AUROBINDO AGRO ENERGY PRIVATE LIMITED. 21 … · The 21 MW grid connected biomass based power plant has been implemented ... (TNEB) grid based on a 15 year Power ... thermal power

PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 02 CDM – Executive Board page 1

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CLEAN DEVELOPMENT MECHANISM PROJECT DESIGN DOCUMENT FORM (CDM-PDD)

Version 02 - in effect as of: 1 July 2004)

AUROBINDO AGRO ENERGY PRIVATE LIMITED.

21 MW GRID CONNECTED ELECTRICITY GENERATION FROM BIOMASS RESIDUES



CONTENTS A. General description of project activity B. Application of a baseline methodology C. Duration of the project activity / Crediting period D. Application of a monitoring methodology and plan E. Estimation of GHG emissions by sources F. Environmental impacts G. Stakeholders’ comments

Annexes Annex 1: Contact information on participants in the project activity Annex 2: Information regarding public funding Annex 3: Baseline information Annex 4. Monitoring Plan

Annex 5: Biomass Availability Annex 6: Power Scenario in India



SECTION A. General description of project activity A.1 Title of the project activity: 21 MW grid connected biomass based power generation by Aurobindo Agro Energy Pvt.Ltd,

Kalayarkovil, Sivagangai District in TamilNadu.

Version: 1 Date : 08/07/2006 A.2. Description of the project activity:

The 21 MW grid connected biomass based power plant has been implemented by Aurobindo Agro

Energy Pvt Ltd. (AAEPL), in Sivagangai district of Tamilnadu,India.The generated green power will be

sold and exported to Tamil Nadu Electricity Board (TNEB) grid based on a 15 year Power Purchase

Agreement (PPA) with TNEB. This biomass based power generation will replace the fossil fuel based

thermal power generation in the southern regional grid. The project activity is proposed to be

implemented in two phases,

Phase- I:

8.5 MW capacity is planned to be commissioned before August 2006.

Phase- II:

Ground work for 12.5 MW capacity has been completed and power generation will be started before

March -2008

The implementation of power generation projects based on biomass in rural areas will create adequate

employment opportunities, additional income generation, awareness and positive impact in the mind of

local people, which in turn will improve life standards of local people.

The following are the main purpose of the project activity:

Contribute to the Sustainable Development through the effective utilization of biomass residues

available in the project region for Power generation, thereby enhancing additional income

through rural employment opportunities in the region.

Climate Change mitigation through the generation of eco-friendly power and reduce the

dependence on fossil fuel based conventional power.

The main objective of project activity is to achieve sustainable development in the rural region by

enhancing four pillars of sustainable development such as:



Social well being

Economic well being

Environmental well being

Technological well being

Social well being

• Social inequalities have been cleared due to the emergence of power plant which provides jobs for both skilled and unskilled labours in the local area.

• The effective collection and utilisation of biomass residues for power generation will give a

social status to the farmers Economic well being

• To construct the power plant a large area has been required so the project promoter purchased wastelands from farmers. The farmers are benefited as they have limited or no use of the wasteland.

• The continuous operation of power plant provides daily employment and regular income for

casual labours near project site.

• The requirement of biomass fuel for power plant will provide regular income for both biomass dealers and owners dealing with biomass transport.

Environmental well being CO2 emission from thermal power plants by burning fossil fuel plays a major role in the climate change

alleviation and enhancement of global warming. Aurobindo Agro Energy Pvt.Ltd involved themselves in

environmental friendly power generation sector by using biomass as a prime fuel in their power plant to

generate green power. Combustion of biomass in the proposed project does not result in net increase in

GHG emissions of CO2, CH4 and NOx. While the CO2 forms the major constituent of GHG emissions

with about 98%, CH4 and NOx constitute the remaining 2%. Typical ultimate analysis of biomass

materials indicates the Nitrogen content within 1 to 2%, which is negligible. Hence CO2 is considered as

the only GHG emissions from biomass. However since emissions from biomass is considered CO2 neutral

based on their life cycle emissions analysis, no CO2 emissions is estimated from this project.

Technology Well being



The technology implemented in the project activity is based on combustion of biomass for steam

generation in high temperature and high pressure boiler and generation of power from steam turbine

based on Rankine cycle technology. Some of the benefits due to implementation of technology are

explained below :

• Reduce specific water consumption

• As this technology is well improved there will be a consistent operation of power plant which

gives confidence to employees working at site.

• All the grid connected biomass based power projects in India are based on the biomass

combustion boiler and Rankine cycle, a highly advanced and state-of-art technology. Hence

considerable operational experience is available in the country and the access to the technology

has been well established.

• In sharp contrast to fossil fuels and most of the other renewable energy sources, the local

harvesting and utilisation of biomass and its local conversion into electricity and energy creates

local value addition most of which stays in the local economy and contributes to poverty

reduction

• The plant’s operation and maintanence requirements are not so complex. Hence even local skills

can also get an opportunity to operate the plant, which is additional benefit for people in local

area of project activity.

