CDM-SSC-PDD (version 02) CDM Executive Boardpage 1
CLEAN DEVELOPMENT MECHANISM SIMPLIFIED PROJECT DESIGN DOCUMENT
FOR SMALL-SCALE PROJECT ACTIVITIES (SSC-CDM-PDD) Version 02
CONTENTS
A. B. C. D. E. F. G.
General description of the small-scale project activity Baseline
methodology Duration of the project activity / Crediting period
Monitoring methodology and plan Calculation of GHG emission
reductions by sources Environmental impacts Stakeholders
comments
Annexes Annex 1: Information on participants in the project
activity Annex 2: Information regarding public funding Appendix
Appendix 1: Baseline Information Appendix 2: Project cash flows and
assumptions certified by Charted Accountant
CDM-SSC-PDD (version 02) CDM Executive Boardpage 2
Revision history of this document Version Number 01 02 Date 21
January 2003 8 July 2005 Description and reason of revision Initial
adoption The Board agreed to revise the CDM SSC PDD to reflect
guidance and clarifications provided by the Board since version 01
of this document. As a consequence, the guidelines for completing
CDM SSC PDD have been revised accordingly to version 2. The latest
version can be found at <
http://cdm.unfccc.int/Reference/Documents>
CDM-SSC-PDD (version 02) CDM Executive Boardpage 3
SECTION A. General description of the small-scale project
activity A.1. Title of the small-scale project activity: >>
Title : 12 MW Bundled Wind Power Project in Tenkasi, Tamilnadu
Version : Version 02 Date : October 2006 A.2. Description of the
small-scale project activity: >> The project activity is the
installation of Wind Electric Generators (WEGs) in Tenkasi of
Tirunelveli District in Tamil Nadu, Southern India. The project is
located in one of the wind rich areas of the country and the
capacity utilisation factor expected is about 28.6% with an
estimated annual generation of 1,884,375 kWh per WEG. The project
consists of 16 WEGs that are connected to the grid. The WEGs owned
by different entities are bundled together. The project activity
generates electricity and sells it to the State grid thereby
displacing electricity that would have been generated from
predominantly thermal source. Electricity generated from the
project activity displaces approximately 22,552.2 t CO2e (tonnes of
Carbon dioxide equivalent) annually. During the initial crediting
period of ten years the quantity of Carbon dioxide emission
reductions achieved would be 225522 t CO2e. The expected lifetime
of the project is twenty years. The project assists in the
sustainable development of the Country, and the State in large by
reducing dependency on fossil fuels, reducing local air pollution,
providing emission free clean electricity and providing employment
to rural youth both during the construction phase and the entire
lifetime of the project. The highly coal dominated power sector in
Tamil Nadu poses severe threats to the energy security and the
environment as well. Promotion of such projects ensures adequate
power supply, improved air quality, alternative sources of energy
and improved local livelihoods. A.3. Project participants: >>
NEG Micon (I) Private Limited is the primary coordinator of the
project and the other promoters are individual entities whose WEGs
are part of the project activity. NEG Micon (I) Private Limited
acts as a facilitator for the project activity and has entered into
contractual agreements with other promoters to carry out the CDM
project activity on their behalf. NEG Micon (I) Private Limited a
100% subsidiary of NEG Micon A/S Denmark having a market share of
28% globally, has installed about 700 WEGs across the country
adding about 500 MW to the National grid. NEG Micon (I) Private
Limited shall be the single point contact for all communications
with the CDM Executive Board and the National CDM Authority. NEG
Micon (I) Private Limited shall act as a coordinator for providing
all relevant information during this exercise. Information
regarding the sharing of CERs shall be provided as and when need
arises. Thus for all practical purposes NEG Micon (I) Private
Limited is the project promoter.
CDM-SSC-PDD (version 02) CDM Executive Boardpage 4
Name of Party involved
Private and / or Public entity Project Participants NEG Micon
(I) Private Limited
Kindly indicate if the Party involved wishes to be considered as
Project Participant No
Government of India (Host Country)
There are eleven individual Project participants from various
industries who have set up wind turbines and are bundled in this
Project. The Names of the project promoters, Capacity of the WEGs,
Commissioning Date of the WEGs, Location and the High Tension
Service Connection number (a unique number to identify the WEGs
across the state) for the WEGs are as listed below for your
reference. Sl. No 1 2 3 4 5 6 7 8 9 10 11 Date of Commissioning
29.09.2004 26.02.2005 07.01.2005 25.01.2005 26.03.2005 22.03.2005
21.03.2005 30.03.2004 12.08.2005 12.08.2005 06.01.2005 06.01.2005
06.01.2005 26.03.2005 12.08.2005 17.08.2005 H.T. S.C. No. 956 1122
1059 1064 1202 1161 1160 773 1357 1358 1056 1057 1058 1199 1361
1363
Companies Nelsun Paper Ganga Mills Thiruvettai Ayyanar VMD Mills
A.P. Dhandapani Sudamani Morvi Exports Naga Aurofood Aurofood KP
Textiles KP Textiles KP Textiles Gangai Garments SKM Animal Feed
SKM Animal Feed
Capacity of WEGs 0.750 0.750 0.750 0.750 0.750 0.750 0.750 0.750
0.750 0.750 0.750 0.750 0.750 0.750 0.750 0.750
Location Tenkasi Tenkasi Tenkasi Tenkasi Tenkasi Surandai
Surandai Ayikudi Surandai Surandai Tenkasi Tenkasi Tenkasi Tenkasi
Tenkasi Tenkasi
A.4. Technical description of the small-scale project activity:
>> The project involves the installation of 750 kW Wind
Electric Generators of NEG Micon. The WEGs are ideal for Indian
meteorological conditions. The NM 48/750 kW WEG with a rated output
of 750 kW is one of the machines well known for its best
performance. The NM 48/750 kW WEG is a stall regulated machine with
a cut-in speed of 4 m/s and a cut-out speed of 25 m/s. The NM
48/750 kW machine is type tested and certified by DNV, Denmark A/S.
The technical design of the WEGs is from NEG Micon A/S, Denmark
where a dedicated team of professionals are actively involved in
design and testing. NEG Micon (I) Private Limited has been
effective in technology transfer. NEG Micon (I) Private Limited has
setup manufacturing plants in Chennai and Pondicherry. The
technical specifications of the WEGs are as mentioned in Table
1.
CDM-SSC-PDD (version 02) CDM Executive Boardpage 5
ParametersSl No 1
NM 48/750Sl No 5 750 KW Stall 4 m/s 25 m/s 48.2 m 1824 cm 3 nos.
7 Hydraulic, fail safe Hydraulic 8 Planetary - parallel axle 1:67.5
- 50Hz High quality forged shaft Spherical roller bearing2
Parameters Generator Type Nominal Voltage Nominal Frequency Name
Plate Rating Cooling Yaw Type Drive Mechanism Tower Type Hub Height
Controller Type Capacitor Bank
NM 48/750Asynchronous 690 V 50 Hz 750/200 KW Closed circuit
liquid cooling Ball Bearing 4 electrical planetary gears Conical,
Steel, PU Painted According to type approvals Computer controlling
NO LOAD Compensated
2
3
4
Operational Data Nominal Output Power Regulation Cut-In Speed
Cut-Out Speed Rotor Rotor Diameter Rotor Swept Area Number of
Blades Brake System Blade tip Air Brake Disc Brake Drive Train Gear
type Ratio Main Shaft Main Bearing Cooling
6
Closed circiut liquid cooling (Table 1: Technical Specifications
of NM 48/750 kW WEG)
A.4.1. Location of the small-scale project activity: >>
India A.4.1.1. Host Party(ies): >> Government of India
A.4.1.2. Region/State/Province etc.: >> Tamilnadu A.4.1.3.
City/Town/Community etc: >> Tenkasi A.4.1.4. Detail of
physical location, including information allowing the unique
identification of this small-scale project activity(ies): >>
The project site falls within latitudes N 88o 40 and N 98o 12 and
longitudes E 77o 08 and E 77o 58, Figure 1 shows a map of the
project site. The location where the project activity has been
carried out is uncultivable barren and wasteland. The nearest town
Tenkasi is about 15 km away from the project site. The unique
identification of the project is the High Tension Service
Connection Number (H.T.S.C. No.) of the turbines in the project
bundle.
CDM-SSC-PDD (version 02) CDM Executive Boardpage 6
Tenkasi Wind Farm
(Figure 1: Location map of the 12 MW Bundled Wind Power Project
in Tenkasi)
A.4.2. Type and category and technology of the small-scale
project activity: >> Since, the capacity of the proposed
project is only 12 MW, which is less than the maximum qualifying
capacity of 15MW, the project activity has been considered as a
small scale CDM project activity and UNFCCC indicative simplified
modalities and procedures are applied. The project activity
utilizes the wind potential for power generation and exports the
generated electricity to the grid. According to small-scale CDM
modalities the project activity falls under: Scope 1 : Energy
Industries (renewable/non-renewable sources) Type 1 : Renewable
Energy Projects Category I D : Renewable Electricity Generation for
a grid A.4.3. Brief explanation of how the anthropogenic emissions
of anthropogenic greenhouse gas (GHGs) by sources are to be reduced
by the proposed small-scale project activity, including why the
emission reductions would not occur in the absence of the proposed
small-scale project activity, taking into account national and/or
sectoral policies and circumstances: >> A thorough analysis
of the power sector in Southern Region grid of India is essential
to understand the greenhouse gas emission reductions achievable
from the project activity. The registered peak demand of the
Southern Regional grid during 2004 - 2005 was 22364 MW indicating
an increase of 1.99 % over the previous year. The unrestricted
maximum demand was 22717 MW, the overall capacity shortage in the
region was of the order of 0.62 % to 6.43 % during the year
2004-05. The maximum monthly capacity shortages were of the order
of 0.12 % to 5.08 % in Andhra Pradesh, 0.25 % to 13.26 % in
Karnataka, 4.64 % to 4.90 % in Kerala and 0.4 % to 2.74 % in
Tamilnadu.
