Wind Mill Project

CDM-SSC-PDD (version 02) CDM – Executive Board

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CLEAN DEVELOPMENT MECHANISM SIMPLIFIED PROJECT DESIGN DOCUMENT FOR SMALL-SCALE PROJECT ACTIVITIES (SSC-CDM-PDD) Version 02 CONTENTS

A.

General description of the small-scale project activity

B.

Baseline methodology

C.

Duration of the project activity / Crediting period

D.

Monitoring methodology and plan

E.

Calculation of GHG emission reductions by sources

F.

Environmental impacts

G.

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 Board

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Revision history of this document Version Number 01 02

Date

Description and reason of revision

21 January 2003 8 July 2005

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>

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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 Board

Name of Party involved

Government of India (Host Country)

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Private and / or Public entity Project Participants

Kindly indicate if the Party involved wishes to be considered as Project Participant

NEG Micon (I) Private Limited

No

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

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

Date of Commissioning

Location

H.T. S.C. No.

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

Tenkasi Tenkasi Tenkasi Tenkasi Tenkasi Surandai Surandai Ayikudi Surandai Surandai Tenkasi Tenkasi Tenkasi Tenkasi Tenkasi Tenkasi

956 1122 1059 1064 1202 1161 1160 773 1357 1358 1056 1057 1058 1199 1361 1363

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 Board

Parameters Sl No 1

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

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NM 48/750

Parameters Sl No 5

750 KW Stall 4 m/s 25 m/s 48.2 m 1824 cm

6 2

3 nos. 7 Hydraulic, fail safe Hydraulic 8 Planetary - parallel axle 1:67.5 - 50Hz

Generator Type Nominal Voltage Nominal Frequency Name Plate Rating Cooling Yaw Type Drive Mechanism Tower Type Hub Height Controller Type Capacitor Bank

NM 48/750 Asynchronous 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

High quality forged shaft Spherical roller bearing 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.

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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.

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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

A.4.4. Public funding of the small-scale project activity: >> There is no public funding involved in this project activity.

10 years 22552.2

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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.

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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.

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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

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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 project’s 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

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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 Factor 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

2001-02

2002-03

2003-04

2004-05

128,796

131,747

136,742

138,153

143,932

120,964

123,468

127,617

128,032

134,551

24,193

24,694

25,523

25,606

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.

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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.

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D.3 >>

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Data to be monitored:

ID No.

Data type

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

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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

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EFBM,y EFy

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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 Board

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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.

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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 DOE’s 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 Board

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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 holder’s 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 Board

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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: ƒ Improvement in the roads and other communication in that area ƒ 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: ƒ Moving rain clouds due to the windmills ƒ Too much heat generated from the windmills

CDM-SSC-PDD (version 02) CDM – Executive Board

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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 Board

page 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 Board

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Annex 2 INFORMATION REGARDING PUBLIC FUNDING There is no public funding involved in this project activity

CDM-SSC-PDD (version 02) CDM – Executive Board

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Appendix 1 BASELINE INFORMATION – Southern Region Electricity Board Grid S.

