jindal aluminium ltd. wind power

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PROJECT DESIGN DOCUMENT FORM (CDM-SSC-PDD) - Version 03

CDM Executive Board

CLEAN DEVELOPMENT MECHANISM

PROJECT DESIGN DOCUMENT FORM (CDM-SSC-PDD)

Version 03 - in effect as of: 22 December 2006

CONTENTS

A. General description of the small scale project activity

B. Application of a baseline and monitoring methodology

C. Duration of the project activity / crediting period

D. Environmental impacts

E. Stakeholders comments

Annexes

Annex 1: Contact information on participants in the proposed small scale project activity

Annex 2: Information regarding public funding

Annex 3: Baseline information

Annex 4: Monitoring Information


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Revision history of this document

VersionNumber

Date Description and reason of revision

01 21 January

2003

Initial adoption

02 8 July 2005 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

.

03 22 December

2006 The Board agreed to revise the CDM project design

document for small-scale activities (CDM-SSC-PDD), taking

into account CDM-PDD and CDM-NM.
http://cdm.unfccc.int/Reference/Documentshttp://cdm.unfccc.int/Reference/Documents


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SECTION A. General description of small-scale project activity

A.1 Title of the small-scale project activity:

>>

8.5 MW wind power project in Chitradurga district in Karnataka by Jindal Aluminium Ltd.

Version1.1 25th

March 2007

A.2. Description of the small-scale project activity:

>>

The project activity involves the implementation of a total of 8.5 MW capacity wind turbines at

Chitradurga District, Karnataka. This project is promoted by M/s Jindal Aluminium Limited (JAL), based

in Bangalore, Karnataka.

JAL is the largest producer of Aluminium Extrusion components in India, and has been in operation for

over 35 years. JAL was promoted by Dr.S.R.Jindal who has over 50 years experience in the industry

including 36 years in aluminium extrusion industry and 10 years in wind energy sector.

JAL has been one of the pioneers in utilizing renewable energy resources for its operations. With acute

power shortages in Karnataka, JAL stepped in to ease the situation with alternate non-conventional

renewable energy source- wind energy. JAL established its first wind power project in 1997 and meets a

majority of its requirements through the wind power it generates. It is exporting the entire electricitygenerated from its newer wind power projects (established after 2002) to the grid.

The objective for the project under consideration is generation of electricity from renewable wind energy,

resulting in addition of capacity to the grid and displacing an equivalent amount of fossil fuel based

electricity generation. The electricity generated from this project activity is supplied to common local

substation through local transmission lines duly metered at developers end.

The project activity comprises of supply, erection, commissioning and operation of 11 numbers of

Enercon 600 kW rated Wind Turbine Generators (WTG) and 2 numbers of 950 KW WTG from NEG

Micon. The project is guaranteed to generate a maximum annual output of 22.1 GWh of electricity.

The project contributes to sustainability in many ways

1. The reduction of emission due to the prevention of the use of fossil fuel for the generation of

power


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Andhra Pradesh

The first site is near Nandana Hosura, H.D. Pura & Thalya Village, Holalkere Taluk, District of

Chitradurga. This site consists of 11 WTG of 600KW each, manufactured by Enercon limited.

The second site is located at G.R. Halli and Kunchiganal Villages, Chitraduga Taluk, Chitradurga

District. This site consists of 2 WTG of 950 KW each, manufactured by NEG Micon.

Karnataka

Tamil Nadu

NH4

Site 2


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A.4.2. Type and category(ies) and technology/measure of the small-scale project activity:

>>

The project generates a total of 8.5 MW, within the qualification criteria of 15 MW for small scale

projects. Being a renewable energy project, there is no project emissions, hence it qualifies under the

criterion for small scale projects.

The project generates electricity through the use of renewable energy, which places it under Type I

according to the Appendix B of the small scale CDM project activities. As the project is exporting the

entire electricity generated to the grid, it falls under the category ID. The applicable methodology is AMSID, Renewable electricity generation for a grid.

