
0
0
Hydro
Private
6.924
0
0
Natural
Gas
Hydro
Auto
Producer
Private
2.035
15
15
1.57
11
6
Hydro
Private
8.72
32
18
Hydro
ORT
15
51
28
Biogas
6
45
45
Hydro
Auto
Producer
Private
4.9
18
10
Hydro
Private
37.19
92
52
Hydro
Private
8.44
0
0
Hydro
Private
7.14
0
0
Hydro
Private
1.04
10
6
Hydro
Private
5.8
21
12
Hydro
Private
8.578
0
0
Fuel
Natural
Gas
Hydro
Firm
Production
Gwh
82
Date
of
Commissioni
ng
29/12/12
71
Name Of Unit
Yağmur Reg. Ve Hes (Bt
Bordo Elk. Ür.)
Yamanli Iii Kaps. Gökkaya
Hes (Mem Enerji)
Yamanli Iii Kaps. Himmetli
Hes (Mem Enerji)
Yavuz Hes (Arem Enerji
Üretim A.Ş.)
Yedisu Hes (Özaltin Enerji
Üretim Ve İnşaat)
Yedisu Hes (Özaltin Enerji
Üretim Ve İnşaat)
Yeni Uşak Enerji Elektrik
Santrali
Yeni Uşak Enerji Elektrik
Santrali
Yildirim
Hes
(Bayburt
Enerji Üretim Ve Tic.)
Yildirim
Hes
(Bayburt
Enerji Üretim Ve Tic.)
Yokuşlu Kalkandere Hes
(Sanko Enerji)
Yongapan
(Kastamonu
Entegre)(D.İskelesi)
Zeytin Bendi Hes (Zeytin
Enerji Üret. San.)
Zeytin Bendi Hes (Zeytin
Enerji Üret. San.)
Zorlu Enerji (B.Karıştıran)
Fuel
Hydro
Ownershi
p
Private
Capacity
(MW)
8.946
Project
Production
Potential
(Gwh)
0
Hydro
Private
28.54
0
0
Hydro
Private
26.98
0
0
Hydro
Private
5.8
0
0
Hydro
Private
15.14
48
27
Hydro
Private
7.57
24
14
Natural
Gas
Natural
Gas
Hydro
Private
8.73
64
64
Private
1
7
7
Private
7.118
26
15
Hydro
Private
3.559
13
7
Hydro
Private
5.2
0
0
Natural
Gas
Hydro
Auto
Producer
Private
15.04
112
112
5.2
18
10
Hydro
Private
0
0
0
Natural
Gas
Private
25.7
193
193
Firm
Production
Gwh
0
Date
of
Commissioni
ng
30/12/12
72
Appendix 5. Further background information on monitoring
plan
No Further information
73
Appendix 6. Summary of post registration changes
74
Appendix 7. The Legal Framework of the Host Country That
Binds the Project Activity
The Environmental Law (No. 2872), which was published in Turkish Official Gazette No.
18132 dated August 11, 1983 and revised in Turkish Official Gazette No. 26167 dated May
13, 2006 (Law No. 5491) provides the legislative framework for the regulation of industries
and their potential impact on the environment. Industrial projects are subject to varying
levels of review that begin while projects are in the development and pre-operation phases.
Additional regulations apply to facilities once they are in operation.
• The Environmental Law authorized the promulgation of a number of regulations. Those that
pertain to development and operation of renewable energy projects are the following:
• Environmental Impact Assessment Regulation, Official Gazette No. 26939 dated July 17,
2008.
• Water Pollution Control Regulation, Official Gazette No. 25687 dated December 31, 2004
and revised in Official Gazette No. 26786 dated February 13, 2008;
• Regulation on Construction of Cesspits where there is no Wastewater Collection System,
Official Gazette No. 13783 dated March 13, 1971;
• Hazardous Chemicals Regulation, Official Gazette No.21634 dated July 11, 1993 and
revised in Official Gazette No. 27092 dated December 26, 2008;
• Regulation on General Principles of Waste Management, Official Gazette No. 26927 dated
July 5, 2008;
• Hazardous Wastes Control Regulation, Official Gazette No. 25755 dated March 14, 2005;
• Waste Oil Control Regulation, Official Gazette No. 26952 dated July 30, 2008 and revised
Official Gazette No. 27304 dated July 31, 2009;
• Vegetative Waste Oil Control Regulation, Official Gazette No. 25791 dated April 19, 2005;
and revised Official Gazette No. 27305 dated July 31, 2009
• Solid Waste Control Regulation, Official Gazette No. 20814 dated March 14, 1991 and
revised in Official Gazette No. 25777 dated April 5, 2005;
• Medical Waste Control Regulation, Official Gazette No. 25883 dated July 22, 2005;
• Environmental Audit Regulation, Official Gazette No. 27061 dated November 21, 2008;