A.3. Project participants: Name of party involved ((host) indicates a host party)

Private and/or Public entity (ies) project

participants

Kindly indicate if the Party involved wishes to be considered as project

participant Ministry of Environment and Forest, Government of India

(host)

Aurobindo Agro Energy Private Limited

No

A.4.Technical description of the project activity:



A.4.1. Location of the project activity: A.4.1.1.Host Party (ies): India A.4.1.2.Region/State/Province etc.: Tamilnadu A.4.1.3.City/Town/Community etc: Virgadi Kadambangulam Village, Kalayarkoil Taluka, Sivagangai District. A.4.1.4.Detail of physical location, including information allowing the unique identification of this project activity (maximum one page):

The project site is physically located at Sivagangai District, Tamilnadu. The state highway is 2.5 km from

the plant site.Sivagangai Railway Station is about 16 kms.The nearest airport is Madurai and is about 60

kms from project site. The site is located at 78 °5 ‘E longitude and 9° 2 ‘N latitude

The project location is shown below:

o India Map

o Tamilnadu Map

o District Map



Tamilnadu

Sivagangai District



o District Map

Sivaganga Taluka

A.4.2. Type and Category (ies) of project activity: The project falls under the UNFCCC large scale CDM project activity categories under Approved

consolidated baseline methodology ACM0006, “Consolidated baseline methodology for grid-

connected electricity generation from biomass residues”. This is a grid connected biomass power

project of more than 15 MW and less than 60 MW capacity .The power generated by the project activity

is directly exported to the southern regional grid which is currently fed and dominated by fossil fuel based

power plants.



A.4.3. Technology to be employed by the project activity: The Rankine Cycle technology is implemented in this 21 MW biomass based power plant. It is a proven

technology for high-pressure steam generation based on direct combustion and single extraction

condensing turbine for power generation. A brief description regarding the technology is as follows.

Rank The Ran

heated turbine. The turbine drives a

gen

feed-wa

ine Cycle:

kine cycle is a thermodynamic cycle used to generate electricity in many power stations. Super-

steam is generated in a boiler, and then expanded in a steam

erator, to convert the work into electricity. The remaining steam is then condensed and recycled as

ter to the boiler. Chemically treated water will be used in the boilers.

Figure: Components of Rankine Cycle The project is designed as a cleaner energy generation project. The technology employed is the

indigenous developed state-of-art direct combustion boiler for high pressure steam generation and high

pressure condensing steam turbine for power generation. The unique feature of the project in this region

is that it also employs an air cooled condenser in the place of the water cooling towers. Other features

f the technology are provided below: o



The pro phase-I is 8.5 MW

whic consists o one 33 T W s e. T oning date

of Phase-I will be August 2006. The installed capacity of phase-II is 12.5 MW which consists of one

47.32 TPH steam generator with one 12.5 MW steam tu The co oning -II will be

March 2008.

The s enerator proposed u t will b ker fire ral circul o drum

balanced draft type and deliver super heated s 65 bar 485 °C supplied

with ter at a ure of .

Rene ass as a f trave e combustion steam generator to produce

high-pressure steam in urbine ate power

The urbine w of t omp enerat densing horizontally split

double casing machine with one uncontrolled extraction for feed heating in the deaerator.

T am at HP Turbine inlet will be at 0 °C a xhaust fro urbine is

0.180 a

thropogenic emissions of anthropogenic greenhouse gas

ject activity has been implemented in two phases. The installed capacity of

h f PH steam generator with one 8.5 M team turbin he commissi

date of Phaserbine. mmissi

team g for the ni e of sto d , natu ation ,tw

team at (a) and ,when

feed wa temperat 105 °C

wable biom is burnt uel in a lling grat

, which is then expanded a steam t to gener .

steam t ould be andem c ound, reg ive, con

he main ste 63 ata, 48 nd the e m the t

condensed in the air cooled condenser, which is maintained at a pressure ta

A.4.4. Brief explanation of how the an(G proposed CDM project activityHGs) by sources are to be reduced by the , including why the emission reductions would not occur in the absence of the proposed project activity, taking into account national and/or sectoral policies and circumstances: Biomass fuels such as Prosopis Juliflora and other agricultural residue like Eucalyptus Wood, Coconut

esidues, Chilly Stalks and Sugarcane Trash are utilised for power generation in the proposed power

moter selected biomass as fuel for their power

lant mainly due to its resultant neutral anthropogenic green house gas emissions. According to the

filling

ower demand. The power generation through thermal power plants by utilising fossil fuel results in CO2

DM project activity, the power

will result in generation of greenhouse gas

A.4.4.1.Estimated amount of emission reductions over the chosen crediting period

R

plant of Aurobindo Agro Energy Pvt Ltd. The project pro

p

current scenario in India the fossil fuel based thermal power plants are playing major role in ful

p

emission which leads to global warming. In the absence of proposed C

generated from the fossil fuel based southern regional grid

emissions.