Project Site 1.

The Project Activity at the first site consists of 11 numbers of Enercon made 600 kW rated WTG with

internal electrical lines connecting the projects with local evacuation facility.

The WTGs generates 3-phase power at 440 V, which is stepped up to 33 KV. The turbines operate as

base load units and can operate in the frequency range of 47.551.5 Hz and in the voltage range of 400 V

12.5%. PPAs for 10 years term extendible by another 10 years with mutual consent with KarnatakaPower Transmission Corporation Limited have been agreed upon.

The other salient features of the WTGs are:

Gearless Construction - Rotor & Generator Mounted on same shaft eliminating the Gearbox.

Variable Speed function ensuring optimum efficiency at all times, having speed range of 18 to 33

RPM.

Variable Pitch functions ensuring maximum energy capture.

Minimum drawl (less than 1% of kWh generated) of Reactive Power from the grid. No voltage peaks at any time.

Three Independent Braking System.

Incorporates lightning protection system, which includes blades.

Project Site 2

The second project site has 2 numbers of NEG Micon made 950 KW rated WTG. The WTGs have a

rotor diameter of 54 meter installed on 55 meter high steel tubular towers. They operate as base load

units. PPAs for 10 years term extendible by another 10 years with mutual consent with Karnataka PowerTransmission Corporation Limited have been agreed upon. A diagram of the WTG is attached below.


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A.4.3 Estimated amount of emission reductions over the chosen crediting period:

>>

The estimated emission reduction over the 10 year period is 151840 credits

A.4.4. Public funding of the small-scale project activity:

>>

There is no ODA funding being used for the project. The entire project has been funded through a

combination of debt and equity by the project promoters.

A.4.5. Confirmation that the small-scale project activity is not a debundled component of a

large scale project activity:

A small scale project is considered a de-bundled component of a large scale project activity if it meets the

criteria laid down in Paragraph 2 of the Simplified Modalities and Procedures for Small Scale CDM

project activities. A project is considered de-bundled, 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 an technology/measure; and

Registered within the previous 2 years; and

Whose project boundary is within 1 km of the project boundary of the proposed small scale

activity at the closest point.

No other small scale activity meets all the above mentioned criteria. The proposed project activity is,

therefore, not a de-bundled component of a larger project activity


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SECTION B. Application of a baseline and monitoring methodology

B.1. Title and reference of the approved baseline and monitoring methodology applied to the

small-scale project activity:

>>

Approved Small Scale Methodology Type I Renewable Energy Projects

Category I D

Title: Grid Connected Renewable Energy Generation

Reference: AMS I D

Scope I Version 10 (23 December 2006)

B.2 Justification of the choice of the project category:

>>

The project consists of exporting electricity to the Southern grid generated through wind power. As the

project emissions are zero, the emissions reductions is equivalent to the emissions avoided in the baseline

scenario. The baseline is based on the electricity exported to the grid and generation mix for the grid. The

avoided emissions can be measured directly by the quantum of electricity generated and evacuated to the

grid by the project activity. This is monitored by electricity meters at the generation site and at the point

of connection to the grid.

The project activity meets the eligibility criteria to use simplified modalities and procedure for smallscaleCDM project activities as set out in paragraph 6 (c) of decision 17/CP.7. The total installed capacity of

the project is 8.5 MW, which is less than the limit of 15 MW prescribed for small scale project.

Moreover, being a renewable energy project, the project emissions are zero.

B.3. Description of the project boundary:

>>

The project boundary as per AMS ID encompasses the physical, geographical site of the renewablegeneration source.

For the project under consideration, the project boundary will be the 6.6 MW and 1.9 MW project site,

the associated grid connection till the KPTCL substation.


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The emission coefficient can be arrived at by two methods, as follows.

(a) The average of the Approximate Operating Margin and the Build Margin, where:

The Approximate Operating Margin is the weighted average emissions (in tCO2eq./kWh) of all generating

sources serving the system, excluding hydro, geothermal, wind, low-cost biomass, nuclear and solar

generation.