Name

Unit-no

NO

Capacity MW As on 31STMar 2005

Type

Fuel

1

K_GUDEM

0

680

THERMAL

COAL

1

K_GUDEM

1

60

THERMAL

COAL

1

K_GUDEM

2

60

THERMAL

COAL

1

K_GUDEM

3

60

THERMAL

COAL

1

K_GUDEM

4

60

THERMAL

COAL

1

K_GUDEM

5

110

THERMAL

COAL

1

K_GUDEM

6

110

THERMAL

COAL

1

K_GUDEM

7

110

THERMAL

COAL

1 2

K_GUDEM K_GUDEM NEW

8 0

110 500

THERMAL THERMAL

COAL COAL

2

K_GUDEM NEW

1

250

THERMAL

COAL

2 3

K_GUDEM NEW VIJAYWADA

2 0

250 1260

THERMAL THERMAL

COAL COAL

3

VIJAYWADA

1

210

THERMAL

COAL

3

VIJAYWADA

2

210

THERMAL

COAL

3

VIJAYWADA

3

210

THERMAL

COAL

3

VIJAYWADA

4

210

THERMAL

COAL

3

VIJAYWADA

5

210

THERMAL

COAL

3 4

VIJAYWADA R_GUNDEM - B

6 0

210 62.5

THERMAL THERMAL

COAL COAL

4

R_GUNDEM - B

1

62.5

THERMAL

COAL

2000-01

2000-01

2001-02

2001-02

2002-03

2002-03

2003-04

2003-04

2004-05

2004-05

2004-05

Net Generation GWh

in Operating Margin

Net Generatio n GWh

in Operating Margin

Net Generation GWh

in Operating Margin

Net Generation GWh

in Operating Margin

Net Generation GWh

in Operating Margin

in Build Margin

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 Board

page 25

5

RAYAL SEEMA

0

420

THERMAL

COAL

5

RAYAL SEEMA

1

210

THERMAL

COAL

5

RAYAL SEEMA

2

210

THERMAL

COAL

6

VIJESWARAN GT

0

272.3

THERMAL

GAS

6

VIJESWARAN GT

1

33

THERMAL

GAS

6

VIJESWARAN GT

2

33

THERMAL

GAS

6

VIJESWARAN GT

3

112.5

THERMAL

GAS

6

VIJESWARAN GT

4

34

THERMAL

GAS

3,123

1

3,068

1

3,120

1

3,045

1

3,078

1

1,928

1

1,905

1

1,978

1

2,093

1

1,940

1

255

6

VIJESWARAN GT

5

59.8

THERMAL

GAS

7

R_GUNDEM STPS

0

2600

THERMAL

COAL

412

7

R_GUNDEM STPS

1

200

THERMAL

COAL

7

R_GUNDEM STPS

2

200

THERMAL

COAL

7

R_GUNDEM STPS

3

200

THERMAL

COAL

7

R_GUNDEM STPS

4

500

THERMAL

COAL

7

R_GUNDEM STPS

5

500

THERMAL

COAL

7

R_GUNDEM STPS

6

500

THERMAL

COAL

7

R_GUNDEM STPS

7

500

THERMAL

COAL

8

SIMHADRI

0

1000

THERMAL

COAL

8

SIMHADRI

1

500

THERMAL

COAL

3,856

8

SIMHADRI

2

500

THERMAL

COAL

3,806

9

JEGURUPADU GT

0

235.4

THERMAL

GAS

9

JEGURUPADU GT

1

52.8

THERMAL

GAS

9

JEGURUPADU GT

2

52.8

THERMAL

GAS

9

JEGURUPADU GT

3

52.8

THERMAL

GAS

9

JEGURUPADU GT

4

77

THERMAL

GAS

10

GODAVARI GT

0

208

THERMAL

GAS

10

GODAVARI GT

1

47

THERMAL

GAS

10

GODAVARI GT

2

47

THERMAL

GAS

10

GODAVARI GT

3

47

THERMAL

GAS

10

GODAVARI GT

4

67

THERMAL

GAS

11

KONDAPALLI GT

0

350

THERMAL

GAS

11

KONDAPALLI GT

1

112

THERMAL

GAS

0

1

11

KONDAPALLI GT

2

112

THERMAL

GAS

0

1

11

KONDAPALLI GT

3

126

THERMAL

GAS

0

1

15,433

1

14,693

1

15,748

1

14,766

1

16,038

1

0

1

4,576

1

7,027

1

7,663

1

488

1 1 1 1

1,625

1

1,575

1

1,555

1

1,476

1

1,392

1

1,544

1

1,458

1

1,160

1

1,090

1

1,344

1

659

1

1,683

1

2,403

1

2,171

1

2,179

1

CDM-SSC-PDD (version 02) CDM – Executive Board

page 26

12

LVS POWER DG

0

36.8

THERMAL

DISL

12

LVS POWER DG

1

18.4

THERMAL

DISL

0

12 13

LVS POWER DG PEDDAPURAM CCGT

2 0

18.4 220

THERMAL THERMAL

DISL GAS

1

1

13

PEDDAPURAM CCGT

1

220

THERMAL

GAS

14

RAICHUR

0

1470

THERMAL

COAL

14

RAICHUR

1

210

THERMAL

COAL

14

RAICHUR RAICHUR

2

210

THERMAL

COAL

14

0

1

90

1

8,180

1

8,185

1

2

1

0

1

0

1

908

1

1,248

1

0 1,142

1

908 9,141

1

10,425

1

1,142 9,799

1 1 1

1

3

210

THERMAL

COAL

14

RAICHUR

4

210

THERMAL

COAL

14

RAICHUR

5

210

THERMAL

COAL

1,498

14

RAICHUR

6

210

THERMAL

COAL

1,341

14

RAICHUR

7

210

THERMAL

COAL

1,370

15

YELHANKA (DG)

0

127.92

THERMAL

DISL

15

YELHANKA (DG)

1

21.32

THERMAL

DISL

15

YELHANKA (DG)

2

21.32

THERMAL

DISL

15

YELHANKA (DG)

3

21.32

THERMAL

DISL

15

YELHANKA (DG)

4

21.32

THERMAL

DISL

15

YELHANKA (DG)

5

21.32

THERMAL

DISL

15

YELHANKA (DG)