:



Emission reductions of the proposed project during the crediting period

Base line Emission tCO2/year

S.No

Year

Phase-I 8.5 MW

Phase-II 12.5 MW

Total 21 MW

Project emission

tCO2

Emission reductions tCO2/year

1 2006 20,697 0 20,697 6,321 14,3762 2007 57,557 0 57,557 17,578 39,9793 2008 57,557 60,873 118,430 36,169 82,2614 2009 57,557 84,643 142,200 43,428 98,7715 2010 57,557 84,643 142,200 43,428 98,7716 2011 57,557 84,643 142,200 43,428 98,7717 2012 57,557 84,643 142,200 43,428 98,7718 2013 57,557 84,643 142,200 43,428 98,7719 2014 57,557 84,643 142,200 43,428 98,77110 2015 57,557 84,643 142,200 98,77143,428

T 53 3,371 1,192,081 828,01otal 8,710 65 364,066 5Total estimated emission reductions (tons of CO2) 828, 015Tota credi 10l number of ting years Annual average over the crediting period of es ction timated redu s (tons of CO2/year) 82,801

A.4.5. Public funding of the project activity: There is no public fundin roject a

g availed for the p ctivity.

SECTION B. Application of a baseline methodology B.1.Title and reference of the approved baseline methodology applied to the project activity: The ap aseline m for th t activit Appro lidated y A “Consolidated baseline m biomass residues” – Version 03, Sectoral Scope : 01, dated 19 May 2006 B.1.1. Justification of the choice of the methodology and why it is applicable to the project

proved b

ved conso

ethodology applied

baseline methodolog

ethodology for grid-connected electricity generation from

is projec

CM0006

y is:

1

activity:

1 http://cdm.unfccc.int/methodologies/DB/IAB80AE6G21VF0PU9OLLX389DXMCMX/view.html



The project activity is implementation of a grid connected 21 MW biomass based power plan

nerated electricity is exported to the southern regional grid. The fuel used for this power plant is

t. The

ge CO2

eutral renewable biomass residues. The methodology used for this project activity is ACM0006,

generation project activities

is project activity is a Greenfield power project

n

“Consolidated baseline methodology for grid-connected electricity generation from biomass

residues” and this is the most appropriate methodology available in the UNFCCC for grid-connected

biomass residue fired electricity

The methodology is applicable for this project under the following conditions:

The project activity is a new biomass power plant at a site where currently no power generation

occurs .So th

Baseline scenario Scenario Project type Power

generation Use of biomass Heat generation

As per the Installation of a new The The biomass is used

ACM0006 biomass power

ntly no

generation of

existing

power

for power generation,

cogeneration, in other

-

(Scenario-1) generation plant at a

site where curre

power in including

power generation

occurs (Greenfield

projects )

and/or new

grid-

connected

existing or new grid

connected

power plants1(B3)

plants(P4)

As per the

Project

The project activity is a The proposed The biomass has

Activity

new biomass power

plant at a site where

project

activity is a

prior to the project

implementation been

generation with that -

currently no power

generation occurs .So

this project activity is a

21 MW new

grid

connected

sold in a market and

where electricity

Greenfield power biomass biomass type is

project power project common practice.



• No other biomass types than biomass residues are used in the project plant and these biomass

r

The pre this project activity are prosopis juliflora from waste land and other

agri

coal.

For projects that use biomass residues from a production process (e.g. production of sugar or wood

pan

capacity of raw input (e.g. sugar, rice, logs, etc.) or in other substantial changes (e.g. product change)

in t

This Pr wer plant. The biomass residues used in this project

ctivity are prosopis juliflora and other agricultural residue coming from the nearby area and market.

The biomass used by the project facility should not be or mor

Biomass used for this pr l not be stored

for more than one year w

No sig gy q to prep e the

biomas r bu r pro iomass residues prior to

combustion (e.g.esterification of waste oils) are no der

The major biomass used Prosopis juliflora and other agricultural residues. There

is no significant energy portation of the biomass, are required to prepare this

biomass residues.

“Scen t invol s the

installa ew pow ower er

generated by the project

Description of how the methodology is applied in the context of the project activity

esidues are the predominant fuel used in the project plant (some fossil fuels may be co-fired);

dominant fuels used for

cultural residue (Annexure V) available in this region. The project will also co-fire fossil fuel namely

el boards), the implementation of the project shall not result in an increase of the processing

his process;

oject activity is an independent biomass po

a

stored f e than one year;

oject is available in this re

ithin the plant.

uantities, except from tran

gion through ou

sportation of the

ojects that

t eligible un

t the year. Biomass wil

biomass, are required

cess the b

nificant ener

s residues fo

ar

fuel com stion, i.e. p

this methodology.

for this project activity is

quantities, except from trans

ield Power Projects” has

er plant at a site where cu

activity is fed into the sout

ario 1-Green F

tion of a n

been applied fo

rrently no p

hern grid.

r the project activity tha

generation occurs. The pow

ve

B.2. : The project activity follows the Scenario 1- Green Field Power Projects of the Table 1 of methodology

ACM0006.




from waste land and

roject will also co-fire

fossil fuel namely coal.

ass residues used in this

The major biomass used for this project activity is Prosopis juliflora and other agricultural

The alternative baseline scenario:

The predominant fuels used for this project activity are prosopis juliflora

other agricultural residue (Annexure V) available in this region. The p

This Project activity is an independent biomass power plant. The biom

project activity are prosopis juliflora and other agricultural residue coming from the nearby area

and market.

Biomass used for this project is available in this region only. Biomass will not be stored for more

than one year within the plant.

residues. There is no significant energy quantities, except from transportation of the biomass, are

required to prepare this biomass residues.