CDM-SSC-PDD (version 02) CDM Executive Boardpage 7
The installed capacity of Southern Region at the end of
financial year 2004-05 was 31876.15 MW. The total installed
capacity comprises Hydro- 10707.47 MW (33.59 %), Thermal+ Gas+
Diesel- 17662.19 MW (55.41 %), Nuclear- 830 MW (2.60 %) and Wind+
R.E.S- 2676.49 MW (8.40 %). There was an increase of 6.58 % in the
installed capacity over the previous year through addition of
1969.23 MW in Southern Region. The Hydro Thermal ratio was 38:62 as
on 31.03.2005. (Source: CEA Southern Regional Electricity Board
Bangalore. Annual Report 2004-05). As it can be observed, the
project activity has contributed an additional sustainable clean
generation source to the regional grid thereby reducing the
dependency on fossil fuel by a small but significant extent. As on
date there has been no regulation either from the State Government
or Central Government on the generation sources. No policy from the
Governments mandates the promotion or implementation of renewable
energy projects. Still the activity has been carried out by the
project entities. The project will generate electricity from WEGs
in the State of Tamilnadu. The project activity has been
essentially conceived for selling the generated output to the state
electricity utility. Hence the wind power generated from the
project site will be replacing the electricity generated from
thermal power stations feeding into regional grid (during power
surplus time). Since wind power is free from GHG emissions, the
power generated will save the anthropogenic green house gas (GHG)
emissions that would have been generated by the fossil fuel based
thermal power stations comprising coal, diesel, furnace oil and
gas. The estimation of GHG reductions by this project is limited to
carbon-dioxide only. A.4.3.1 Estimated amount of emission
reductions over the chosen crediting period: >> The project
activity is expected to reduce 22552.2 tonnes of CO2 annually.
Projections have been made assuming that the project will get
registered in the year 2007. Years 2007 2008 2009 2010 2011 2012
2013 2014 2015 2016 Total Estimated Emission Reductions (tonnes of
CO2e) Total Number of crediting years Annual Average over the
crediting period of estimated reductions (tonnes of CO2e) Annual
Estimate of emission reductions in tonnes of CO2 e 22552.2 22552.2
22552.2 22552.2 22552.2 22552.2 22552.2 22552.2 22552.2 22552.2
225522 10 years 22552.2
A.4.4. Public funding of the small-scale project activity:
>> There is no public funding involved in this project
activity.
CDM-SSC-PDD (version 02) CDM Executive Boardpage 8
A.4.5. Confirmation that the small-scale project activity is not
a debundled component of a larger project activity: >>
According to paragraph 2 of Appendix C to the Simplified Modalities
and Procedures for SmallScale CDM project activities
(FCCC/CP/2002/7/Add.3), a small-scale project is considered a
debundled component of a large project activity if there is a
registered small-scale activity or an application to register
another small-scale activity: With the same project participants In
the same project category and technology; and Registered within the
previous two years; and Whose project boundary is within 1km of the
project boundary of the proposed small scale activity None of the
above applies to 12 MW Bundled Wind Power Project at Tenkasi and
the project participants have not registered or applied for
registration of another small scale wind project. Therefore the
proposed project is not a debundled component of a larger CDM
project activity. SECTION B. Application of a baseline methodology:
B.1. Title and reference of the approved baseline methodology
applied to the small-scale project activity: >> The
methodology followed will be Renewable electricity generation for a
grid - AMS 1 D. Version 9 Scope 1 (28 July 2006) B.2 Project
category applicable to the small-scale project activity: >>
Technology/measure (As per Renewable electricity generation for a
grid - AMS 1.D Version 9 Scope 1) 1. This category comprises
renewable energy generation units, such as photovoltaics, hydro,
tidal/wave, wind, geothermal, and renewable biomass, that supply
electricity to and/or displace electricity from an electricity
distribution system that is or would have been supplied by at least
one fossil fuel fired generating unit. 2. If the unit added has
both renewable and non-renewable components (e.g. a wind/diesel
unit), the eligibility limit of 15MW for a small-scale CDM project
activity applies only to the renewable component. If the unit added
co-fires fossil fuel, the capacity of the entire unit shall not
exceed the limit of 15MW. 3. Biomass combined heat and power
(co-generation) systems that supply electricity to and/or displace
electricity from a grid are included in this category. To qualify
under this category, the sum of all forms of energy output shall
not exceed 45 MW thermal. E.g., for a biomass based cogenerating
system the rating for all the boilers combined shall not exceed 45
MW thermal. 4. Project activities adding renewable energy capacity
should consider the following cases: a. Adding new units; b.
Replacing old units for more efficient units. To qualify as a small
scale CDM project activity, the aggregate installed capacity after
adding the new units (case a.) or of the more efficient units (case
b.) should be lower than 15 MW.
CDM-SSC-PDD (version 02) CDM Executive Boardpage 9
5. Project activities that seek to retrofit or modify an
existing facility for renewable energy generation are included in
this category. To qualify as a small scale project, the total
output of the modified or retrofitted unit shall not exceed the
limit of 15 MW. This project activity qualifies as per Section 1,
which includes renewable energy generation units, such as Wind.
B.3. Description of how the anthropogenic emissions of GHG by
sources are reduced below those that would have occurred in the
absence of the registered small-scale CDM project activity:
>> The additionality of the 12MW bundled Wind Power Project
in Tenkasi is established primarily on the basis of a detailed
Investment Analysis along with a more in-depth discussion on
barrier analysis, relating to the Project itself as well as within
the scope of the Southern Regional Grid. Investment Analysis For
the purpose of the investment analysis the prime financial
indicator that has been used is the IRR of the project activity.
The Internal Rate of Return of any investment activity is one of
the most commonly used tools to establish the viability and the
financial feasibility of the project. The benchmark Internal Rate
of Return (Equity IRR) of any project in the power sector in India
is around 16%. Taking all this into account the investment analysis
was carried out taking the following assumptions into
consideration. Assumptions for Investment Analysis Size of Project
No. of WEGs Capacity of each WEG Generation per WEG Plant Load
Factor Life of WEG Total project cost Wheeling charges O&M Cost
as an % of the total Project Cost Escalation on O&M cost
Insurance cost Interest on loan Buy-back rate Escalation on
buy-back Income tax rate MAT Accelerated Depreciation 12 MW 16
0.750 kW 1,884,375 units 28.6% 20 yrs INR. 488,152,000/5% 1.45%
7.19% 0.37% 8.25% Sale to Board INR 2.70/Captive INR 3.50/0% 36.6%
(Including Sur Charge) 7.85% 80%
Considering the above mentioned assumptions over a period of 20
years, without considering the CDM revenues the Project IRR is
12.00% and the Equity IRR is 13.88%. When the revenues from CDM are
considered the Project IRR improves to 13.37% and the Equity IRR to
16.17%. The project cash flow detailing the calculation and
assumptions are approved by an external auditor and are submitted
for the reference of the DOE and is attached in Appendix 2.
CDM-SSC-PDD (version 02) CDM Executive Boardpage 10
Barriers and additionality In this case, we establish that
significant barriers exist and would have prevented the Project
from being undertaken or completed and also establish that the CDM
activity would act as an impetus for this Project to survive. The
primary relevant barriers to the project activity are: 1.
Investment barriers 1. Lowering of tax benefits and the
introduction of the Minimum Alternate Tax (MAT) 2. Reduction in tax
concessions enacted by the Union Government led to corresponding
reduction in tax benefits to investors to put in wind farms 3.