The Build Margin is the weighted average emissions (in tCO2eq./kWh) of recent capacity additions to the

system, which capacity additions are defined as the greater (in MW) of most recent 20% of existing plants or

the 5 most recent plants

OR

(b) The weighted average emissions (in tCO2eq./kWh) of the current generation mix.

The methodology suggests a conservative approach by selecting the lower of the above two options.

The grid under consideration is the entire Southern Grid, consisting of the states of Karnataka, Andhra

Pradesh, Tamil Nadu and Kerala. The regional grid electricity system is a mix of predominantly coal fired

thermal, hydro, wind, natural gas and nuclear. The contribution of solar and biomass based grid supply isnegligible.

Keeping in view of the electricity scenario, the entire Southern region electricity grid system with its

expansion plans, generation and investment trends is considered for identifying the baseline. For this purpose

of baseline calculation, data published by the Central Electricty Authority and the power ministry has been

used. Since, collecting heat rates for all baseline power generating stations is difficult, only net heat rates as

specified by the CEA are considered. This is conservative and reasonable for a small-scale project activity

whose generation is negligibly small compared to the total generation of the grid system

The details of the baseline calculation are provided in Appendix 3

B.5. Description of how the anthropogenic emissions of GHG by sources are reduced belowthose that would have occurred in the absence of the registered small-scaleCDM project activity:

According to the Attachment A to Appendix B, project participants are to provide an explanation to show

that the project activity would not have occurred anyway due to at least one of the following barriers:


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Most of their activities revolve around charity and social benefits. The factory premises provide housing

facilities for the workers, schools and hospitals for employees and local residents.

The interest in renewable energy is primarily driven by the chairman of the company Dr. S. R. Jindal. The

first captive wind power facility was established in 1997, with a capacity of 4.14 MW. This was one of

the first commercial wind power project set up in Karnataka, and JAL took substantial risk in setting up

this project. This project (not part of the projects under consideration in this document as it was

established prior to the year 2000), provides captive power to the plant operations and meets 65% of itscurrent requirement. At the time of installation of the captive wind project, its capacity was sufficient to

meet the entire requirements of the plant.

Investment Barriers

Return on investment

JAL put in the required investment based on a PLF of 28% for the duration of the project. A PLF of 28%entailed a IRR on equity of 24%. However, the operation in the past two years has shown an average PLF

of only 23%, a drop of around 18%. This variation is substantially more than what can be accounted for

in the normal project risk.

Investment Options to JAL

With wheeling and banking charges making captive wind power projects financially unviable, no further

expansion happened until the year 2002. In the year 2002, multiple projects were under consideration forinvestment. Amongst the projects considered were core to the activities of JAL. They included

1. Ductile Iron pipe manufacturing plant

2. Integrated steel plant

Both these projects are core to the skill sets of the company and offered a lower risk investment

proposition to the company. The existing consumer base built over 35 years of operation and the booming

Indian economy was a strong case for investments in these projects.

However, the focus of the chairman of JAL towards renewable energy tilted the decision to go in for

further investments in wind energy. The evidence for the push towards renewable energy is provided by

the following:

1. The PPA provides highly unfavorable sharing of carbon revenues between JAL and KPTCL. Inspite of

the unfavorable potential of carbon revenues, JAL decided to go ahead with the projects.

2 The company has availed the benefits of depreciation on windmill projects spread over a period of 4


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JAL has been a pioneer in promoting wind power projects, and has even taken legal recourse against the

increasingly unfavorable climate to renewable energy projects. For example, the applicable wheeling

charges were increased from 2% at the time the first project was set up in 1997 to 20% by 2001. The tariff

structure offered by KPTCL over the years shows an unfavorable trend towards renewable energy

projects. For example, for PPAs filed on or after 10 June 2004 (Source: KERC Order dated 18 January

2005), the tariff for wind energy projects is set at Rs. 3.40 per kWh without any escalation for the 10-year

period from the date of commercial operation of the plant. As compared to this, projects prior to this

period were entitled to a 5% escalation on a base of 3.25 per KWh.