Baseline scenario Scenario Project type Power

generation Use of biomass Heat generation

As per ACM0006 (Scenario-1)

biomass power

power generation field

power in

grid-connected power plants(P4)

for power generation,

existing or new grid connected

ant

-

Installation of a new The generation of The biomass is used

the generation plant at a site where currently no

existing and/or new

including cogeneration, in other

occurs (Greenprojects )

power pl s1(B3)

AsProject

vity is a

power

ant at a site where


Greenfield power

The proposed project

ity is a 21 MW new

biomass power project

The biomass has the ect

implementation been sold in a market and

that

biomass type is common practice.

-

The project acti

new biomass

pl

per the currently no power activ

Activity this project activity is a grid connected

where electricitygeneration with

project

prior to proj



1. How power would be generated i

n the absence of the CDM project activity

2. What would happen to the biomass in the absence of the project activity;

How power would be generated in the absence of the CDM project activity There are five regional grids in India namely, Northern, Western, Southern, Eastern and North Eastern

regions. All the States in India are connected to one of these five regional grids as explained further in the

6. .The southern regional grid supplies electricity for southern states namely Andhra Pradesh,

Karnataka, Kerala, Tamilnadu and one union territory Pondicherry.

The proposed b indo Agro Energy Pvt Ltd. is located in

Sivagangai Dist t of Ta ed electricity to southern regional grid.

According to the current scenario in southern regional grid, the power generation by fossil fuel based

thermal power ence of this project activity the power

tive baseline for this project activity is the generation of power by Fossil fuel based

Annex

iomass based power plant implemented by Aurob

ric milnadu and it will export the generat

plants are dominating the grid. So even in abs

generation would continue to be by fossil fuel based thermal power plants in southern grid and hence the

predominant alterna

thermal power plants.

Type of power plants and their net power generation in 2005-06

Type of Power Plant GWh %

Coal Power Plant 71,364 51.68 Lignite Power Plant 16,072 11.64 Gas Power Plant 10,869 7.87 D esi el Power Plant 1,738 1.26 Hydro Power Plant 33,332 24.14 Nuclear Power Plant 4,713 3.41 Total 1,38,088 100

Reference: CEA web site www.cea.nic.in

What would ass in the absence of the project activity;happen to the biom

The 21 MW po utilizes the biomass available in the local region of

Sivagangai district, Tamilnadu. In absence of this project activity the biomass generated in Sivagangai

district w ricts.

wer plant of AAEPL mainly

ill be utilized by other cogeneration and biomass power plants located in the nearby dist



Hence the biomass generated has prior to the project implementation been sold in a market and where

lectricity generation with thae t biomass.

Baseline emission factor calculation: As described in ACM0006, the emission factor he southern grid sented as a combination

of the Operatin and the Build Margin. sion factor of the ted method is given by:

E = wOM * EF_OMy EF_BMy

Where

ion factor of O

ission factor of Build Margin

wOM - weight factors of Operating Margin

wBM - weight factors of Build Margin

Operating Margin emission factor(s) (EF

EFy of t is repre

g Margin The emis associa

Fy + w *BM

EF_OMy - emiss perating Margin

EF_BMy - em

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

(wOM = wBM = 0.5).

OM)

The Operating Margin emission factor EF_OMy is defined as the generation-weighted average emissions

it (tCO2 / MWh) of all generating sources serving the system, excluding zero- or low-

operating cost power plants (hydro, geothermal, wind, low-cost biomass, nuclear and solar generation),

per electricity un

based on the latest year statistics data (year of 2005-06) and are derived from the following equation:

EF_OMy = ∑

∑=j yj,

iyi,

GEN

EF*Fi

y

y CO

TGENTEM

Where:

TEMy - Total GHG emissions

TGENy – Total electricity generation supplied to the grid excluding zero- or low- operating cost

sources.

Fi,y & COEFi - Fuel consumption and associated carbon coefficient of the fossil

fuel i consumed in the grid.



GENj,y - rid excluding zero- o low-

operating cos

Type of power plant, their generation and Emission in 2005-06 (Southern Grid-Excluding zero and st sources)

ype of power pla Net Generation GWh

Emission ktCO2/year

Electricity generation at the plant j connected to the g r

t sources.

low operating co

T nt

Coal 71,364 79,385 Lignite 16,072 23,092 Gas 10,869 5,808 Diesel 1,738 1,175

Total 100,043 109,460 Operating Margin

emission factor 1.094 TCO2/MWH


Build Margin emission factor (EFBM) The Build Margin emission factor EF_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):

∑

∑=

kykEN

ii

y G

FBMEF

,_

as t The summation ov d k is for the fuels and electricity generation of the plants

men

The of plants group should b esponding with metho CM0002 and A D.

Hen rger annual generation is selected.

The difference between (1) recent power plants represente e 5 m nt plants and (2) st

er plants

yi COEF, *

he default method. er i an

tioned above.

selection e corr dology A MS-I.

ce, the set that comprises the la

d by th ost rece the mo

20% of the generating units built (in GWh) in 2005-06 is shown in below table:

Capacity and Generation deails of five recent pow



.nic.in

Reference: CEA web site www.cea

In 2005-06, et el thern regional grid was 138,088 GWh. 20% of this

generation was 27,617.6 GWh. The generation capacity of the last five power plants was 36,363 GWh.