6

21.32

THERMAL

16

KAIGA

0

440

NUCLEAR

16

KAIGA

1

220

NUCLEAR

16

KAIGA

2

220

NUCLEAR

DISL NUCLE AR NUCLE AR NUCLE AR

17

TORANGALLU IMP

0

260

THERMAL

COAL

17

TORANGALLU IMP

1

130

THERMAL

COAL

920

17

TORANGALLU IMP

2

130

THERMAL

COAL

920

18

BELLARY DG

0

25.2

THERMAL

DISL

18

BELLARY DG

1

25.2

THERMAL

DISL

19

TANIR BAVI

0

220

THERMAL

GAS

19

TANIR BAVI

1

42.5

THERMAL

GAS

0

1

19

TANIR BAVI

2

42.5

THERMAL

GAS

0

1

19

TANIR BAVI

3

42.5

THERMAL

GAS

0

1

639

1

1,688

746

1

2,843

685

1

3,020

384

1

2,800

262

1 1 1

2,608 1,355

1,558

1

2,044

1

2,024

1

1,841

1

1,264 1,841

13

1

181

1

62

1

41

1

39

0

1

938

1

1,178

1

866

1

630

1 1 1 1 1 1

39

1 1

CDM-SSC-PDD (version 02) CDM – Executive Board

page 27

19

TANIR BAVI

4

42.5

THERMAL

GAS

0

19

TANIR BAVI

5

50

THERMAL

GAS

0

20

BELGAUM DG

0

81.3

THERMAL

DISL

20

BELGAUM DG

1

27.1

THERMAL

DISL

0

1

20

BELGAUM DG

2

27.1

THERMAL

DISL

0

1

20

BELGAUM DG

3

27.1

THERMAL

DISL

0

21

BRAMHAPURAM DG

0

106.5

THERMAL

DISL

21

BRAMHAPURAM DG

1

106.5

THERMAL

DISL

22

KOJIKODE DG

0

128

THERMAL

DISL

22

KOJIKODE DG

1

128

THERMAL

DISL

23

COCHIN CCGT

0

174

THERMAL

NAPT

23

COCHIN CCGT

1

45

THERMAL

NAPT

0

1

23

COCHIN CCGT

2

45

THERMAL

NAPT

0

1

23

COCHIN CCGT

3

39

THERMAL

NAPT

0

1

23

COCHIN CCGT

4

45

THERMAL

NAPT

0

24

KASARGODE DG

0

21.9

THERMAL

DISL

0

1

404

1

343

1

227

1

308

1

305

1

121

1

255

1

443

1

282

1

374

1

298

1

240

1 1 1

1

252

1

152

1

152 149

1

233

1

296

1

961

1

108

0

1

85

1

143

1

75

1

15

1,887

1

1,291

1

2,058

1

2,054

1

602

24

KASARGODE DG

1

21.9

THERMAL

DISL

25

KAYAM KULAM GT

0

350

THERMAL

GAS

25

KAYAM KULAM GT

1

115.3

THERMAL

GAS

221

25

KAYAM KULAM GT

2

115.3

THERMAL

GAS

160

25

KAYAM KULAM GT

3

119.4

THERMAL

GAS

26

ENNORE

0

450

THERMAL

COAL

26

ENNORE

1

60

THERMAL

COAL

26

ENNORE

2

60

THERMAL

COAL

26

ENNORE

3

110

THERMAL

COAL

26

ENNORE

4

110

THERMAL

COAL

26

ENNORE

5

110

THERMAL

COAL

27

TUTICORIN

0

1050

THERMAL

COAL

27

TUTICORIN

1

210

THERMAL

COAL

27

TUTICORIN

2

210

THERMAL

COAL

27

TUTICORIN

3

210

THERMAL

COAL

27

TUTICORIN

4

210

THERMAL

COAL

27

TUTICORIN

5

210

THERMAL

COAL

28

METTUR

0

840

THERMAL

COAL

1 1

1 1

15

1 1

638

1

970

1

1,517

1

1,087

1

220 1,041

1

1

7,328

1

7,486

1

7,562

1

7,452

1

7,539

1

5,902

1

5,884

1

6,208

1

6,208

1

6,128

1

CDM-SSC-PDD (version 02) CDM – Executive Board

page 28

28

METTUR

1

210

THERMAL

COAL

28

METTUR

2

210

THERMAL

COAL

28

METTUR

3

210

THERMAL

COAL

28

METTUR

4

210

THERMAL

COAL

29

NORTH CHENNAI

0

630

THERMAL

COAL

29

NORTH CHENNAI

1

210

THERMAL

COAL

29

NORTH CHENNAI

2

210

THERMAL

COAL

29

NORTH CHENNAI

3

210

THERMAL

COAL

30

BASIN BRIDGE GT

0

120

THERMAL

NAPT

30

BASIN BRIDGE GT

1

30

THERMAL

NAPT

30

BASIN BRIDGE GT

2

30

THERMAL

NAPT

30

BASIN BRIDGE GT

3

30

THERMAL

NAPT

30

BASIN BRIDGE GT

4

30

THERMAL

NAPT

31

VALUTHUR GT

0

94

THERMAL

GAS

31

VALUTHUR GT

1

94

THERMAL

GAS

32

KUTTALAM GT

0

100

THERMAL

GAS

32

KUTTALAM GT

1

64

THERMAL

GAS

387

32

KUTTALAM GT

2

36

THERMAL

GAS

218

33

B. BRIDGE D.G

0

200

THERMAL

DISL

33

B. BRIDGE D.G

1

50

THERMAL

DISL

771

33

B. BRIDGE D.G

2

50

THERMAL

DISL

0

33

B. BRIDGE D.G

3

50

THERMAL

DISL

0

33

B. BRIDGE D.G

4

50

THERMAL

DISL

34

KOVILKALAPPAL

0

107

THERMAL

GAS

34

KOVILKALAPPAL

1

107

THERMAL

GAS

35

P.NALLUR CCGT

0

330.5

THERMAL

GAS

35

P.NALLUR CCGT

1

330.5

THERMAL

GAS

36

SAMALPATTI DG

0

105.7

THERMAL

DISL

36

SAMALPATTI DG SAMAYANALLUR DG

1

105.7

THERMAL

DISL

0

37

106

THERMAL

DISL

1

106

THERMAL

DISL

38

SAMAYANALLUR DG KARUPPUR GT (ABAN)