Effect of weather conditions on the generation from renewables

Renewable energy in the Southern part of India, specially Hydro and Wind is heavily dependent on the

monsoon situation. There are no perennial rivers for hydro power projects and the wind density is highest

only during the monsoons. The lack of proper monsoon rainfall affects both the Hydro and wind power

projects severely. Continuous droughts over three years led to a drop in output from renewable energy

projects in the entire Southern region, including Karnataka. This affects the Wind projects as they aresmaller in size and the reduced generation affects the projected income

Karnataka State

0

2

4

6

8

10

12

14

16

2001 2002 2003 2004 2005

Year

GWh('000)

Fossil fuel

Renewable

B.6. Emission reductions:


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Data / Parameter: BEy

Data unit: tCO2e

Description: Baseline Emissions

Source of data used: Not Applicable

Value applied: Calculated

Justification of the

choice of data ordescription of

measurement methods

and procedures actually

applied :

Any comment:

Data / Parameter: EFy

Data unit: tCO2/MWh

Description: Emission Factor for the grid under consideration

Source of data used: Calculated from Publicly available data

Value applied:


choice of data or

description of

measurement methodsand procedures actually

applied :

Any comment:

Data / Parameter: EF_OMy

Data unit: tCO2/MWh

Description: Operating Margin

Source of data used: CalculatedValue applied: Not Applicable


choice of data or

description of

measurement methods


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choice of data or

description of

measurement methods


applied :

Any comment: Generation-weighted average emission factor of the selected representative set

of recent power plants represented by the 5 most recent plants or the most 20%of the generating units built

Data / Parameter: Fi,y

Data unit: Kg (for solid fuel) l (for liquid fuel)

Description: Fuel consumption for the generation plant in consideration

Source of data used: Publicly Available data

Value applied:Justification of the

choice of data or

description of

measurement methods


applied :

Any comment:

Data / Parameter: COEFi

Data unit: Number

Description: The associated carbon coefficient of the fossil fuel i consumed in the grid.

Source of data used:

Value applied:


choice of data ordescription of

measurement methods


applied :

Any comment:


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applied :

Any comment:

Data / Parameter: OXIDi

Data unit: Number between 0 and 1

Description: Oxidation factor of the fuelSource of data used: default values based on 1996 Revised IPCC Guidelines

Value applied:


choice of data or

description of

measurement methods


applied :Any comment:

Data / Parameter: EFCO2,i

Data unit: gCO2/MJ

Description: CO2 emission factor per unit of energy of the fuel i.

Source of data used:

Value applied:Justification of the

choice of data or

description of

measurement methods


applied :

Any comment:

B.6.3 Ex-ante calculation of emission reductions:

>>


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8 2013-14 17.8 0.853 0 15184

9 2015-16 17.8 0.853 0 15184

10 2017-18 17.8 0.853 0 15184


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B.6.4 Summary of the ex-ante estimation of emission reductions:

>>

Year Annual Estimation of emission

reduction in tonnes of CO2e

Year 1 15184

Year 2 15184Year 3 15184

Year 4 15184

Year 5 15184

Year 6 15184

Year 7 15184

Year 8 15184Year 9 15184

Year 10 15184

Total Estimated reduction over the

crediting period

151840

Crediting period 10

Annual average over the crediting

period

15184

B.7 Application of a monitoring methodology and description of the monitoring plan:

B.7.1 Data and parameters monitored:

(Copy this table for each data and parameter)

Data / Parameter: EGy

Data unit: KWh

Description: Power Generated

Source of data to be

used:

Electronic Measurement at site


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Monitoring methodology is as per approved small scale methodology AMS- ID Version 10 (23 December

2006). Paragraph 13 of the approved methodology mentions Monitoring shall consist of metering theelectricity generated by the renewable technology. In the case of co-fired plants, the amount of biomass and

fossil fuel input shall be monitored

The project consists of exporting electricity to the Southern grid generated through wind power. As the

project emissions are zero, the emissions reductions is equivalent to the emissions avoided in the baseline

scenario. The baseline is based on the electricity exported to the grid and generation mix for the grid. Theavoided emissions can be measured directly by the quantum of electricity generated and evacuated to the

grid by the project activity. This is monitored by electricity meters at the generation site and at the point

of connection to the grid.