Disproportionate hike in interest rates subsequently imposed by
IREDA for loans to set up wind farms 4. Applying wind-speed data
from limited number of anemometer resulted in wide variation from
predicted wind turbine generation and actual generation creating
doubts about the viability of wind projects The financial indicator
is the Equity IRR. The IRR has been computed for the entire
lifetime of the project activity. 2. Technological barriers The
non-availability of cost-effective, commercially viable technology
for utilisation of wind energy constitutes one of the major
barriers to the project activity. Moreover the project activity
comprises of installation of NM 48 class of WEGs which has over 60%
of the components imported making the technology barrier more
relevant for this project activity. 3. Institutional and Regulatory
Barriers The main institutional and regulatory barriers faced by
the Project activity are listed below: 1. Delay in sanctioning by
the SEBs and other State agencies 2. Unplanned addition of wind
farms at sites like Muppandal, Kayathar, Poolavadi, etc., which
resulted in inadequate capacity at dedicated substations resulted
in shutting down of wind turbines even during peak wind speed
periods with loss of generation and hence revenue loss to the Wind
farm owners. 3. Connecting WEGs to weak and rural feeder lines in
the absence of dedicated substations at some wind farm sites, poor
grid, poor generation and loss of revenue 4. TNEB imposing
penalties for excess Reactive Power (RkVAh) consumption 5. Absence
of third party sale coupled with uncertainty about the tariff
structure, inconsistent contractual agreements like the PPA and
their enforceability. 6. Inadequate power evacuation facilities by
SEBs in many areas, along with inadequate capacity of substations
4. Tariff Barriers The Ministry of Non-conventional Energy Sources,
Government of India had issued guidelines for power purchase tariff
to be Rs.2.25 per kWh with 5 % escalation every year for all
renewable energy to promote generation of renewable clean energy in
the year 1996. TNEB followed the same guidelines until the year
2001. In 2001, however TNEB changed its policy and froze the power
purchase tariff for wind energy at Rs.2.70 per kWh with no
escalation till 2006 and had informed that this power purchase
tariff will be reviewed at 2006 and a new tariff will be fixed
then. This figure was arrived by escalating the base tariff of
Rs.2.25 by 5% over a term of 5 years from 1996 2001. The price
being paid for wind energy is one of the lowest in the country at
Rs.2.70 with no escalation. This is much lower than what
CDM-SSC-PDD (version 02) CDM Executive Boardpage 11
some of the other States are paying for wind power. The tariff
has only changed marginally over the last couple of years and third
party sale is also not permitted in the state of Tamilnadu. Whereas
the power purchase tariff from Industrial Waste/Municipal Waste
based generation is at Rs.3.49 in the year 2005 against wind power
being paid just Rs.2.70. 5. Transaction barriers Transaction
barriers to wind energy are similar in many ways to those in
developed and developing countries. In India many of the sources of
risk, institutional structures and conditions, experience and
skills deficiencies are unique. The result is greater uncertainty
in transactions about opportunities, costs and benefits. Impact of
CDM registration Registering the project activity as a CDM project
expected after approval and registration, would provide additional
revenue to the project activity improving the cash flows. The
financial viability of the project activity would improve with CER
revenues. The CDM revenues will assist the investor in realizing
returns commensurate the risks in development and operations of the
project. In addition to the investment barriers already faced, the
project proponent is also bearing the additional transaction costs
for CDM project by taking a pro-active approach in showing
confidence in the Kyoto Protocol/CDM mechanism. B.4. Description of
how the definition of the project boundary related to the baseline
methodology selected is applied to the small-scale project
activity: >> The project boundary is defined as the notional
margin around a project within which the projects impact (in terms
of GHG reduction) will be assessed. According to ACM0002/Version
06/Sectoral Scope (19 May 2006) the spatial extent of this project
activity includes the project site and all the power plants
connected physically to the electricity system that the CDM power
project is connected to. Thus, it is essentially the zone
encompassing the WEG installations to the nearest grid
interconnection point. There are three choices available for
choosing the grid system for the project activity, viz. national
grid, regional grid or state grid. Since the CDM project would be
supplying electricity to the southern regional grid it is
preferable to take the regional grid as project boundary than the
state boundary. It also minimizes the effect of inter state power
transactions, which are dynamic and vary widely. Considering free
flow of electricity among the member states and the union territory
through the Southern Region Load Dispatch Centre (SRLDC), the
entire southern grid is considered as a single entity for
estimation of baseline. B.5. Details of the baseline and its
development: >> According to paragraph 9 of the AMS 1.D.
Version 9 Scope 1 (28 July 2006) the baseline is the kWh produced
by the renewable generating unit multiplied by an emission
coefficient (measured in kg CO2equ/kWh) calculated in a transparent
and conservative manner as: a. A combined margin (CM), consisting
of the combination of operating margin (OM) and build margin (BM)
according to the procedures prescribed in the approved methodology
ACM0002. Any of the four procedures to calculate the operating
margin can be chosen, but the restrictions to use the Simple OM and
the Average OM calculations must be considered OR
CDM-SSC-PDD (version 02) CDM Executive Boardpage 12
b. The weighted average emissions (in kg CO2equ/kWh) of the
current generation mix. The data of the year in which project
generation occurs must be used. Step (a.) was followed to arrive at
the emission factor. The formulae that have been used in the
calculations are presented in Section E.1. Data required for the
calculations were collected from appropriate sources, a sample of
which is presented below. COEF i, j for various fuels used in the
State was calculated using appropriate values of NCVi, EF and OXIDi
specified by IPCC Guidelines for National Greenhouse Gas
Inventories: Reference Manual, Revised 1996.CO2i
Fuel consumption data and Generation details for all the sources
were collected and used to arrive at the Baseline emission factor.
The various values obtained are tabulated as below. Calculation of
Combined Margin Emission FactorParameter Gross Generation Total (In
GWh) Net Generation Total (In GWh) 20% of Net Generation (In GWh)
Absolute Emissions Total (tCO2) Absolute Emissions OM (tCO2)
Absolute Emissions BM (tCO2) Simple Operating Margin (tCO2/ MWh)
Build Margin (tCO2/ MWh) Combined margin incl. Imports (tCO2/ MWh)
2000-01 128,796 120,964 24,193 2001-02 131,747 123,468 24,694
2002-03 136,742 127,617 25,523 2003-04 138,153 128,032 25,606
2004-05 143,932 134,551 26,910
87,815,363
91,590,959
103,269,937
107,406,076
104,917,425
87,815,363
91,590,959
103,269,937
107,406,076
104,917,425
19,332,594
1.02
1.00
0.99
1.00
1.00
0.71
0.86
0.85
0.85
0.86
0.85
The data is obtained from CO2 Baseline Database for the Indian
Power Sector (User Guide Draft V1.0 dated 4 Oct 2006) which was
designed especially for the purpose of baseline calculation. The
various plants and the assumptions considered in the calculation
are given in the link
http://www.cea.nic.in/planning/c%20and%20e/CO2%20Database.zip.
However the list of plants considered for baseline study is
tabulated in Appendix 1.
CDM-SSC-PDD (version 02) CDM Executive Boardpage 13
SECTION C. Duration of the project activity / Crediting period:
C.1. Duration of the small-scale project activity: >> 10
years C.1.1. Starting date of the small-scale project activity:
>> 30/03/2004 (DD/MM/YYYY) commissioning date of first WEG in
the bundle C.1.2. Expected operational lifetime of the small-scale
project activity: >> 20 years C.2. Choice of crediting period
and related information: >> C.2.1. Renewable crediting
period: >> C.2.1.1. Starting date of the first crediting
period: >> C.2.1.2. Length of the first crediting period:
>> C.2.2. Fixed crediting period: >> C.2.2.1. Starting
date: >> 18/01/2007 (DD/MM/YYYY) C.2.2.2. Length: >> 10
years SECTION D. Application of a monitoring methodology and plan:
D.1. Name and reference of approved monitoring methodology applied
to the small-scale project activity: >> Renewable electricity
generation for a grid AMS 1.D. Version 9 Scope 1 (28 July 2006)
D.2. Justification of the choice of the methodology and why it is
applicable to the small-scale project activity: >>
The project activity meets the eligibility criteria to use
simplified modalities and procedure for small-scale CDM project
activities as set out in paragraph 6 (c) of decision 17/CP.7.
CDM-SSC-PDD (version 02) CDM Executive Boardpage 14
D.3 >>ID No. Data type
Data to be monitored:Data variable Data unit Measured (m),
calculated (c) or estimated (e) Recording frequency Proportion of
data to be monitored How will the data be archived? (electronic/
paper) For how long is archived data to be kept? Comment
1
Electricity supplied to the regional electricity grid
Electricity
kWh
M
Monthly
100%
Electronic & Paper
Two years beyond Crediting period
Electricity generated from each WEG is individually
measured.
D.4. Qualitative explanation of are undertaken: >> ID
Uncertainty level of number data (High/Medium/Low) 1 Low
how quality control (QC) and quality assurance (QA)
procedures
Explain QA/QC procedures planned for these data, or why such
procedures are not necessary. The data can be very accurately
measured. The meters installed on sub stations (grid
interconnection point) will be used to measure mentioned variables
on a continuous basis. Every month these meter readings will be
recorded by plant personnel, these records will be archived for
crosschecking yearly figures. The meters at the sub station will be
two-way meters and will be in custody of SEB (TNEB). SEB will take
the readings in these meters and the same reading may be used to
determine the net power wheeled to the grid and determine the
extent of mitigation of GHG over a period of time.
D.5. Please describe briefly the operational and management
structure that the project participant(s) will implement in order
to monitor emission reductions and any leakage effects generated by
the project activity: >> NEG Micon (I) Private Limited has
certifications from ISO on Quality Management Systems,
Environmental Management Systems and Occupational Health and
Safety. NEG Micon (I) Private Limited follows standard documented
best practices at all stage of its activities, from project
identification to wind resource assessment, marketing to
commissioning and during the entire lifetime of the WEGs within the
operation and maintenance period. Each project executed by NEG
Micon (I) Private Limited involves an Operations and Maintenance
Agreement that is signed with the project promoter. NEG Micon (I)
Private Ltd also has adequate and technically qualified site
managers to ensure constant monitoring of wind turbines installed.