0

70

THERMAL

GAS

38

KARUPPUR GT

1

70

THERMAL

GAS

37

3,949

1

4,259

1

4,001

1

3,951

1

3,560

1

158

1

167

1

266

1

86

1

39

1

0

1

0

1

116

1

633

1

526

1

526 0

1,236

35

1

1

1

0

1,193

659

1

1

1

0

1,167

686

1

1

1

102

957

680

1

1

1

605

763

0 717

1 1 1 1 1

1

717 0

1

1,015

1

2,103

1

1,293

1

88

1

631

1

601

1

442

1

462

1 1

462 345

1 1

345 0

1

241

1

568

1

339

1

369

1 1

369 0

1

0

1

0

1

0

1

1 1

0

1

CDM-SSC-PDD (version 02) CDM – Executive Board

page 29

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

39

NEYVELI ST I

0

600

THERMAL

LIGN

39

NEYVELI ST I

1

50

THERMAL

LIGN

39

NEYVELI ST I

2

50

THERMAL

LIGN

39

NEYVELI ST I

3

50

THERMAL

LIGN

39

NEYVELI ST I

4

50

THERMAL

LIGN

39

NEYVELI ST I

5

50

THERMAL

LIGN

39

NEYVELI ST I

6

50

THERMAL

LIGN

39

NEYVELI ST I

7

100

THERMAL

LIGN

39

NEYVELI ST I

8

100

THERMAL

LIGN

39

NEYVELI ST I

9

100

THERMAL

LIGN

40

NEYVELI ST II

0

1470

THERMAL

LIGN

40

NEYVELI ST II

1

210

THERMAL

LIGN

40

NEYVELI ST II

2

210

THERMAL

LIGN

40

NEYVELI ST II

3

210

THERMAL

LIGN

40

NEYVELI ST II

4

210

THERMAL

LIGN

40

NEYVELI ST II

5

210

THERMAL

LIGN

40

NEYVELI ST II

6

210

THERMAL

LIGN

40

NEYVELI ST II

7

210

THERMAL

LIGN

41

NEYVELI FST EXT

0

420

THERMAL

LIGN

41

NEYVELI FST EXT

1

210

THERMAL

LIGN

1,500

41

NEYVELI FST EXT

2

210

THERMAL

LIGN

1,444

42

NEYVELI TPS(Z)

0

250

THERMAL

LIGN

42

NEYVELI TPS(Z)

1

250

THERMAL

43

M.A.P.P.

0

390

NUCLEAR

43

M.A.P.P.

1

170

NUCLEAR

43

M.A.P.P.

2

220

NUCLEAR

LIGN NUCLE AR NUCLE AR NUCLE AR

44

KARAIKAL

0

32.5

THERMAL

GAS

44

KARAIKAL

1

32.5

THERMAL

GAS

45

MACHKUND

0

114.75

HYDRO

45

MACHKUND

1

17

HYDRO

45

MACHKUND

2

17

HYDRO

45

MACHKUND

3

17

HYDRO

45

MACHKUND

4

21.25

HYDRO

0

1

0

1

321

1

1,405

1

1,246

1 1 1

1,220 2,249

221

1,970

1

236

1,971

1

250

1,300

1

260

1,300

1

260 259

666

725

576

526

1

895

1 1

CDM-SSC-PDD (version 02) CDM – Executive Board

page 30

45

MACHKUND

5

21.25

45

MACHKUND

6

21.25

HYDRO HYDRO

46

UPPER SILERU I&II

0

240

HYDRO

46

UPPER SILERU-I

1

60

HYDRO

46

UPPER SILERU-I

2

60

HYDRO

46

UPPER SILERU-II

3

60

HYDRO

46

UPPER SILERU-II

4

60

HYDRO

47

LOWER SILERU

0

460

HYDRO

47

LOWER SILERU

1

115

HYDRO

47

LOWER SILERU

2

115

HYDRO

47

LOWER SILERU

3

115

HYDRO

47

4

115

HYDRO

48

LOWER SILERU NAGARJUNA SAGAR

0

815.6

HYDRO

48

NAGARJUNA SAGAR

1

110

HYDRO

48

NAGARJUNA SAGAR

2

100.8

HYDRO

48

NAGARJUNA SAGAR

3

100.8

HYDRO

48

NAGARJUNA SAGAR

4

100.8

HYDRO

48

NAGARJUNA SAGAR

5

100.8

HYDRO

48

NAGARJUNA SAGAR

6

100.8

HYDRO

48

NAGARJUNA SAGAR

7

100.8

HYDRO

48

8

100.8

HYDRO

49

NAGARJUNA SAGAR N_SAGAR RBC & EXTN.