The project activity meets the eligibility criteria to use simplified modalities and procedure for smallscale

CDM project activities as set out in paragraph 6 (c) of decision 17/CP.7. The total installed capacity of

the project is 8.5 MW, which is less than the limit of 15 MW prescribed for small scale project.

Moreover, being a renewable energy project, the project emissions are zero.

QA/QC Procedure

The meter readings happen at two levels.

1. The actual generation for each WTG is recorded by the JAL employees at site. This is done by a

manual recording of the daily output. The historical generation data is also recorded by electronic

meters at each WTG.

2. The generation data is also recorded by the O&M teams of the manufacturers at the project site.

3. The data is sent to the Bangalore project office of JAL for consolidation and checks.

4. Invoice based on the meter readings is generated and sent to KPTCL.

5. The amount evacuated to the substation is recorded by KPTCL meters. The difference in readings

is due to T&D losses.

Multiple records and checks are kept in the form of actual amount generated, quantum evacuated at the

substation and the net T&D losses

B.8 Date of completion of the application of the baseline and monitoring methodology and thename of the responsible person(s)/entity(ies)

>>

Baseline and monitoring methodology prepared on 15/11/06

Baseline and monitoring Methodology was prepared by Mr. Monish Das of Amoda Environmental

Solutions Pvt Ltd Bangalore


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C.1.2. Expected operational lifetime of the project activity:

>>

The lifetime of the project is 20 years

C.2 Choice of the crediting period and related information:

C.2.1. Renewable crediting period

C.2.1.1. Starting date of the first crediting period:

>>

Not Applicable

C.2.1.2. Length of the first crediting period:

>>

Not Applicable

C.2.2. Fixed crediting period:

C.2.2.1. Starting date:

>>

15/06/07 or date of registration of the project whichever is later

C.2.2.2. Length:

>>

10 years

SECTION D. Environmental impacts

>>

D.1. If required by the host Party, documentation on the analysis of the environmental impacts

of the project activity:

>>EIA is not required for the project as it does not fall either under Category A or Category B of the MoEF

Notification on Environmental Impact Assessment. Hence no EIA was conducted for the project.

D.2. If environmental impacts are considered significant by the project participants or the host

Party, please provide conclusions and all references to support documentation of an environmental


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Under the govt of India rules for renewable energy projects

1. EIA is not required for the project as it does not fall either under Category A or Category B of the

MoEF Notification on Environmental Impact Assessment. Hence no EIA was conducted for the

project.

2. As the land used for the project comes under the jurisdiction of the Forest department,

Government of Karnataka, the NOC/ Clearance from Zilla Panchayat / Gram Panchayat does notarise.

3. The land is leased in the name of KREDL (Karnataka Renewable Energy Development Limited)

which in turn has sub leased it to Enercon for the implementation of the project.

4. Clearance was obtained both from Ministry of Environment and Forest (Govt. of India) and

Forest Ecology and Environment Department (State govt. of Karnataka) for the land used for

setting up of the wind mill. All relevant documents are provided to the validating authority.

The various stakeholders during the project implementation were.

Stakeholder Name Function

KREDL (Karnataka Renewable Energy

Development Limited)

http://www.kredl.kar.nic.in/

Organization devoted entirely to the promotion of

non-conventional energy sources in Karnataka. The

company advises the Government of Karnataka on

policies to be adopted for ensuring a systematic and

balanced growth of projects for harnessing

renewable energy sources.