In addition, NEG Micon (I) Private Ltd has prepared a CDM Manual
that will facilitate easy monitoring of the project activity. The
annual electricity generation from these turbines can be accessed
from www.power2customer.com
CDM-SSC-PDD (version 02) CDM Executive Boardpage 15
D.6. Name of person/entity determining the monitoring
methodology: >> Carbon Advisory Services of NEG Micon (I)
Private Limited. The contact information is provided in Annex 1.
SECTION E.: Estimation of GHG emissions by sources: E.1. Formulae
used: >> Appendix B of the Simplified modalities and
procedures for small scale CDM projects activities recommends the
use of the average of the approximate operating margin and the
combined margin, calculated in a transparent and conservative
manner, in estimating the emission coefficient. The baseline is the
kWh produced by the renewable generating unit multiplied by the
emission coefficient( measured in kg CO2eq / kWh). The operating
margin emission factor is calculated as: i,j Fi,j,y . COEF i, j EF
OM,, y = -------------------------- Gen j, y The build margin
emission factor is calculated as: i,j Fi,j,y . COEF i, j EF BM, y =
--------------------------- Gen j, y Average emission factor is
calculated as: (EFOM,y + EFBM,y) EFy = --------------------2 E.1.1
Selected formulae as provided in appendix B: >> No formula is
provided in Appendix B for these types of projects. E.1.2
Description of formulae when not provided in appendix B: >> F
i, j, y is the amount of fuel i consumed by relevant power sources
j in year(s) y, j refers to the power sources delivering
electricity to the grid, COEF i, j y is the CO2 emission
coefficient of fuel i (tCO2 / mass or volume unit of the fuel),
taking into account the carbon content of the fuels used by
relevant power sources j and the percent oxidation of the fuel in
year(s) y, and GEN j, y is the electricity (MWh) delivered to the
grid by source j. The CO2 emission coefficient COEF i is obtained
as COEF i = NCVi EFCO2,i OXIDi Where, NCV i OXID i EF CO2, i EFOM,y
is the net calorific value (energy content) per mass or volume unit
of a fuel i, is the oxidation factor of the fuel (see page 1.29 in
the 1996 Revised IPCC Guidelines for default values) is the CO2
emission factor per unit of energy of the fuel i. is the operating
margin emission factor
CDM-SSC-PDD (version 02) CDM Executive Boardpage 16
EFBM,y EFy
is the build margin emission factor is the average baseline
emission factor
E.1.2.1 Describe the formulae used to estimate anthropogenic
emissions by sources of GHGs due to the project activity within the
project boundary: >> The project activity is a wind based
power generation project with no emissions. Hence there is no
relevance to this section. E.1.2.2 Describe the formulae used to
estimate leakage due to the project activity, where required, for
the applicable project category in appendix B of the simplified
modalities and procedures for small-scale CDM project activities
>> The project activity is a wind based power generation
project with no emissions. Hence there is no relevance to this
section. E.1.2.3 The sum of E.1.2.1 and E.1.2.2 represents the
small-scale project activity emissions: >> The project
activity emissions are zero. E.1.2.4 Describe the formulae used to
estimate the anthropogenic emissions by sources of GHGs in the
baseline using the baseline methodology for the applicable project
category in appendix B of the simplified modalities and procedures
for small-scale CDM project activities: >> BEy = EGy EFy
Where, EFy is the baseline emission factor for the year y EGy is
the electricity generation for the year y E.1.2.5 Difference
between E.1.2.4 and E.1.2.3 represents the emission reductions due
to the project activity during a given period: >> 225522
tonnes of CO2e for the ten years crediting period. E.2 Table
providing values obtained when applying formulae above: >>
Year Estimation of Estimation of baseline Estimation Estimation of
project activity activity emission of leakage emission reductions
emissions ( tCO2e) reductions ( tCO2e) ( tCO2e) ( tCO2e) 2007 0
22552.2 0 22552.2 2008 0 22552.2 0 22552.2 2009 0 22552.2 0 22552.2
2010 0 22552.2 0 22552.2 2011 0 22552.2 0 22552.2 2012 0 22552.2 0
22552.2 2013 0 22552.2 0 22552.2 2014 0 22552.2 0 22552.2 2015 0
22552.2 0 22552.2 2016 0 22552.2 0 22552.2 Total tonnes of CO2e 0
225522 0 225522
CDM-SSC-PDD (version 02) CDM Executive Boardpage 17
SECTION F.: Environmental impacts: F.1. If required by the host
Party, documentation on the analysis of the environmental impacts
of the project activity: >> Wind power is one of the cleanest
sources of renewable energy, with no associated emissions and waste
products. In India, wind power projects do not require an
Environmental Impact Assessment; however some of the significant
impacts are discussed below: Land use Extremely stringent measures
are taken to ensure that the land available for wind farm
development has no alternative use. The land for the Tenkasi Wind
Project was barren land which could not be used for any
agricultural cultivation. Furthermore, no forest land was used for
the purpose. Noise pollution Most of the wind turbines are in
isolated areas or on designated wind zones and hence do not cause
residents of the area any concern. In the same vein, construction
activities so far also have not caused noise pollution due to the
isolated nature of the area and actually only has a positive impact
of producing employment for the village people in nearby areas.
Water pollution No water bodies exist in the area of the Project
and hence there was no contamination destruction of water bodies
during and after the construction activities. Flora and fauna As
mentioned above, the land used for the purpose was barren land and
no flora was destroyed for the setting up of the project. The only
vegetation in the area of the project was shrubs and weeds, which
grow abundantly. Further, many wind farm investors are actually
using the land around the wind machines to grow aloe vera and other
xerophytes that require little or no water. This is proving to have
a good environmental impact on the area. Bird hit in these areas is
not a common phenomenon. The Tenkasi Wind Project is not in the
path of migratory birds. Local birds are accustomed to the wind
structures and fly at a lower level near areas of dense vegetation.
There have been no serious incidents involving birds and wind
turbines in the area to the best of our knowledge. Visual impact As
gathered in the stakeholder analysis, the presence of the wind
farms does not have a negative impact on the surrounding villagers
in terms of visual impact. The majority of the persons spoken to
were least concerned of the wind farms in the area. Air pollution
Minimal air pollution might have occurred during the construction
of the Project due to transportation. However, these were not found
to affect the surrounding persons nor the environment in a very
drastic manner.
CDM-SSC-PDD (version 02) CDM Executive Boardpage 18
Social Impacts The social impacts of the Project were more
positive than negative. The Project did not displace any people nor
interfere in their daily life. It provided employment for the first
6 months prior to installation and then for a lesser number of
people on a day to day basis. The Project has also had positive
impacts since infrastructure like roads and communication was
developed in the area. SECTION G. Stakeholders comments: G.1. Brief
description of how comments by local stakeholders have been invited
and compiled: >> The WEG installation and development of wind
farm does not require any EIA (Environmental Impact Assessment).
Additionally the installations carried out under the proposed
project activity are away from human habitation, and the land used
for installations of WEG is of no use (barren land). The villages
in the near vicinity were contacted before the implementation of
the proposed project activity, and were appraised about the
execution of wind farm project. The local stakeholders raised no
issues, thus no action was required. The land used for
installations has been kept without any fencing and thus no
right-ofway/current usage (what so ever) has been disturbed. The
villagers are free to move around and make use of the land (if it
can come to any use). G.2. Summary of the comments received:
>> A survey was conducted in the area of the Tenkasi Wind
Project in Tamilnadu. A subsequent analysis was undertaken as a
part of Validation as per the DOEs request. PHASE 1 Primary data
was collected through questionnaires and focus group discussions.
Responses were tabulated on a Likert scale and then coded and
classified to arrive at the final analysis. The stakeholders were
predominantly male and adult. It was observed that almost 95% were
strongly in favour of the Project. The rest 5% were concerned about
certain rumors they had heard about wind mills which is addressed
below. Questions were made simple and easy to understand. A number
of pictures and graphics were also taken as part of the interview
to make the respondents understand better. The orientation and
questionnaire addressed the following: 1. 2. 3. 4. 5. 6. 7. 8. 9.
Project introduction Reasons for setting up the Project Costs and
benefits of setting up the Project How did they think it would
affect them? Do they perceive that the Project will have negative
or positive impacts on their livelihood? Are they bothered about
the noise pollution? Have there been any difficulties faced during
construction? What are some of the other issues that concern them?
Do they have any other suggestions or queries?
The survey had a 90% response rate. The reason for this high
response rate was the fact that the local Panchayat was involved in
mobilizing people for this survey. The respondents felt confident
that the local municipal body was involved.
CDM-SSC-PDD (version 02) CDM Executive Boardpage 19
1. 2. 3. 4. 5.
Most respondents were farmers with no education at all. 80% of
the respondents felt that the Project did not have any negative
impacts on their livelihood. Almost 88% felt that the Project
actually benefited them through employment 100% of respondents
agreed with the development of the Project The main issue that
concerned them was a perception that wind mills moved away rain
clouds (almost 82.7%) and women in the group were concerned that
the windmills were creating a lot of heat which depleted the
groundwater sources. This concern was understandable since it is
invariably women who travel long distances to fetch water. Further
around 10% of the respondent group were concerned about blades
falling. 6. No additional comments were received.