0

90

HYDRO

49

N_SAGAR RBC

1

30

HYDRO

49

2

30

HYDRO

49

N_SAGAR RBC N_SAGAR RBC EXTN.

3

30

HYDRO

50

N_SAGAR LBC

0

60

HYDRO

50

N_SAGAR LBC

1

30

HYDRO

50

N_SAGAR LBC

2

30

HYDRO

51

DONKARAYI

0

25

HYDRO

51

DONKARAYI

1

25

HYDRO

52

SRISAILAM

0

770

HYDRO

52

SRISAILAM

1

110

HYDRO

52

SRISAILAM

2

110

HYDRO

436

447

244

399

541

1,306

1,053

612

972

1,165

1,517

1,064

864

367

501

43

61

0

0

48

17

23

0

0

5

140

83

41

110

132

3,021

1,933

534

307

935

CDM-SSC-PDD (version 02) CDM – Executive Board

page 31

52

SRISAILAM

3

110

HYDRO

52

SRISAILAM

4

110

HYDRO

52

SRISAILAM

5

110

HYDRO

52

SRISAILAM

6

110

HYDRO

52

SRISAILAM

7

110

HYDRO

53

T.B. DAM

0

36

HYDRO

53

T.B. DAM

1

9

HYDRO

53

T.B. DAM

2

9

HYDRO

53

T.B. DAM

3

9

HYDRO

53

T.B. DAM

4

9

HYDRO

54

POCHAMPAD

0

27

HYDRO

54

POCHAMPAD

1

9

HYDRO

54

POCHAMPAD

2

9

HYDRO

54

POCHAMPAD

3

9

HYDRO

55

NIZAM SAGAR

0

10

HYDRO

55

NIZAM SAGAR

1

5

HYDRO

224

164

118

101

148

126

103

81

64

0

29

3

0

6

0

66

14

0

0

0

88

4

7

6

55

NIZAM SAGAR

2

5

HYDRO

56

PENNA AHOBELAM

0

20

HYDRO

56

PENNA AHOBELAM

1

10

HYDRO

56

PENNA AHOBELAM

2

10

HYDRO

57

SINGUR

0

15

HYDRO

57

SINGUR

1

7.5

HYDRO

0

1

57

SINGUR

2

7.5

HYDRO

0

1

58

SRISAILAM LBPH

0

900

HYDRO

58

SRISAILAM LBPH

1

150

HYDRO

234

1

58

SRISAILAM LBPH

2

150

HYDRO

234

1

58

SRISAILAM LBPH

3

150

HYDRO

234

1

58

SRISAILAM LBPH

4

150

HYDRO

234

1

58

SRISAILAM LBPH

5

150

HYDRO

234

1

58

SRISAILAM LBPH

6

150

HYDRO

234

1

59

SHARAVATHY

0

1006.2

HYDRO

59

SHARAVATHY

1

103.5

HYDRO

59

SHARAVATHY

2

103.5

HYDRO

59

SHARAVATHY

3

103.5

HYDRO

0

5,207

379

4,195

555

2,935

326

3,299

1

1,404

3,836

CDM-SSC-PDD (version 02) CDM – Executive Board

page 32

59

SHARAVATHY

4

103.5

HYDRO

59

SHARAVATHY

5

103.5

HYDRO

59

SHARAVATHY

6

103.5

HYDRO

59

SHARAVATHY

7

103.5

HYDRO

59

SHARAVATHY

8

103.5

HYDRO

59

SHARAVATHY

9

89.1

HYDRO

59

SHARAVATHY

10

89.1

HYDRO

60

KALINADI

0

855

HYDRO

60

KALINADI

1

135

HYDRO

60

KALINADI

2

135

HYDRO

60

KALINADI

3

135

HYDRO

60

KALINADI

4

150

HYDRO

60

KALINADI

5

150

HYDRO

60

KALINADI

6

150

HYDRO

61

KALINADI SUPA

0

100

HYDRO

61

KALINADI SUPA

1

50

HYDRO

61

KALINADI SUPA

2

50

HYDRO

62

LIGANAMAKKI

0

55

HYDRO

62

LIGANAMAKKI

1

27.5

HYDRO

62

LIGANAMAKKI

2

27.5

HYDRO

63

VARAHI

0

230

HYDRO

63

VARAHI

1

115

HYDRO

63

VARAHI

2

115

HYDRO

64

BHADRA

0

39.2

HYDRO

64

BHADRA (L)

1

2

HYDRO

64

BHADRA (L)

2

12

HYDRO

64

BHADRA (L)

3

12

HYDRO

64

BHADRA ( R)

4

7.2

HYDRO

64

BHADRA (RBC)