MoEF (Ministry of Environment and Forest, Govt.

of India)

http://Moef.nic.in

The ministry of environment and forest of the Govt

of India is responsible for environmental well being

and overseeing all activities on forest land.

Forest Ecology and Environment, Govt. of

Karnataka state

http://parisara.kar.nic.in/

State level body for overseeing all environment and

ecology functions

E.2. Summary of the comments received:
http://www.kredl.kar.nic.in/http://moef.nic.in/http://parisara.kar.nic.in/http://parisara.kar.nic.in/http://moef.nic.in/http://www.kredl.kar.nic.in/


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There were no adverse comments on the projects hence no action was required.


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Annex 1

CONTACT INFORMATION ON PARTICIPANTS IN THE PROJECT ACTIVITY

Organization: Jindal Aluminium Limited

Street/P.O.Box: Jindal Nagar

Building: Tumkur Road

City: BangaloreState/Region: Karnataka

Postfix/ZIP: 560073

Country: India

Telephone: +91 80 23715555

FAX: +91 80 23713333

E-Mail:

URL: www.jindalaluminium.com

Represented by:Title: GM (Corporate Affairs)

Salutation: Mr.

Last Name: Mayurnath

Middle Name:

First Name: Ravindranath

Department:

Mobile:

Direct FAX:Direct tel:

Personal E-Mail: [email protected]


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Annex 2

INFORMATION REGARDING PUBLIC FUNDING

No public funding was availed for this project.


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Annex 3

BASELINE INFORMATION

As per AMS I.D, the baseline emissions are calculated as the net electricity generated by the project activity, multiplied with the baseline emission factor for

the project grid derived in Section B.2:

BEy =EGy xEFy

where:

BEy Baseline emissions in year y (t CO2)

EGy Net electricity generated by the project activity (GWh)

EFy Baseline emission factor for the project grid (t CO2/GWh)

The emission factorEFy of the grid is represented as a combination of the Operating Margin and the Build Margin. If we set the emission factor of associated

method asEF_OMy andEF_BMy, theEFy is given by:

EFy = wOM *EF_OMy + wBM *EF_BMy..(1)

with respective weight factors wOM and wBM (where wOM + wBM = 1), and by default, are weighted equally (wOM = wBM = 0.5).

The Operating Margin emission factor

EF_OMy is defined as the generation-weighted average emissions per electricity unit of all generating sources serving the system, including zero- or low-operating cost power plants (hydro, geothermal, wind, low-cost biomass, nuclear and solar generation), based on the latest year statistics data and are derived

from the following equation:

EF_OMy = [iFi,y*COEFi] / [jGENj,y] ..(2)

where

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Fi,y is the fuel consumption

COEFiis the associated carbon coefficient of the fossil fuel i consumed in the grid.

GENj,yis the electricity generation at the plantj connected to the grid excluding zero- or low-operating cost sources.

The CO2 emission coefficient COEFi,j is obtained as:

COEFi,j =NCVi,j* EFCO2,i* OXIDi.(3)

where:

NCVi,jis the net calorific value (energy content) per mass or volume unit of a fuel i,

OXIDiis the oxidation factor of the fuel (default values based on 1996 Revised IPCC Guidelines),

EFCO2,iis the CO2 emission factor per unit of energy of the fuel i.

The build margin emission factor

The Build Margin emission factorEF_BMy is given as the generation-weighted average emission factor of the selected representative set of recent power

plants represented by the 5 most recent plants or the most 20% of the generating units built (summation is over such plants specified by k):

EF_BMy = [iFi,y*COEFi] / [kGENk,y]..(4)

as the default method.