Conclusion It can be concluded that there was no opposition to
the setting up of the Project. In summary: (1) The issues discussed
were well understood and the local stakeholders did not have any
issues with the Project being in the area. They well understood the
fact that it would not interfere with their village and community.
(2) However some perceptions were interesting to note. The
villagers felt that the presence of the wind turbines moved away
rain clouds and that was the reason the monsoons were not bringing
in any rain to the area and causing crop failure. Further, they had
heard that wind mills increased the heat in the neighboring areas.
Both these false perceptions were explained in detail by us,
especially the fact the clouds are much higher than the height of
the wind mill and it is highly unlikely that it would cause the
problem. Further the case was made stronger by cross checking this
information with the Indian Institute of Tropical Meteorology and
the Center for Wind Energy Technology. The women in the group who
traversed long distances to fetch water for daily activities were
concerned that the wind mills created a lot of heat and were
depleting groundwater sources. All these perceptions were explained
and the respondent group was convinced. (3) Falling blades although
not witnessed, but heard of was another concern. We explained that
this is very unlikely and since the windmills are located far from
the community and houses it would not affect them directly.
However, their concerns were noted. There were no specific negative
comments. There were some apprehensions based on misconceptions
rather than actual facts but were cleared. Since there were no
negative comments, there were no changes to Project activity. Thus
no serious concerns or issues were raised regarding the Project.
PHASE 2 To re-ascertain the views of local public about setting up
of WEGs in their localities another stake holders analysis was
conducted during the validation of this project on the 20th of
February at the Wind Farms in the Tenkasi district of Tamilnadu,
Southern India. The meet with the stake holders saw a good
gathering of people who were residents of Ayakudi, Surandai,
Keelveeranam, Veeranam, Pattakurichi and Sambavarvadakkarai. There
was an active participation from both male as well as female. A
flyer stating that an analysis of this kind will be carried out at
the site on the aforesaid date was circulated by the service site
people well in advance, so that they could make it convenient to
attend the meet.
CDM-SSC-PDD (version 02) CDM Executive Boardpage 20
A questionnaire was circulated and the contents of the same were
explained as most of them who had attended were illiterate. All the
people who had attended the meet were happy about people setting up
wind mills in their villages, as most of the farmers who had
suffered due to bad harvest are happy that now they have sold out
their lands for good prices to the people setting up the wind
mills. Moreover in most of the cases they have also been provided
with employment opportunities. For example: few of the old farmers
are now working as watchmen in the wind farm site and people are
also being employed to paint the tower structures. Also young
people with the minimum qualification have been trained and
absorbed as operators for the turbines. This has clearly led to an
increase in awareness among the people residing around the area.
People who attended the meet said there is a drastic change in
their lifestyle post setting up of wind turbines in their locality.
Apart from the convenience in communication a lot of shops have
also come up in the area which caters to their daily needs. A few
of the advantages stated by the people are listed below Fewer or no
Power Shutdowns Increased employment opportunities Improvement in
the standard of living Improved roads and hence better
communication facilities The following is a summary of the major
questions addressed in the questionnaire and the response from the
stakeholders: Questionnaire Stakeholders Responses Has the
installation of the windmills The stakeholders did not identify any
significant demerits of marked any positive / negative impact wind
mill installations. However two major positive effects on the
livelihood of the local people? identified were: Improvement in the
roads and other communication in that area Employment opportunities
for the local population Have the local people felt any problem
There is no noise nuisance as windmills are on hilltops and are due
to the noise from the windmills? far away from the villages. Has
there been any water related The local people did not identify any
scarcity or other problems problem due to the windmills? regarding
water availability due to the windmills. However, it was mentioned
that there was a riot somewhere in Maharashtra due to lack of rains
three years back, but nothing of that sort had happened here. What
were the major issues that The stakeholders admit that there had
been a few concern the local people? misconceptions initially
regarding the consequences of setting up windmills. But they are
now quite aware and have realized that there are no significant
disadvantages due to the same. A few of those issues were: Moving
rain clouds due to the windmills Too much heat generated from the
windmills
CDM-SSC-PDD (version 02) CDM Executive Boardpage 21
G.3. Report on how due account was taken of any comments
received: >> The issues discussed were well understood and
the local stakeholders did not have any issues with the Project
being in the area. They well understood the fact that it would not
interfere with their village and community. However some of the
earlier perceptions (Phase I) were interesting to note. The
villagers felt that the presence of the wind turbines moved away
rain clouds that might cause a disruption of the monsoon season.
Further, they had heard that wind mills increased the heat in the
neighboring areas. Both these false perceptions were explained in
detail by us, especially the fact that the clouds are at a much
higher altitude than the height of the wind mill and it is highly
unlikely that it would cause the problem. Further, information from
the Center for Wind Energy Technology based in Chennai also
conveyed the same. They also wanted to know why the Project could
not directly supply their village instead of having to depend on
the grid. Some of the villagers from a neighboring village which
was off the grid were also keen on this issue. It had to be
explained that wind mills supply much more power than what can be
used by the villagers for their domestic use, which would result in
considerable power wastage, Furthermore, the buy back rates for
wind power in the State is at Rs.2.70 without any escalation, which
would be unaffordable for the villagers who are receiving power at
subsidized rates. Once the wind power is fed into the grid, it is
impossible to distinguish which is wind power and hence would make