5

6

HYDRO

65

GHAT PRABHA

0

32

HYDRO

65

GHAT PRABHA

1

16

HYDRO

65

GHAT PRABHA

2

16

HYDRO

66

MANI DPH

0

9

HYDRO

66

MANI DPH

1

4.5

HYDRO

2,554

2,411

1,803

1,709

1,712

423

395

256

240

293

274

176

110

119

193

1,095

896

840

717

968

107

41

18

11

43

86

73

59

62

96

25

21

18

11

22

CDM-SSC-PDD (version 02) CDM – Executive Board

page 33

66

MANI DPH

2

4.5

HYDRO

67

MALLARPUR

0

9

HYDRO

67

MALLARPUR

1

4.5

HYDRO

67

2

4.5

HYDRO

0

240

HYDRO

1

60

HYDRO

109

1

2

60

HYDRO

109

1

3

60

HYDRO

109

1

68

MALLARPUR SHARAVATHY TAIL RACE SHARAVATHY TAIL RACE SHARAVATHY TAIL RACE SHARAVATHY TAIL RACE SHARAVATHY TAIL RACE

4

60

HYDRO

109

1

69

KADRA

0

150

HYDRO

69

KADRA

1

50

HYDRO

69

KADRA

2

50

HYDRO

69

KADRA

3

50

HYDRO

70

KODASALI

0

120

HYDRO

70

KODASALI

1

40

HYDRO

71

70

KODASALI

2

40

HYDRO

72

68 68 68 68

25

8

1

0

0

42

411

296

356

435

343

291

237

222

231 77 77

303

281

217

213

215

70

KODASALI

3

40

HYDRO

71

ALMATTI DAM

0

180

HYDRO

72

71

ALMATTI DAM

1

15

HYDRO

12

1

71

ALMATTI DAM

2

55

HYDRO

43

1

71

ALMATTI DAM

3

55

HYDRO

43

1

71

ALMATTI DAM

4

55

HYDRO

43

1

72

JOG

0

139.2

HYDRO

72

JOG

1

13.2

HYDRO

72

JOG

2

13.2

HYDRO

72

JOG

3

13.2

HYDRO

72

JOG

4

13.2

HYDRO

72

JOG

5

21.6

HYDRO

72

JOG

6

21.6

HYDRO

72

JOG

7

21.6

HYDRO

72

JOG

8

21.6

HYDRO

73

SIVASAMUNDRUM

0

42

HYDRO

0

0

75

0

116

5

0

145

14

0

159

79

1

139

172 16

1

27

1

193

CDM-SSC-PDD (version 02) CDM – Executive Board

page 34

73

SIVASAMUNDRUM

1

3

HYDRO

73

SIVASAMUNDRUM

2

3

HYDRO

73

SIVASAMUNDRUM

3

3

HYDRO

73

SIVASAMUNDRUM

4

3

HYDRO

73

SIVASAMUNDRUM

5

3

HYDRO

73

SIVASAMUNDRUM

6

3

HYDRO

73

SIVASAMUNDRUM

7

6

HYDRO

73

SIVASAMUNDRUM

8

6

HYDRO

73

SIVASAMUNDRUM

9

6

HYDRO

73

SIVASAMUNDRUM

10

6

HYDRO

74

SHIMSAPURA

0

17.2

HYDRO

74

SHIMSAPURA

1

8.6

HYDRO

74

SHIMSAPURA

2

8.6

HYDRO

75

MUNIRABAD

0

28.3

HYDRO

75

MUNIRABAD

1

9

HYDRO

75

MUNIRABAD

2

9

HYDRO

75

MUNIRABAD

3

10.3

HYDRO

76

SHIVAPURA

0

18

HYDRO

76

SHIVAPURA

1

9

HYDRO

76

SHIVAPURA

2

9

HYDRO

77

SHAHPUR

0

6.6

HYDRO

77

SHAHPUR

1

1.3

HYDRO

77

SHAHPUR

2

1.3

HYDRO

77

SHAHPUR

3

1.3

HYDRO

77

SHAHPUR

4

1.3

HYDRO

77

SHAHPUR

5

1.4

HYDRO

78

MADHAVAMANTRI

0

4.5

HYDRO

78

MADHAVAMANTRI

1

1.5

HYDRO

8

78

MADHAVAMANTRI

2

1.5

HYDRO

8

1

78

MADHAVAMANTRI

3

1.5

HYDRO

8

1

79

NARAYANPUR

0

11.6

HYDRO

79

NARAYANPUR

1

5.8

HYDRO

21

1

79

NARAYANPUR

2

5.8

HYDRO

21

1

80

KUTTIADI & EXTN.

0

125

HYDRO

62

43

57

57

94

100

66

47

41

69

104

104

67

54

71

14

34

22

22

24

0

0

0

13

23

0

266

27

328

36

302

38

258

1

43

369

CDM-SSC-PDD (version 02) CDM – Executive Board

page 35

80

KUTTIADI

1

25

HYDRO

80

KUTTIADI

2

25

HYDRO

80

KUTTIADI

3

25

HYDRO

80

KUTTIADI EXTN.