The total generation capacity of the last five power plants is greater than the 20% of southern grid

enerati n. The her id g The build margin is estimated from the last five

of the year

005-06 shows that out of the last 5 plants, 3 are Coal based and 2 are Gas based, which shows that the

apacity addition to the grid in the is thermal based & these will also contribute to the increasing GHG

Plants Capacity Net Emission Emission

total n ectricity outputs of the Sou

g o sout n gr eneration refer annex 3.

power plants capacity and is estimated to be 1.102 tCO2/MWh. The build margin calculation

2

c

emissions to the environment.

Five most recent plants Generation and CO2 Emission on 2005-06

MW Generation

GWh

factor in T CO2/MWh Kt CO2/year

R'gundam STPS 2,600 18,393 1.1457 21,073Valuthur CCGT 95 676 0.5106 345Raichur 1,470 8,364 1.0854 9,079Peddapuram CCGT 220 817 0.4898 400Simhadri 1,000 7,304 1.1342 8,285

Total 5,385 35,554 39,182


Thus, the “Build Margin” emission factor will be EFBM = 39,182 / 35,554

ed five power plants Details of recently commission

Name Year of Commissioning

Capacity MW Net Generation GWh

R'gundam STPS 2004 2,600 18,393 Valuthur CCGT 2003 95 676 Raichur 2002 1,470 8,364 Peddapuram CCGT 2003 220 817 Simh 2002 1,000 7,304 adri

Total 5,385 35,554

= 1.102 tCO2/MWh



Calculate the baseline emission factor (EF) The baseline emission factor EF is calculated as combination of the Operating Margin emission factor

(EF ) and the Build Margin emission factor (EF ):

EF = w *EF + w *EF

OM BM

OM OM BM BM

Where

The weight factors wOM and wBM (where wOM + wBM = 1), and by default, are weighted equally

EF - 1.094 tCO /MWh

w - 0.5

- 0.5

d below those

(wOM = wBM = 0.5).

OM 2

OM

EFBM - 1.102 tCO2/MWh

wBM

EF = 0.5*1.094 + 0.5*1.102

Baseline emission factor will be (EF) = 1.098 tCO2/MWh

B.3. Description of how the anthropogenic emissions of GHG by sources are reducethat would have occurred in the absence of the registered CDM project activity: Step 0. Preliminary screening based on the starting date of the project activity a) Provide evidence that the starting date of the CDM project activity falls between 1 January 2000 and

he date of the registration of a first CDM project activity, bearing in mind that only CDM project

(

t

activities submitted for registration before 31 December 20005 may claim for a crediting period starting

before the date of registration

e incentive from the CDM was seriously considered in the decision to proceed

ior to, the start of the project

ctivity.

s sufficient evidence available in the form of documentation, clearly showing that

Not applicable since the project will be commissioned during 2006 only. (b)Provide evidence that th

with the project activity. This evidence shall be based on (preferably official, legal and/or other

corporate) documentation that was available to third parties at or pr

a

e project management considered the incentives from the CDM during the decision to proceed with the Th

project activity. There i



the CDM incentives played a role during the decision-making. Before the implementation of biomass

this project activity the biomass generated in Sivagangai

omass power plants located in the nearby districts.

implementation been sold in a market and where

power plant, the project proponent convened a board meeting to discuss about technical requirements,

various barriers, risks etc., involved in the implementation of project, ways and support needed to

overcome these barriers. At that time of Board meeting, the incentives from the CDM was seriously

considered. The minutes from the board meetings are available for evidence in the form of written

document.

Step 1: Identification of alternatives to the project activity consistent with current laws and regulations. Sub-step 1a :Define alternatives to the project activity: The realistic and credible alternatives identified for this project activity are

a. How power would be generated in the absence of the CDM project activity

The proposed biomass based power plant implemented by AAEPL is located in Sivagangai District of

Tamilnadu. The major sources of power generation in the southern region are based on coal, hydro, gas

and lignite. So even in the absence of this project activity the power generation would be continued by

fossil fuel based thermal power plants in this region.

b. What would happen to the biomass in the absence of the project activity

The 21 MW power plant of AAEPL mainly utilizes the biomass available in the local region of

Sivagangai district, Tamilnadu. In absence of

district will be utilized by other cogeneration and bi

ence the biomass generated has prior to the project H

electricity generation with that biomass.

Sub-step 1b: Enforcement of applicable laws and regulations Both alternatives are in compliance with relevant legal and regulatory requirements. Step 3: Barrier Analysis

The proposed project activity faces barriers that prevent the implementation of this type of project activity

and do not prevent the implementation of at least one of the alternatives.