no difference apart from the fact that they would be dependent on
the grid again. The concept of transmission and distribution of
electricity was explained to them to help them understand how and
why it would not be suitable for the villagers to utilize the power
from WEGs for their daily domestic consumptions.
CDM-SSC-PDD (version 02) CDM Executive Boardpage 22
Annex 1 CONTACT INFORMATION ON PARTICIPANTS IN THE PROJECT
ACTIVITY Organization: Street/P.O.Box: Building: City:
State/Region: Postfix/ZIP: Country: Telephone: FAX: E-Mail: URL:
Represented by: Title: Salutation: Last Name: Middle Name: First
Name: Department: Mobile: Direct FAX: Direct tel: Personal E-Mail:
NEG Micon (I) Private Limited 298, Old Mahabalipuram Road,
Sholinganallur, Chennai Tamil Nadu 600 119 India + 91 44 2450 5100
+ 91 44 2450 5101 www.neg-micon.com Carbon Advisory Services
+ 91 44 2450 5101 + 91 44 2450 5044
[email protected]
CDM-SSC-PDD (version 02) CDM Executive Boardpage 23
Annex 2 INFORMATION REGARDING PUBLIC FUNDING There is no public
funding involved in this project activity
CDM-SSC-PDD (version 02) CDM Executive Boardpage 24
Appendix 1 BASELINE INFORMATION Southern Region Electricity
Board GridS. NO Name Unit-no Capacity MW As on 31STMar 2005 Type
Fuel 2000-01 Net Generation GWh 2000-01 in Operating Margin 2001-02
Net Generatio n GWh 2001-02 in Operating Margin 2002-03 Net
Generation GWh 2002-03 in Operating Margin 2003-04 Net Generation
GWh 2003-04 in Operating Margin 2004-05 Net Generation GWh 2004-05
in Operating Margin 2004-05 in Build Margin
1 1 1 1 1 1 1 1 1 2 2 2 3 3 3 3 3 3 3 4 4
K_GUDEM K_GUDEM K_GUDEM K_GUDEM K_GUDEM K_GUDEM K_GUDEM K_GUDEM
K_GUDEM K_GUDEM NEW K_GUDEM NEW K_GUDEM NEW VIJAYWADA VIJAYWADA
VIJAYWADA VIJAYWADA VIJAYWADA VIJAYWADA VIJAYWADA R_GUNDEM - B
R_GUNDEM - B
0 1 2 3 4 5 6 7 8 0 1 2 0 1 2 3 4 5 6 0 1
680 60 60 60 60 110 110 110 110 500 250 250 1260 210 210 210 210
210 210 62.5 62.5
THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL
THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL
THERMAL THERMAL THERMAL THERMAL THERMAL
COAL COAL COAL COAL COAL COAL COAL COAL COAL COAL COAL COAL COAL
COAL COAL COAL COAL COAL COAL COAL COAL
3,482
1
3,769
1
4,210
1
3,833
1
4,919
1
3,466
1
3,535
1
3,734
1
3,689
1
3,770
1
9,317
1
9,346
1
9,382
1
9,247
1
8,926
1
405
1
387
1
352
1
431
1
449
1
CDM-SSC-PDD (version 02) CDM Executive Board5 5 5 6 6 6 6 6 6 7
7 7 7 7 7 7 7 8 8 8 9 9 9 9 9 10 10 10 10 10 11 11 11 11 RAYAL
SEEMA RAYAL SEEMA RAYAL SEEMA VIJESWARAN GT VIJESWARAN GT
VIJESWARAN GT VIJESWARAN GT VIJESWARAN GT VIJESWARAN GT R_GUNDEM
STPS R_GUNDEM STPS R_GUNDEM STPS R_GUNDEM STPS R_GUNDEM STPS
R_GUNDEM STPS R_GUNDEM STPS R_GUNDEM STPS SIMHADRI SIMHADRI
SIMHADRI JEGURUPADU GT JEGURUPADU GT JEGURUPADU GT JEGURUPADU GT
JEGURUPADU GT GODAVARI GT GODAVARI GT GODAVARI GT GODAVARI GT
GODAVARI GT KONDAPALLI GT KONDAPALLI GT KONDAPALLI GT KONDAPALLI GT
0 1 2 0 1 2 3 4 5 0 1 2 3 4 5 6 7 0 1 2 0 1 2 3 4 0 1 2 3 4 0 1 2 3
420 210 210 272.3 33 33 112.5 34 59.8 2600 200 200 200 500 500 500
500 1000 500 500 235.4 52.8 52.8 52.8 77 208 47 47 47 67 350 112
112 126 THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL
THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL
THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL
THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL
THERMAL THERMAL THERMAL COAL COAL COAL GAS GAS GAS GAS GAS GAS COAL
COAL COAL COAL COAL COAL COAL COAL COAL COAL COAL GAS GAS GAS GAS
GAS GAS GAS GAS GAS GAS GAS GAS GAS GAS 659 1 1,683 1 2,403 1 2,171
1 2,179 0 0 0 1 1 1 1 1,544 1 1,458 1 1,160 1 1,090 1 1,344 1 1,625
1 1,575 1 1,555 1 1,476 1 1 0 1 4,576 1 7,027 1 488 7,663 3,856
3,806 1,392 1 1 1 1 1 15,433 1 14,693 1 15,748 1 14,766 1 412
16,038 1 255 1,928 1 1,905 1 1,978 1 2,093 1 1,940 1 3,123
page 25
1
3,068
1
3,120
1
3,045
1
3,078
1
CDM-SSC-PDD (version 02) CDM Executive Boardpage 26
12 12 12 13
LVS POWER DG LVS POWER DG LVS POWER DG PEDDAPURAM CCGT
PEDDAPURAM CCGT RAICHUR RAICHUR RAICHUR RAICHUR RAICHUR RAICHUR
RAICHUR RAICHUR YELHANKA (DG) YELHANKA (DG) YELHANKA (DG) YELHANKA
(DG) YELHANKA (DG) YELHANKA (DG) YELHANKA (DG) KAIGA KAIGA KAIGA
TORANGALLU IMP TORANGALLU IMP TORANGALLU IMP BELLARY DG BELLARY DG
TANIR BAVI TANIR BAVI TANIR BAVI TANIR BAVI
0 1 2 0
36.8 18.4 18.4 220
THERMAL THERMAL THERMAL THERMAL
DISL DISL DISL GAS
0
1
90
1
2
1
0
1
0 0 0 1,142
1 1 1 1
1
1
908
1
1,248
1
13 14 14 14 14 14 14 14 14 15 15 15 15 15 15 15 16 16 16 17 17
17 18 18 19 19 19 19
1 0 1 2 3 4 5 6 7 0 1 2 3 4 5 6 0 1 2 0 1 2 0 1 0 1 2 3
220 1470 210 210 210 210 210 210 210 127.92 21.32 21.32 21.32
21.32 21.32 21.32 440 220 220 260 130 130 25.2 25.2 220 42.5 42.5
42.5
THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL
THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL
NUCLEAR NUCLEAR NUCLEAR THERMAL THERMAL THERMAL THERMAL THERMAL
THERMAL THERMAL THERMAL THERMAL
GAS COAL COAL COAL COAL COAL COAL COAL COAL DISL DISL DISL DISL
DISL DISL DISL NUCLE AR NUCLE AR NUCLE AR COAL COAL COAL DISL DISL
GAS GAS GAS GAS 0 1 938 1 13 1 181 1 639 1 746 1 8,180 1 8,185
1
908 9,141
1
10,425
1
1,142 9,799
1 1
1,498 1,341 1,370 685 1 384 1 262 1 1 1
1,688
2,843
3,020
2,800
2,608 1,355 1,264 1,841 920 920 1 1 1 1 1 1 1 1 1 1 1
1,558
1
2,044
1
2,024
1
1,841
1
62 1,178
1 1
41 866
1 1
39 39 630 0 0 0
CDM-SSC-PDD (version 02) CDM Executive Boardpage 27
19 19 20 20 20 20 21 21 22 22 23 23 23 23 23 24 24 25 25 25 25
26 26 26 26 26 26 27 27 27 27 27 27 28
TANIR BAVI TANIR BAVI BELGAUM DG BELGAUM DG BELGAUM DG BELGAUM
DG BRAMHAPURAM DG BRAMHAPURAM DG KOJIKODE DG KOJIKODE DG COCHIN
CCGT COCHIN CCGT COCHIN CCGT COCHIN CCGT COCHIN CCGT KASARGODE DG
KASARGODE DG KAYAM KULAM GT KAYAM KULAM GT KAYAM KULAM GT KAYAM
KULAM GT ENNORE ENNORE ENNORE ENNORE ENNORE ENNORE TUTICORIN
TUTICORIN TUTICORIN TUTICORIN TUTICORIN TUTICORIN METTUR
4 5 0 1 2 3 0 1 0 1 0 1 2 3 4 0 1 0 1 2 3 0 1 2 3 4 5 0 1 2 3 4
5 0
42.5 50 81.3 27.1 27.1 27.1 106.5 106.5 128 128 174 45 45 39 45
21.9 21.9 350 115.3 115.3 119.4 450 60 60 110 110 110 1050 210 210
210 210 210 840
THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL
THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL
THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL
THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL
THERMAL THERMAL
GAS GAS DISL DISL DISL DISL DISL DISL DISL DISL NAPT NAPT NAPT
NAPT NAPT DISL DISL GAS GAS GAS GAS COAL COAL COAL COAL COAL COAL
COAL COAL COAL COAL COAL COAL COAL 5,902 1 5,884 1 6,208 1 6,208 1
7,328 1 7,486 1 7,562 1 7,452 1 638 1 970 1 1,517 1 1,087 1 1,887 1
1,291 1 2,058 1 2,054 1 0 1 85 1 143 1 75 1 149 1 233 1 296 1 961 1
443 1 282 1 374 1 298 1 308 1 305 1 121 1 255 1 0 1 404 1 343 1 227
1
0 0 240 0 0 0 252 152 152 108 0 0 0 0 15 15 602 221 160 220
1,041 1 1 1 1 1 1
1 1 1 1 1
1 1 1 1 1 1
1 1
7,539
1
6,128
1
CDM-SSC-PDD (version 02) CDM Executive Boardpage 28
28 28 28 28 29 29 29 29 30 30 30 30 30 31 31 32 32 32 33 33 33
33 33 34 34 35 35 36 36 37 37 38 38
METTUR METTUR METTUR METTUR NORTH CHENNAI NORTH CHENNAI NORTH