4

50

HYDRO

81

IDUKKI

0

780

HYDRO

81

IDUKKI

1

130

HYDRO

81

IDUKKI

2

130

HYDRO

81

IDUKKI

3

130

HYDRO

81

IDUKKI

4

130

HYDRO

81

IDUKKI

5

130

HYDRO

81

IDUKKI

6

130

HYDRO

82

SABARIGIRI

0

300

HYDRO

82

SABARIGIRI

1

50

HYDRO

82

SABARIGIRI

2

50

HYDRO

82

SABARIGIRI

3

50

HYDRO

82

SABARIGIRI

4

50

HYDRO

82

SABARIGIRI

5

50

HYDRO

82

SABARIGIRI

6

50

HYDRO

83

IDAMALAYAR

0

75

HYDRO

83

IDAMALAYAR

1

37.5

HYDRO

148 2,285

2,739

1,895

1,240

1,993

1,331

1,398

800

695

1,218

327

330

258

154

335

542

559

412

361

511

177

183

149

125

1

83

IDAMALAYAR

2

37.5

HYDRO

84

LOWER PERIYAR

0

180

HYDRO

84

LOWER PERIYAR

1

60

HYDRO

84

LOWER PERIYAR

2

60

HYDRO

84

LOWER PERIYAR

3

60

HYDRO

85

KAKKAD

0

50

HYDRO

85

KAKKAD

1

25

HYDRO

105

1

85

KAKKAD

2

25

HYDRO

105

1

86

SHOLAYAR

0

54

HYDRO

86

SHOLAYAR

1

18

HYDRO

86

SHOLAYAR

2

18

HYDRO

86

SHOLAYAR

3

18

HYDRO

87

SENGULAM

0

48

HYDRO

87

SENGULAM

1

12

HYDRO

210

195

226

137

201

263

132

114

129

127

165

CDM-SSC-PDD (version 02) CDM – Executive Board

page 36

87

SENGULAM

2

12

HYDRO

87

SENGULAM

3

12

HYDRO

41

1

87

SENGULAM

4

12

HYDRO

41

1

88

NARIMANGLAM

0

45

HYDRO

88

NARIMANGLAM

1

15

HYDRO

88

NARIMANGLAM

2

15

HYDRO

88

NARIMANGLAM

3

15

HYDRO

89

PALLIVASAL

0

37.5

HYDRO

89

PALLIVASAL

1

5

HYDRO

30

89

PALLIVASAL

2

5

HYDRO

30

1

89

PALLIVASAL

3

5

HYDRO

30

1

89

PALLIVASAL

4

7.5

HYDRO

89

PALLIVASAL

5

7.5

HYDRO

89

PALLIVASAL

6

7.5

HYDRO

90

PORINGALKUTTU

0

32

HYDRO

90

PORINGALKUTTU

1

8

HYDRO

90

PORINGALKUTTU

2

8

HYDRO

90

PORINGALKUTTU

3

8

HYDRO

90

PORINGALKUTTU

4

8

HYDRO

91

PORINGALKUTTU L

0

16

HYDRO

91

PORINGALKUTTU L

1

16

HYDRO

92

PANNIAR

0

30

HYDRO

92

PANNIAR

1

15

HYDRO

92

PANNIAR

2

15

HYDRO

93

KALLADA

0

15

HYDRO

93

KALLADA

1

7.5

HYDRO

93

KALLADA

2

7.5

HYDRO

0

3.75

HYDRO

94

CHEMBUKADAVU-II

263

272

229

195

232

165

117

156

192

222

173

190

122

229

53

29

78

0

1

181

169 169

168

122

78

76

69

67

35

36

0

0

0

0

141 71

1

75

6

94

CHEMBUKADAVU-II

1

1.25

HYDRO

2

1

94

CHEMBUKADAVU-II

2

1.25

HYDRO

2

1

94

CHEMBUKADAVU-II

3

1.25

HYDRO

2

1

95

URUMI-I

0

3.75

HYDRO

95

URUMI

1

1.25

HYDRO

1

1

95

URUMI

2

1.25

HYDRO

1

1

0

0

0

0

3

CDM-SSC-PDD (version 02) CDM – Executive Board

page 37

95

URUMI

3

1.25

HYDRO

96

MANIYAR

0

12

HYDRO

1

96

MANIYAR

1

4

HYDRO

96

MANIYAR

2

4

HYDRO

96

MANIYAR

3

4

HYDRO

97

KUTHUNGAL

0

21

HYDRO

97

KUTHUNGAL

1

7

HYDRO

12

1

97

KUTHUNGAL

2

7

HYDRO

12

1

97

KUTHUNGAL

3

7

HYDRO

12

1

98

KUNDAH I-V

0

555

HYDRO

98

KUNDAH-I

1

20

HYDRO

98

KUNDAH-I

2

20

HYDRO

98

KUNDAH-I

3

20

HYDRO

98

KUNDAH-II

4

35

HYDRO

98

KUNDAH-II

5

35

HYDRO

98

KUNDAH-II

6

35

HYDRO

98

KUNDAH-II

7

35

HYDRO

98

KUNDAH-II

8

35

HYDRO

98

KUNDAH-III

9

60

HYDRO

98

KUNDAH-III

10

60

HYDRO

98

KUNDAH-III

11

60

HYDRO

98

KUNDAH-IV

12

50

HYDRO

98

KUNDAH-IV

