jindal aluminium ltd. wind power
TRANSCRIPT
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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:
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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:
Justification of the
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
Justification of the
choice of data or
description of
measurement methods
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Justification of the
choice of data or
description of
measurement methods
and procedures actually
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
and procedures actually
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:
Justification of the
choice of data ordescription of
measurement methods
and procedures actually
applied :
Any comment:
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and procedures actually
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:
Justification of the
choice of data or
description of
measurement methods
and procedures actually
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
and procedures actually
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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