CHENNAI NORTH CHENNAI BASIN BRIDGE GT BASIN BRIDGE GT BASIN BRIDGE
GT BASIN BRIDGE GT BASIN BRIDGE GT VALUTHUR GT VALUTHUR GT KUTTALAM
GT KUTTALAM GT KUTTALAM GT B. BRIDGE D.G B. BRIDGE D.G B. BRIDGE
D.G B. BRIDGE D.G B. BRIDGE D.G KOVILKALAPPAL KOVILKALAPPAL
P.NALLUR CCGT P.NALLUR CCGT SAMALPATTI DG SAMALPATTI DG
SAMAYANALLUR DG SAMAYANALLUR DG KARUPPUR GT (ABAN) KARUPPUR GT
1 2 3 4 0 1 2 3 0 1 2 3 4 0 1 0 1 2 0 1 2 3 4 0 1 0 1 0 1 0 1 0
1
210 210 210 210 630 210 210 210 120 30 30 30 30 94 94 100 64 36
200 50 50 50 50 107 107 330.5 330.5 105.7 105.7 106 106 70 70
THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL
THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL
THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL
THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL
THERMAL
COAL COAL COAL COAL COAL COAL COAL COAL NAPT NAPT NAPT NAPT NAPT
GAS GAS GAS GAS GAS DISL DISL DISL DISL DISL GAS GAS GAS GAS DISL
DISL DISL DISL GAS GAS 0 1 0 1 0 1 0 1 0 0 1 241 1 568 1 339 1 88 1
631 1 601 1 442 1 0 1 1,015 1 2,103 1 1,293 1 35 1 659 1 686 1 680
1 1,236 1 1,193 1 1,167 1 957 1 0 1 0 1 0 1 102 1 0 1 0 1 116 1 633
1 526 526 605 387 218 763 771 0 0 0 717 717 462 462 345 345 369 369
1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 158 1 167 1 266 1 86 1 39 1 3,949 1
4,259 1 4,001 1 3,951 1 3,560 1
CDM-SSC-PDD (version 02) CDM Executive Boardpage 29
39 39 39 39 39 39 39 39 39 39 40 40 40 40 40 40 40 40 41 41 41
42 42 43 43 43 44 44 45 45 45 45 45
NEYVELI ST I NEYVELI ST I NEYVELI ST I NEYVELI ST I NEYVELI ST I
NEYVELI ST I NEYVELI ST I NEYVELI ST I NEYVELI ST I NEYVELI ST I
NEYVELI ST II NEYVELI ST II NEYVELI ST II NEYVELI ST II NEYVELI ST
II NEYVELI ST II NEYVELI ST II NEYVELI ST II NEYVELI FST EXT
NEYVELI FST EXT NEYVELI FST EXT NEYVELI TPS(Z) NEYVELI TPS(Z)
M.A.P.P. M.A.P.P. M.A.P.P. KARAIKAL KARAIKAL MACHKUND MACHKUND
MACHKUND MACHKUND MACHKUND
0 1 2 3 4 5 6 7 8 9 0 1 2 3 4 5 6 7 0 1 2 0 1 0 1 2 0 1 0 1 2 3
4
600 50 50 50 50 50 50 100 100 100 1470 210 210 210 210 210 210
210 420 210 210 250 250 390 170 220 32.5 32.5 114.75 17 17 17
21.25
THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL
THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL
THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL THERMAL NUCLEAR
NUCLEAR NUCLEAR THERMAL THERMAL HYDRO HYDRO HYDRO HYDRO HYDRO
LIGN LIGN LIGN LIGN LIGN LIGN LIGN LIGN LIGN LIGN LIGN LIGN LIGN
LIGN LIGN LIGN LIGN LIGN LIGN LIGN LIGN LIGN LIGN NUCLE AR NUCLE AR
NUCLE AR GAS GAS
3,710
1
3,695
1
3,872
1
3,894
1
3,773
1
9,498
1
9,304
1
9,488
1
9,052
1
8,344
1
0
1
0
1
0
1
1,877
1
2,945 1,500 1,444
1 1 1 1 1
0
1
0
1
321
1
1,405
1
1,246 1,220
2,249
1,970
1,971
1,300
1,300
221 666
1
236 725
1
250 576
1
260 526
1
260 259 895
1 1
CDM-SSC-PDD (version 02) CDM Executive Boardpage 30
45 45 46 46 46 46 46 47 47 47 47 47 48 48 48 48 48 48 48 48 48
49 49 49 49 50 50 50 51 51 52 52 52
MACHKUND MACHKUND UPPER SILERU I&II UPPER SILERU-I UPPER
SILERU-I UPPER SILERU-II UPPER SILERU-II LOWER SILERU LOWER SILERU
LOWER SILERU LOWER SILERU LOWER SILERU NAGARJUNA SAGAR NAGARJUNA
SAGAR NAGARJUNA SAGAR NAGARJUNA SAGAR NAGARJUNA SAGAR NAGARJUNA
SAGAR NAGARJUNA SAGAR NAGARJUNA SAGAR NAGARJUNA SAGAR N_SAGAR RBC
& EXTN. N_SAGAR RBC N_SAGAR RBC N_SAGAR RBC EXTN. N_SAGAR LBC
N_SAGAR LBC N_SAGAR LBC DONKARAYI DONKARAYI SRISAILAM SRISAILAM
SRISAILAM
5 6 0 1 2 3 4 0 1 2 3 4 0 1 2 3 4 5 6 7 8 0 1 2 3 0 1 2 0 1 0 1
2
21.25 21.25 240 60 60 60 60 460 115 115 115 115 815.6 110 100.8
100.8 100.8 100.8 100.8 100.8 100.8 90 30 30 30 60 30 30 25 25 770
110 110
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 3,021 1,933 534 307 935 140 83 41 110 132 17 23 0 0 5 43 61 0
0 48 1,517 1,064 864 367 501 1,306 1,053 612 972 1,165 436 447 244
399 541
CDM-SSC-PDD (version 02) CDM Executive Boardpage 31
52 52 52 52 52 53 53 53 53 53 54 54 54 54 55 55 55 56 56 56 57
57 57 58 58 58 58 58 58 58 59 59 59 59
SRISAILAM SRISAILAM SRISAILAM SRISAILAM SRISAILAM T.B. DAM T.B.
DAM T.B. DAM T.B. DAM T.B. DAM POCHAMPAD POCHAMPAD POCHAMPAD
POCHAMPAD NIZAM SAGAR NIZAM SAGAR NIZAM SAGAR PENNA AHOBELAM PENNA
AHOBELAM PENNA AHOBELAM SINGUR SINGUR SINGUR SRISAILAM LBPH
SRISAILAM LBPH SRISAILAM LBPH SRISAILAM LBPH SRISAILAM LBPH
SRISAILAM LBPH SRISAILAM LBPH SHARAVATHY SHARAVATHY SHARAVATHY
SHARAVATHY
3 4 5 6 7 0 1 2 3 4 0 1 2 3 0 1 2 0 1 2 0 1 2 0 1 2 3 4 5 6 0 1
2 3
110 110 110 110 110 36 9 9 9 9 27 9 9 9 10 5 5 20 10 10 15 7.5
7.5 900 150 150 150 150 150 150 1006.2 103.5 103.5 103.5
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 5,207 4,195 2,935 3,299 0 379 555 326 88 4 7 6 1 0 0
1,404 234 234 234 234 234 234 3,836 1 1 1 1 1 1 1 1 66 14 0 0 0 29
3 0 6 0 126 103 81 64 0 224 164 118 101 148
CDM-SSC-PDD (version 02) CDM Executive Boardpage 32
59 59 59 59 59 59 59 60 60 60 60 60 60 60 61 61 61 62 62 62 63
63 63 64 64 64 64 64 64 65 65 65 66 66
SHARAVATHY SHARAVATHY SHARAVATHY SHARAVATHY SHARAVATHY
SHARAVATHY SHARAVATHY KALINADI KALINADI KALINADI KALINADI KALINADI
KALINADI KALINADI KALINADI SUPA KALINADI SUPA KALINADI SUPA
LIGANAMAKKI LIGANAMAKKI LIGANAMAKKI VARAHI VARAHI VARAHI BHADRA
BHADRA (L) BHADRA (L) BHADRA (L) BHADRA ( R) BHADRA (RBC) GHAT
PRABHA GHAT PRABHA GHAT PRABHA MANI DPH MANI DPH
4 5 6 7 8 9 10 0 1 2 3 4 5 6 0 1 2 0 1 2 0 1 2 0 1 2 3 4 5 0 1 2
0 1
103.5 103.5 103.5 103.5 103.5 89.1 89.1 855 135 135 135 150 150
150 100 50 50 55 27.5 27.5 230 115 115 39.2 2 12 12 7.2 6 32 16 16
9 4.5
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 25 21 18 11 22 86 73 59 62 96 107 41 18 11 43 1,095 896
840 717 968 274 176 110 119 193 423 395 256 240 293 2,554 2,411
1,803 1,709 1,712
CDM-SSC-PDD (version 02) CDM Executive Boardpage 33
66 67 67 67 68 68 68 68 68 69 69 69 69 70 70 70 70 71 71 71 71
71 72 72 72 72 72 72 72 72 72 73
MANI DPH MALLARPUR MALLARPUR MALLARPUR SHARAVATHY TAIL RACE
SHARAVATHY TAIL RACE SHARAVATHY TAIL RACE SHARAVATHY TAIL RACE
SHARAVATHY TAIL RACE KADRA KADRA KADRA KADRA KODASALI KODASALI
KODASALI KODASALI ALMATTI DAM ALMATTI DAM ALMATTI DAM ALMATTI DAM
ALMATTI DAM JOG JOG JOG JOG JOG JOG JOG JOG JOG SIVASAMUNDRUM
2 0 1 2 0 1 2 3 4 0 1 2 3 0 1 2 3 0 1 2 3 4 0 1 2 3 4 5 6 7 8
0
4.5 9 4.5 4.5 240 60 60 60 60 150 50 50 50 120 40 40 40 180 15
55 55 55 139.2 13.2 13.2 13.2 13.2 21.6 21.6 21.6 21.6 42
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
75 5 14 79 27 193 1 0 116 145 159 0 0 0 0 303 281 217 213 77 77 215
71 72 72 139 12 43 43 43 172 16 1 1 1 1 1 1 343 291 237 222 42 411
296 356 435 109 109 109 109 231 1 1 1 1 25 8 1 0 0
CDM-SSC-PDD (version 02) CDM Executive Boardpage 34
73 73 73 73 73 73 73 73 73 73 74 74 74 75 75 75 75 76 76 76 77
77 77 77 77 77 78 78 78 78 79 79 79 80
SIVASAMUNDRUM SIVASAMUNDRUM SIVASAMUNDRUM SIVASAMUNDRUM
SIVASAMUNDRUM SIVASAMUNDRUM SIVASAMUNDRUM SIVASAMUNDRUM
SIVASAMUNDRUM SIVASAMUNDRUM SHIMSAPURA SHIMSAPURA SHIMSAPURA
MUNIRABAD MUNIRABAD MUNIRABAD MUNIRABAD SHIVAPURA SHIVAPURA
SHIVAPURA SHAHPUR SHAHPUR SHAHPUR SHAHPUR SHAHPUR SHAHPUR
MADHAVAMANTRI MADHAVAMANTRI MADHAVAMANTRI MADHAVAMANTRI NARAYANPUR
NARAYANPUR NARAYANPUR KUTTIADI & EXTN.