13

50

HYDRO

98

KUNDAH-V

14

20

HYDRO

98

KUNDAH-V

15

20

HYDRO

99

PARSEN_S VALLE

0

30

HYDRO

99

PARSEN_S VALLE

1

30

HYDRO

100

METTUR DAM

0

240

HYDRO

100

METTUR DAM

1

10

HYDRO

100

METTUR DAM

2

10

HYDRO

100

METTUR DAM

3

10

HYDRO

100

METTUR DAM

4

10

HYDRO

100

METTUR TUNNEL

5

50

HYDRO

100

METTUR TUNNEL

6

50

HYDRO

31

29

23

21

0

33

23

19

1,692

1,336

760

427

64

34

16

18

36

1,559

55 55

704

411

129

181

1

34

333

1

CDM-SSC-PDD (version 02) CDM – Executive Board

page 38

100

METTUR TUNNEL

7

50

100

METTUR TUNNEL

8

50

HYDRO HYDRO

101

PERIYAR

0

140

HYDRO

101

PERIYAR

1

35

HYDRO

101

PERIYAR

2

35

HYDRO

101

PERIYAR

3

35

HYDRO

101

PERIYAR

4

35

HYDRO

102

KODAYAR-I&II

0

100

HYDRO

102

KODAYAR-I

1

60

HYDRO

102

KODAYAR-II

2

40

HYDRO

103

SHOLAYAR I&II

0

95

HYDRO

103

SHOLAYAR -I

1

35

HYDRO

103

SHOLAYAR -I

2

35

HYDRO

103

SHOLAYAR-II

3

25

HYDRO

104

PYKARA

0

58.95

HYDRO

104

PYKARA

1

6.65

HYDRO

104

PYKARA

2

6.65

HYDRO

104

PYKARA

3

6.65

HYDRO

104

PYKARA

4

11

HYDRO

104

PYKARA

5

14

HYDRO

104

PYKARA

6

14

HYDRO

105

ALIYAR

0

60

HYDRO

105

ALIYAR

1

60

HYDRO

106

SARKARPATHY

0

30

HYDRO

106

SARKARPATHY

1

30

HYDRO

107

PAPANASAM

0

28

HYDRO

107

PAPANASAM

1

7

HYDRO

107

PAPANASAM

2

7

HYDRO

107

PAPANASAM

3

7

HYDRO

107

PAPANASAM

4

7

HYDRO

108

MOYAR

0

36

HYDRO

108

MOYAR

1

12

HYDRO

108

MOYAR

2

12

HYDRO

108

MOYAR

3

12

HYDRO

485

457

226

212

491

310

215

149

140

204

382

259

318

198

349

347

381

253

140

217

183

121

107

86

161

156

150

97

150

115

124

98

65

47

88

147

163

104

53

90

CDM-SSC-PDD (version 02) CDM – Executive Board

page 39

109

SURULIYAR

0

35

HYDRO

109

SURULIYAR

1

35

HYDRO

110

SERVALAR

0

20

HYDRO

110

SERVALAR

1

20

HYDRO

111

0

120

HYDRO

1

15

HYDRO

2

15

HYDRO

3

15

HYDRO

4

15

HYDRO

5

15

HYDRO

6

15

HYDRO

7

15

HYDRO

111

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

8

15

HYDRO

112

VAIGAI DAM

0

13.5

HYDRO

112

VAIGAI DAM

1

3

HYDRO

112

VAIGAI DAM

2

3

HYDRO

112

SATHNUR DAM

3

7.5

HYDRO

113

KADAMPARI

0

400

HYDRO

113

KADAMPARI

1

100

HYDRO

113

KADAMPARI

2

100

HYDRO

113

KADAMPARI

3

100

HYDRO

113

KADAMPARI

4

100

HYDRO

111 111 111 111 111 111 111

93

87

75

41

101

34

24

19

19

33

428

367

167

0

254

78

64

27

16

86

186

162

202

406

256

48

CDM-SSC-PDD (version 02) CDM – Executive Board

page 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

2001-02

2002-03

2003-04

2004-05

128,796

131,747

136,742

138,153

143,932

120,964

123,468

127,617

128,032

134,551

24,193

24,694

25,523

25,606

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 Board

page 41

Appendix 2 PROJECT CASH FLOW

CDM-SSC-PDD (version 02) CDM – Executive Board

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

page 42

CDM-SSC-PDD (version 02) CDM – Executive Board

page 43

CDM-SSC-PDD (version 02) CDM – Executive Board

page 44

CDM-SSC-PDD (version 02) CDM – Executive Board

page 45