The summation overi and kis for the fuels and electricity generation of the plants mentioned above

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Appendix 3A: Baseline Generation Data used for calcualtion

S_no NameCapacity MW as on

31/03/2005State Type Fuel 1 Fuel 2

2004-05

Net Generation GWH

1 K_gudem 680 Andhra pradesh Thermal Coal Oil 4,919

2 K_gudem new 500 Andhra pradesh Thermal Coal Oil 3,770

3 Vijaywada 1260 Andhra pradesh Thermal Coal Oil 8,926

4 R_gundem - b 62.5 Andhra pradesh Thermal Coal Oil 449

5 Rayal seema 420 Andhra pradesh Thermal Coal Oil 3,078

6 Vijeswaran gt 272.3 Andhra pradesh Thermal Gas Napt 1,940

7 R_gundem stps 2600 Andhra pradesh Thermal Coal Oil 16,038

8 Simhadri 1000 Andhra pradesh Thermal Coal Oil 7,663

9 Jegurupadu gt 235.4 Andhra pradesh Thermal Gas N/a 1,392

10 Godavari gt 208 Andhra pradesh Thermal Gas N/a 1,344

11 Kondapalli gt 350 Andhra pradesh Thermal Gas Napt 2,179

12 Lvs power dg 36.8 Andhra pradesh Thermal Diesel N/a 0

13 Peddapuram ccgt 220 Andhra pradesh Thermal Gas N/a 1,142

14 Raichur 1470 Karnataka Thermal Coal Oil 9,799

15 Yelhanka (dg) 127.92 Karnataka Thermal Diesel N/a 262

16 Kaiga 440 Karnataka Nuclear Nuclear 2,60817 Torangallu imp 260 Karnataka Thermal Coal Oil/corex 1,841

18 Bellary dg 25.2 Karnataka Thermal Diesel N/a 39

19 Tanir bavi 220 Karnataka Thermal Gas Napt 630

20 Belgaum dg 81.3 Karnataka Thermal Diesel N/a 240

21 Bramhapuram dg 106.5 Kerala Thermal Diesel N/a 252

22 Kojikode dg 128 Kerala Thermal Diesel N/a 152

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23 Cochin ccgt 174 Kerala Thermal Napt Diesel 108

24 Kasargode dg 21.9 Kerala Thermal Diesel N/a 15

25 Kayam kulam gt 350 Kerala Thermal Gas Napt 602

26 Ennore 450 Tamil nadu Thermal Coal Oil 1,041

27 Tuticorin 1050 Tamil nadu Thermal Coal Oil 7,539

28 Mettur 840 Tamil nadu Thermal Coal Oil 6,128

29 North chennai 630 Tamil nadu Thermal Coal Oil 3,560

30 Basin bridge gt 120 Tamil nadu Thermal Napt 39

31 Valuthur gt 94 Tamil nadu Thermal Gas N/a 526

32 Kuttalam gt 100 Tamil nadu Thermal Gas N/a 605

33 B. Bridge d.g 200 Tamil nadu Thermal Diesel N/a 763

34 Kovilkalappal 107 Tamil nadu Thermal Gas N/a 717

35 P.nallur ccgt 330.5 Tamil nadu Thermal Gas Napt 462

36 Samalpatti dg 105.7 Tamil nadu Thermal Diesel N/a 345

37 Samayanallur dg 106 Tamil nadu Thermal Diesel N/a 369

38 Karuppur gt (aban) 70 Tamil nadu Thermal Gas N/a

39 Neyveli st i 600 Tamil nadu Thermal Lign Oil 3,773

40 Neyveli st ii 1470 Tamil nadu Thermal Lign Oil 8,344

41 Neyveli fst ext 420 Tamil nadu Thermal Lign Oil 2,945

42 Neyveli tps(z) 250 Tamil nadu Thermal Lign Oil 1,246

43 M.a.p.p. 390 Tamil nadu Nuclear Nuclear 1,300

44 Karaikal 32.5 Pondichery Thermal Gas N/a 260

45 Machkund 114.75 Andhra pradesh Hydro 895

46 Upper sileru i&ii 240 Andhra pradesh Hydro 541

47 Lower sileru 460 Andhra pradesh Hydro 1,16548 Nagarjuna sagar 815.6 Andhra pradesh Hydro 501

49 N_sagar rbc & extn. 90 Andhra pradesh Hydro 48

50 N_sagar lbc 60 Andhra pradesh Hydro 5

51 Donkarayi 25 Andhra pradesh Hydro 132

52 Srisailam 770 Andhra pradesh Hydro 935

53 T.b. Dam 36 Andhra pradesh Hydro 148

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54 Pochampad 27 Andhra pradesh Hydro 0