1 2 3 4 5 6 7 8 9 10 0 1 2 0 1 2 3 0 1 2 0 1 2 3 4 5 0 1 2 3 0 1
2 0
3 3 3 3 3 3 6 6 6 6 17.2 8.6 8.6 28.3 9 9 10.3 18 9 9 6.6 1.3
1.3 1.3 1.3 1.4 4.5 1.5 1.5 1.5 11.6 5.8 5.8 125
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 266 328 302 258 0 27 36 38 0 0 0 13 23 8 8 8 43 21 21
369 1 1 1 1 1 14 34 22 22 24 104 104 67 54 71 100 66 47 41 69 62 43
57 57 94
CDM-SSC-PDD (version 02) CDM Executive Boardpage 35
80 80 80 80 81 81 81 81 81 81 81 82 82 82 82 82 82 82 83 83 83
84 84 84 84 85 85 85 86 86 86 86 87 87
KUTTIADI KUTTIADI KUTTIADI KUTTIADI EXTN. IDUKKI IDUKKI IDUKKI
IDUKKI IDUKKI IDUKKI IDUKKI SABARIGIRI SABARIGIRI SABARIGIRI
SABARIGIRI SABARIGIRI SABARIGIRI SABARIGIRI IDAMALAYAR IDAMALAYAR
IDAMALAYAR LOWER PERIYAR LOWER PERIYAR LOWER PERIYAR LOWER PERIYAR
KAKKAD KAKKAD KAKKAD SHOLAYAR SHOLAYAR SHOLAYAR SHOLAYAR SENGULAM
SENGULAM
1 2 3 4 0 1 2 3 4 5 6 0 1 2 3 4 5 6 0 1 2 0 1 2 3 0 1 2 0 1 2 3
0 1
25 25 25 50 780 130 130 130 130 130 130 300 50 50 50 50 50 50 75
37.5 37.5 180 60 60 60 50 25 25 54 18 18 18 48 12
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 132 114 129 127 165 195 226 137 201 177 183 149 125 210
105 105 263 1 1 542 559 412 361 511 327 330 258 154 335 1,331 1,398
800 695 1,218 2,285 2,739 1,895 1,240 148 1,993 1
CDM-SSC-PDD (version 02) CDM Executive Boardpage 36
87 87 87 88 88 88 88 89 89 89 89 89 89 89 90 90 90 90 90 91 91
92 92 92 93 93 93 94 94 94 94 95 95 95
SENGULAM SENGULAM SENGULAM NARIMANGLAM NARIMANGLAM NARIMANGLAM
NARIMANGLAM PALLIVASAL PALLIVASAL PALLIVASAL PALLIVASAL PALLIVASAL
PALLIVASAL PALLIVASAL PORINGALKUTTU PORINGALKUTTU PORINGALKUTTU
PORINGALKUTTU PORINGALKUTTU PORINGALKUTTU L PORINGALKUTTU L PANNIAR
PANNIAR PANNIAR KALLADA KALLADA KALLADA CHEMBUKADAVU-II
CHEMBUKADAVU-II CHEMBUKADAVU-II CHEMBUKADAVU-II URUMI-I URUMI
URUMI
2 3 4 0 1 2 3 0 1 2 3 4 5 6 0 1 2 3 4 0 1 0 1 2 0 1 2 0 1 2 3 0
1 2
12 12 12 45 15 15 15 37.5 5 5 5 7.5 7.5 7.5 32 8 8 8 8 16 16 30
15 15 15 7.5 7.5 3.75 1.25 1.25 1.25 3.75 1.25 1.25
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 0 0 0 0 0 0 0 0 6 2 2 2 3 1 1 1 1 1 1 1 69 67 35 36 71
75 1 168 122 78 76 53 29 78 0 169 169 141 173 190 122 229 181 165
117 156 192 222 30 30 30 1 1 1 263 272 229 195 41 41 232 1 1
CDM-SSC-PDD (version 02) CDM Executive Boardpage 37
95 96 96 96 96 97 97 97 97 98 98 98 98 98 98 98 98 98 98 98 98
98 98 98 98 99 99 100 100 100 100 100 100 100
URUMI MANIYAR MANIYAR MANIYAR MANIYAR KUTHUNGAL KUTHUNGAL
KUTHUNGAL KUTHUNGAL KUNDAH I-V KUNDAH-I KUNDAH-I KUNDAH-I KUNDAH-II
KUNDAH-II KUNDAH-II KUNDAH-II KUNDAH-II KUNDAH-III KUNDAH-III
KUNDAH-III KUNDAH-IV KUNDAH-IV KUNDAH-V KUNDAH-V PARSEN_S VALLE
PARSEN_S VALLE METTUR DAM METTUR DAM METTUR DAM METTUR DAM METTUR
DAM METTUR TUNNEL METTUR TUNNEL
3 0 1 2 3 0 1 2 3 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 0 1 0 1
2 3 4 5 6
1.25 12 4 4 4 21 7 7 7 555 20 20 20 35 35 35 35 35 60 60 60 50
50 20 20 30 30 240 10 10 10 10 50 50
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 704 411 129 181 64 34 16 18 1,692 1,336 760 427 0 33 23
19 31 29 23 21
1 34
1
36 12 12 12 1,559 1 1 1
55 55 333 1
CDM-SSC-PDD (version 02) CDM Executive Boardpage 38
100 100 101 101 101 101 101 102 102 102 103 103 103 103 104 104
104 104 104 104 104 105 105 106 106 107 107 107 107 107 108 108 108
108
METTUR TUNNEL METTUR TUNNEL PERIYAR PERIYAR PERIYAR PERIYAR
PERIYAR KODAYAR-I&II KODAYAR-I KODAYAR-II SHOLAYAR I&II
SHOLAYAR -I SHOLAYAR -I SHOLAYAR-II PYKARA PYKARA PYKARA PYKARA
PYKARA PYKARA PYKARA ALIYAR ALIYAR SARKARPATHY SARKARPATHY
PAPANASAM PAPANASAM PAPANASAM PAPANASAM PAPANASAM MOYAR MOYAR MOYAR
MOYAR
7 8 0 1 2 3 4 0 1 2 0 1 2 3 0 1 2 3 4 5 6 0 1 0 1 0 1 2 3 4 0 1
2 3
50 50 140 35 35 35 35 100 60 40 95 35 35 25 58.95 6.65 6.65 6.65
11 14 14 60 60 30 30 28 7 7 7 7 36 12 12 12
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 147 163 104 53 90 124 98 65 47 88 156 150 97 150 115
183 121 107 86 161 347 381 253 140 217 382 259 318 198 349 310 215
149 140 204 485 457 226 212 491
CDM-SSC-PDD (version 02) CDM Executive Boardpage 39
109 109 110 110 111 111 111 111 111 111 111 111 111 112 112 112
112 113 113 113 113 113
SURULIYAR SURULIYAR SERVALAR SERVALAR LOWER METTUR LOWER METTUR
PH-1 LOWER METTUR PH-1 LOWER METTUR PH-2 LOWER METTUR PH-2 LOWER
METTUR PH-3 LOWER METTUR PH-3 LOWER METTUR PH-4 LOWER METTUR PH-4
VAIGAI DAM VAIGAI DAM VAIGAI DAM SATHNUR DAM KADAMPARI KADAMPARI
KADAMPARI KADAMPARI KADAMPARI
0 1 0 1 0 1 2 3 4 5 6 7 8 0 1 2 3 0 1 2 3 4
35 35 20 20 120 15 15 15 15 15 15 15 15 13.5 3 3 7.5 400 100 100
100 100
HYDRO HYDRO HYDRO HYDRO HYDRO HYDRO HYDRO HYDRO HYDRO HYDRO
HYDRO HYDRO HYDRO HYDRO HYDRO HYDRO HYDRO HYDRO HYDRO HYDRO HYDRO
HYDRO
93 34 428
87 24 367
75 19 167
41 19 0
101 33 254
78
64
27
16
86
48 186 162 202 406 256
CDM-SSC-PDD (version 02) CDM Executive Boardpage 40
In Summary Combined margin emission factor is arrived as
Parameter Gross Generation Total (In GWh) Net Generation Total (In
GWh) 20% of Net Generation (In GWh) Absolute Emissions Total (tCO2)
Absolute Emissions OM (tCO2) Absolute Emissions BM (tCO2) Simple
Operating Margin (tCO2/ MWh) Build Margin (tCO2/ MWh) Combined
margin incl. Imports (tCO2/ MWh) 2000-01 128,796 120,964 24,193
2001-02 131,747 123,468 24,694 2002-03 136,742 127,617 25,523
2003-04 138,153 128,032 25,606 2004-05 143,932 134,551 26,910
87,815,363
91,590,959
103,269,937
107,406,076
104,917,425
87,815,363
91,590,959
103,269,937
107,406,076
104,917,425
19,332,594
1.02
1.00
0.99
1.00
1.00
0.71
0.86
0.85
0.85
0.86
0.85
CDM-SSC-PDD (version 02) CDM Executive Boardpage 41
Appendix 2 PROJECT CASH FLOW
CDM-SSC-PDD (version 02) CDM Executive Boardpage 42
For without considering the revenues from CDM (Or click the link
below)
Without CDM Revenues.xls
For with revenues from CDM factored in the project cash flow (Or
click the link below)
With CDM Revenues.xls
CDM-SSC-PDD (version 02) CDM Executive Boardpage 43
CDM-SSC-PDD (version 02) CDM Executive Boardpage 44
CDM-SSC-PDD (version 02) CDM Executive Boardpage 45