Sub-step 3a: Identify barriers that would prevent the implementation of type of the proposed project . Technology barriers:



This is the first grid connected biomass power plant to be commissioned in the state of Tamilnadu of

higher installed capacity (21MW) on an Independent Power Producer basis with the steam parameters of

65 ata and 485oC and having employed a air-cooled condenser with a capacity of 21 MW. This would

save huge quantity of water used for a conventional water-cooled power plant and the water conserved

would be useful for irrigation purposes. The promoter have explored and analysed various biomass power

eneration technologies available in India, in terms of operability, economic and technical aspects and

l steam requirements at the turbine inlet and hence increased boiler rating. This has a spiralling

ffect leading to increased auxiliary power consumption, higher biomass consumption per MW and hence

R.3.15 per kWh based

g

decided to adopt Rankine Cycle technology (direct combustion based steam cycle). The Rankine cycle

technology with the conventional cooling towers requires huge quantity of water. Generally, for power

project capacity of 21 MW with conventional cooling systems, which is a common practice in India, it is

estimated that a very substantial quantity of water (The water required is about 100 m3/ hr for Phase-I &

Phase -II or 24, 00,000 litres /day) is required. Due to the water scarcity in the region surrounding the

project, implementing the project with conventional cooling tower is difficult. Hence as an alternative and

to reduce the ground water depletion, an air-cooled condenser (ACC) which is considered as a water

conservation equipment (as it reduces use of water only for service applications), was found essential for

the operation of the proposed plant. The cost of the air cooling system is about 3 to 4 times more than

conventional water cooling system. Further the ACC requires in additional power and thus results in

additiona

e

increased cost of generation. Thus, the addition of the air cooling system increases the capital investment

cost and the operational costs of the project.

Barrier due to prevailing practice: According to the Government Order (G.O) of TNEB, reference “Permanent B.P. (FB) No: 59, dated

11.4.2000”, the price of electricity for any financial year after 1.4.2000 was fixed at INR 2.73 /kWh with

5% annual escalation for a period of nine years up to the year 2010 and the price shall not exceed 90% of

the prevailing High Tension industrial tariff rate applicable for the industrial consumers which may get

revised from time to time. When this proposed 21 MW biomass power project signed the Power Purchase

Agreement with TNEB during the financial year 2003-04, the tariff was fixed at IN

on the second condition of the G.O referred above (i.e. 90% of the High Tension Industrial tariff). This

tariff (INR 3.15 per kWh) is 10 % lower than the tariff based on the 5 % annual escalation.

Thus the tariff policy for biomass power projects in Tamilnadu is a key risk for the investor, because of

two reasons, first one being that the H.T tariff has not increased since 2003-2004 and secondly the cost of



power generation will escalate more than 5% annually due to the increasing cost of biomass. Further it is

expected that this H.T industrial tariff set out by the TNEB will either remain same or will come down in

due course of time when the system will acquire new regime after implementation of Availability Based

Tariff (ABT) and free market for third party sale as per Indian Electricity Act 2003 as IPPs will be

allowed to sell electricity to High Tension consumers and addition of generation capacity as per the

planning of Government of India and State Government of Tamilnadu.

In addition, as per the Power Purchase Agreement (PPA) signed between the TNEB and the project

promoter, the clause 3 of PPA states that the project is bound by all the provisions of Indian Electricity

ct 2003, statutory amendments, state Government and TNEB orders made from time to time. This

significant barrier faced by the majority of the Renewable Energy based IPPs is the grid

conomically infeasible and industrially backward

dditional infrastructure for a small capacity project.

urther the small capacities associated with typical rural electricity transmission and distribution system

e of any conducive, exclusive, consistent power policy for

promotion of biomass power. These factors acted as a deterrent for the private sector to carryout their

A

overall blanket of conditions of amendments without any time limit places the project performance at a

higher risk level. While the TNERC is yet to finalise the tariff policy for biomass power projects in

Tamilnadu and hence subject to several modifications from the current practices, TNEB has a record of

altering the renewable energy power policies and the PPAs several times in the past. (e.g Tamilnadu wind

power policy). PPA also states that for the TNEB grid power to be drawn by the project for start-up

purposes will not only attract High tension tariff but also the monthly demand charges to be notified by

TNERC from time to time. This will also affect the overall cost of generation of power from the proposed

project.

One of the

interconnection with the state utility. For Renewable Energy projects located at a distance from the grid

due to access to Renewable Energy resources and in e

areas such as this proposed project, efforts in establishing the infrastructure for grid connection results in

an additional capital investment. While the project promoter is not comfortable in this co-investment, the

TNEB may not be comfortable in establishing a

F

(for the small electricity consumption of the rural areas) pose poor grid availability problems and stability

problems (for remote areas) leading to fluctuations and grid failure which will reduce the power

evacuated from the biomass power project and hence affect the plant load factor.

The major reasons for the lack of promotion of biomass power in Tamilnadu can be attributed to the fact

that the biomass assessment studies for estimating the biomass power potential were not available for the

State Government Agencies besides absenc



own independent biomass assessment study and implement the grid connected biomass power projects.

Tamilnadu also limits the biomass power plant promoters to either

lants for the southern regional

by coal, lignite based

ermal power plants as discussed in section B.2.

plementing Rankine cycle technology with conventional water cooled

The electricity policy of the state of

sell the power to TNEB or to put it to captive use, as third party sale is not allowed in the state. Only

recently, during the month of August 2005, the TNERC has passed the order2 that the third party sale is

allowed under the open access scheme as defined in the Indian Electricity Act 2003, within a time frame

covering projects with specific capacities. However the enforcement of this order is not expected soon

since TNEB has to now develop the framework for wheeling charges and other applicable charges for

third party sale for utilising their transmission and distribution network by the independent power

producers and obtain the approval of TNERC before implementation.