55 Nizam sagar 10 Andhra pradesh Hydro 0

56 Penna ahobelam 20 Andhra pradesh Hydro 0

57 Singur 15 Andhra pradesh Hydro 1

58 Srisailam lbph 900 Andhra pradesh Hydro 1,404

59 Sharavathy 1006.2 Karnataka Hydro 3,836

60 Kalinadi 855 Karnataka Hydro 1,712

61 Kalinadi supa 100 Karnataka Hydro 293

62 Liganamakki 55 Karnataka Hydro 193

63 Varahi 230 Karnataka Hydro 968

64 Bhadra 39.2 Karnataka Hydro 43

65 Ghat prabha 32 Karnataka Hydro 96

66 Mani dph 9 Karnataka Hydro 22

67 Mallarpur 9 Karnataka Hydro 0

68 Sharavathy tail race 240 Karnataka Hydro 435

69 Kadra 150 Karnataka Hydro 231

70 Kodasali 120 Karnataka Hydro 215

71 Almatti dam 180 Karnataka Hydro 139

72 Jog 139.2 Karnataka Hydro 172

73 Sivasamundrum 42 Karnataka Hydro 193

74 Shimsapura 17.2 Karnataka Hydro 94

75 Munirabad 28.3 Karnataka Hydro 69

76 Shivapura 18 Karnataka Hydro 71

77 Shahpur 6.6 Karnataka Hydro 24

78 Madhavamantri 4.5 Karnataka Hydro 2379 Narayanpur 11.6 Karnataka Hydro 43

80 Kuttiadi & extn. 125 Kerala Hydro 369

81 Idukki 780 Kerala Hydro 1,993

82 Sabarigiri 300 Kerala Hydro 1,218

83 Idamalayar 75 Kerala Hydro 335

84 Lower periyar 180 Kerala Hydro 511

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85 Kakkad 50 Kerala Hydro 210

86 Sholayar 54 Kerala Hydro 263

87 Sengulam 48 Kerala Hydro 165

88 Narimanglam 45 Kerala Hydro 232

89 Pallivasal 37.5 Kerala Hydro 222

90 Poringalkuttu 32 Kerala Hydro 181

91 Poringalkuttu l 16 Kerala Hydro 169

92 Panniar 30 Kerala Hydro 141

93 Kallada 15 Kerala Hydro 75

94 Chembukadavu-ii 3.75 Kerala Hydro 6

95 Urumi-i 3.75 Kerala Hydro 3

96 Maniyar 12 Kerala Hydro 34

97 Kuthungal 21 Kerala Hydro 36

98 Kundah i-v 555 Tamil nadu Hydro 1,559

99 Parsen_s valle 30 Tamil nadu Hydro 55

100 Mettur dam 240 Tamil nadu Hydro 333

101 Periyar 140 Tamil nadu Hydro 491

102 Kodayar-i&ii 100 Tamil nadu Hydro 204

103 Sholayar i&ii 95 Tamil nadu Hydro 349

104 Pykara 58.95 Tamil nadu Hydro 217

105 Aliyar 60 Tamil nadu Hydro 161

106 Sarkarpathy 30 Tamil nadu Hydro 115

107 Papanasam 28 Tamil nadu Hydro 88

108 Moyar 36 Tamil nadu Hydro 90

109 Suruliyar 35 Tamil nadu Hydro 101110 Servalar 20 Tamil nadu Hydro 33

111 Lower mettur 120 Tamil nadu Hydro 254

112 Vaigai dam 13.5 Tamil nadu Hydro 86

113 Kadampari 400 Tamil nadu Hydro 256

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Annex 4

MONITORING INFORMATION

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