• Packaging Waste Control Regulation, Official Gazette No. 26562 dated June 24, 2007 and
revised in Official Gazette No. 27046 dated November 6, 2008; and
• Waste Batteries and Accumulators Control Regulation, Official Gazette No. 25569 dated
August 31, 2004 and revised in Official Gazette No. 25744 dated March 03, 2005;
• The Excavation, Construction and Demolition Waste Control Regulation, Official Gazette
No. 25406 dated March 18, 2004;
• Soil Pollution Control Regulation, Official Gazette No. 25831 dated May 31, 2005;
• Regulation Related to Workplace Opening and Operation Permits, Official Gazette No.
25902 dated August 10, 2005 and revised in Official Gazette No. 26492 dated April 13,
2007;
• Industrial Air Pollution Control Regulation, Official Gazette No.27277 dated July 3, 2009
• Air Quality Assessment and Management Regulation, Official Gazette No. 26898 dated
June 6, 2008 and revised in Official Gazette No. 27219 and dated May 5, 2009;
• Air Pollution Control Regulation For Heating Sources, Official Gazette No. 25699 dated
January 13, 2005 and revised in Official Gazette No. 27134 dated February 07, 2009;
• Exhaust Gases Emission Control Regulation, Official Gazette No. 27190 dated April 04,
2009; and
• Regulation on Protection of Wetlands, Official Gazette No. 25818 dated May 17, 2005.
In addition to the Environmental Law and its associated regulations, there are several other laws
that directly or indirectly include environmental review, and thus, are applicable to the proposed
project. The project will comply with the 4857 numbered Labour Law and its regulations stated
below:
• Occupational Health and Safety Statute, Official Gazette No. 14765 dated April 11, 1974;
•
75
•
•
•
•
•
•
•
•
•
Health and Safety Regulation for Construction Works, Official Gazette No. 25325 dated
December 23, 2003;
Regulation on Health and Safety Regarding Temporary Works, Official Gazette No. 25463
dated May 15, 2004.
Other regulations that the project will comply with can be listed as follows:
5346 numbered Utilization of Renewable Energy Resources for the Purpose of Generating
Electrical Energy;
Regulation on Protection and Usage of Agricultural Lands, Official Gazette No. 25766 dated
March 25, 2005;
2863 numbered Law on Protection of Cultural and Natural Heritage (revised by 5226
numbered Law);
4342 numbered Pasture Law;
6831 numbered Forestry Law (amended by 5192 numbered Revision in Forestry Law);
Regulation on Buildings located on the Disaster Areas, Official Gazette No. 26582 dated
July 14, 2007;
76
Appendix 8. Certification of the Project Related to EIA
-----
77
----Document information
Version
Date
Description
05.0
25 June 2014
Revisions to:
•
Include the Attachment: Instructions for filling out the project
design document form for CDM project activities (these
instructions supersede the "Guidelines for completing the
project design document form" (Version 01.0));
•
Include provisions related to standardized baselines;
•
Add contact information on a responsible person(s)/
entity(ies) for the application of the methodology (ies) to the
project activity in B.7.4 and Appendix 1;
•
Change the reference number from F-CDM-PDD to CDMPDD-FORM;
•
Editorial improvement.
04.1
11 April 2012
Editorial revision to change version 02 line in history box from Annex
06 to Annex 06b
04.0
13 March 2012
Revision required to ensure consistency with the “Guidelines for
completing the project design document form for CDM project
activities” (EB 66, Annex 8).
03.0
26 July 2006
EB 25, Annex 15
02.0
14 June 2004
EB 14, Annex 06b
01.0
03 August 2002
EB 05, Paragraph 12
Initial adoption.
Decision Class: Regulatory
Document Type: Form
Business Function: Registration
Keywords: project activities, project design document
78

Project Design Document

Transkript

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