The analysis of the other least cost and financially attractive and feasible options for implementing grid

connected power plants and the Tamilnadu state grid augmentation plan in terms of recent and planned

implementation of power plants does not conclude in favour of implementation of grid connected biomass

power plants. Current investments in the power sector of the State of Tamilnadu portrays the fact that

majority of the power generation capacity has been added based on fossil fuels such as coal and gas

which are feasible options, leading to high emissions. Thus in the absence of the proposed grid connected

biomass power project activity, other and alternative investments would be made in coal or gas based

power plants in Tamilnadu resulting in high carbon intensity based power generation with more GHG

emissions.

Sub-step 3b: Show that the identified barriers would not prevent the implementation of atleast one of

the alternatives ( except the proposed project activity)

The alternative for this project is power generated by new thermal power p

grid. In southern regional grid the power generation will be always dominated

th

Such thermal power plants are im

condensing systems. In the conventional water cooling system auxiliary power consumption is low

compared to the air cooled system, so the efficiency of the plant is high. As the initial investment of water

cooling system is very low compared with air cooled condensing systems the thermal power plants are

following the conventional water cooling system to prevent the additional barriers. Hence the identified

barriers of the project activity would not prevent the implementation of this alternative viz., fossil fuel

based grid connected thermal power plants.

http://tnerc.tn.nic.in/regulation/OpenAccess2005.pdf2



Step 4: Common Practice analysis

For over a decade since 1994, grid connected biomass power projects have not been implemented

regularly in the state of Tamilnadu though the neighbouring state namely Andhra Pradesh implemented

em on an accelerated basis. The first grid connected biomass project to be commissioned in the state of

amilnadu was during 1997 with an installed capacity of 12 MW in Palayaseevaram (Kancheepuram

city of the

ely fuel wood based on Prosposis Juliflora.

Besides the switch in the type of biomass for the project, this project faced several hardships related to

tate utility due to less demand during the night period. Further the

roject promoter filed a petition with the Tamil Nadu Electricity Regulatory Commission (TNERC)

tart up of the plant at par with the conventional independent power producers (IPP). Though this was the

erall policy for promotion of such grid connected

iomass based power projects was not forthcoming from Tamil Nadu Energy Development Agency and

il Nadu Electricity Board. After a gap of several years, on nnected biomass power

projects with installed capacity of 18 MW and 7.5 MW been recently commissioned in Tamilnadu. These

cts have been developed under the CDM. Thus as mentioned previously, against the total

ated potential of 670 MW from biomass, the installed capacity as on date has been only to the tune

Though recently ass power projects totalling over 250 MW* has been

sanctioned by TEDA, onl plemented. Hence implementation of grid connected

r project is no on practice in the state of Tamilnadu.

ce: Minutes of of Biomass Power Projects as on 27/04/2004

ct of CDM Registra

21 MW biomass based grid connected power plant implemented by AAEPL in Sivagangai district is

e first higher capacity biomass power plant in Tamilnadu.This biomass based power plant generates

sidues available in this region. Due

im , the electricity generated by the southern regional grid

been displaced which reduces the anthropogenic GHG emission from the fossil fuel based power

th

T

District) based on the bagasse from the neighbouring sugar mill. However due to the pau

baggasse, this power plant switched to other fuels, nam

poor evacuation schedules by the s

p

requesting for waiver of monthly demand charges for drawing power from the grid for shorter time during

s

only power plant in the state of Tamilnadu then, an ov

b

Tam ly two grid co

two proje

estim

of 41.5 MW. licenses for biom

y a few are being im

biomass powe t a comm

*Referen Review

5: Impa tion

The

th

electricity from the waste land biomass (prosopis juliflora) and agro re

to this plementation of this CDM project activity

as h

generation supply to the grid.


This template shall not be altered. It s

The successful registration of this project as a CDM project activity will provide CDM incentives viz.,

revenue from sale of certified emission reductions. This CDM incentive encourages the promoter to

overcome the barriers analyzed in the step 3a, which further support the project activity to provide a

consistent reduction thropogenic G ions.

.4. Description of how the definition of the project boundary

in the an HG emiss

B related to the baseline m ologethod y selected is applied to the project activity:

Project Boundar

.5. Details of baseline

Power to Grid

Power

Generation Systems

(Boilers & Generator)

B informthe name of person (s)/entity (ie Date of Completion of the base Organization Asia CStreet/P.O.box Kodam

Building # 167

RMa

(Bio toS

M(B

Tr

aw terial mass)rage

CO2

Raw aterial iomass) ansportation

hall be completed without modifying/adding headings or logo, format or font.

y

Power plant (In-House)

consumption

ation, including the date of completion of the baseline study and s) determining the baseline:

line study: 11/05/2006

gement India P Ltd., arbon Emission Manabakkam High Road, Nugambakkam



City Chennai

State/ Region Tamilnadu

Post Fix/Zip 600 024

Country India

Telephone +91 44 39180501 Fax +91 44 39180505 E-Mail [email protected]

Url www.asiacarbon.com SECTION C. Duration of the project activity / Crediting period C.1 Duration of the project activity: oject activityC.1.1. Starting date of the pr :

t Activity

Capacity Starting Date

Projec

Phase-I 8.5 MW 31st August -2003

Phase-II 12.5 MW 1 September -2006 st

C.1.2. Expected operational lifetime of the project activity: 25 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: C.2.1.2.Length of the first crediting period:



C.2.2.Fixed crediting period: C.2.2.1.Starting date: 1 st -2006 C.2.2.2

.Length:

st Augu

10 years

SECTION D. Applicat methodologyion of a monitoring and plan D.1. Name and reference of approved monitoring methodology applied to the project activity: The monitoring methodology applied for this grid connected biomass power plants is ACM0006

The name of the applied monitoring methodology is:

“Conso onitorin id-co electric iomass residues” – Vers ectoral S May

D.2. Justification of od and why i the pro ect

lidated mion 03, S

g methodology for grcope : 01, dated 19

the choice of the meth

nnected 2006

ity generation from b

t is applicable to

3

ology jactivity: The 21 MW Aurobindo Agro Energy ass based power plant. The generated electricity is exported to

the southern regional grid. fuel used for this power plant is CO2 ass residue.

The methodology used for this project activity is “Consolidated baseline methodology for grid-connected

generation from biomass residues”- ACM0006 and this is the most appropriate methodology

able in the NFCCC for grid-connected and biomass residue fired electricity generation project

ctivities.


The predominant fuels used for this project activity are prosopis juliflora from waste land and

other agricultural residue (Annexure V) available in this region. The project will also co-fire

some fossil fuels namely coal.

biom

The neutral renewable biom

electricity

avail U

a

3 http://cdm.unfccc.int/methodologies/DB/IAB80AE6G21VF0PU9OLLX389DXMCMX/view.html



This Pr activity is an independent biomass ass residues used in this

project activity are prosopis juliflora and other ing from the nearby area

and market.

Biomass used for this project is available in this region only iom ill n e sto for more

than one y

The ma

residues. There is no significant energy

Baseline scenario

oject

ear within the plant.

jor biom

power plant. The biom

is Prosopis juliflora and other agricultural

agricultural residue com

. B ass w ot b

ass

red

ass used for this project activity

quantities, except for transportation of biom

Scenario

Project type Power ener ass g ation Use of biom Heat

generationAs per the

ACM0006

(Scenario-1)

Installation of a new

n

site where currently no

(Greenfield

projects )

The

nera of

connected

power

(P4)

The biomass is used

pow nera ,

cogeneration, in other

existing or new grid

power plants1(B3)

-

biomass power

generation pla t at a

power generation

occurs

ge

power in

tion

existing

and/or new

grid-

plants

for

including

er ge tion

connected

As per the

Project

Activity

ass power

no power

e pr ed

b as

r to roje

imp entation been

t

biomass ty

mon practice.

The project activity is a

new biom

plant at a site where

currently


this project activity is a

Greenfield power

project

Th

project

opos

activity

21 MW new

grid

connected

is a

iom

power project

s

The biom

prio

ass has

the p ct

lem

sold in a m

where electricity

generati

arke

on with t

and

hat -

pe is

com

PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 02 CDM – Executive Board page 29 D.2. 1. Option 1: Monitoring of the emissions in the project scenario and the baseline scenario a llected in order to monitor emissions from the project activityD.2.1.1. Dat to be co , and how this data will be archived: ID number Please use umbers to ase cross-eferencing o D.3)

Data variable Source of data 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)

Comment (nert

D.1 Electricity generated

Through DCS kWh M Continuous 100 % Electronic The generated electricity is directly

measured through DCS.

D.2 Auxiliary consumption

Through DCS kWh M Continuous 100 % Electronic The Auxiliary consumption is directly

measured through DCS.

D.3 Power export Meter reading at TNEB Substation

kWh M Continuous 100 % Electronic &

Paper

Monitored through meter reading and Double check by sales receipt from TNEB

D.4 Biomass used

Through

Weighbridge

MT M Daily > 95% Paper Measured through the receipt from

Weighbridge.

D.5 Avg. calorific value of Biomass used

Through sample testing in lab

kCal/Kg M For each batch of biomass

100 % Paper Taken from Lab report

D.6 Coal Through

Weighbridge

MT M Daily >95% Paper Measured through the receipt from

Weighbridge.

D.7 Calorific value of coal

Through sample testing in lab

kCal/Kg M For each batch of coal

Grab sample

Paper Taken from Lab report


PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 02 CDM – Executive Board page 30 D.8 Fuel

Transportation Through voucher

km/Trip E Each trip > 95 % Paper Measured from the voucher

Distance D.9 Ash Through km/Trip E Each trip > 95 % Paper Measured from the voucher

Transportation Distance voucher


PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 02 CDM – Executive Board page 31 D.2.1.2. eD scr rm o estima ect emi ea urce ula m, emissioniption of fo ulae used t te proj ssions (for ch gas, so , form e/algorith s units of CO2 equ.) The form ission by the project due to burning of 20 % coal at project site. Other than biomass, maximum 20 %

Coal also allowed to use as fu f biomass. The CO2 released by the 20 % coal is calculated as follows.

C.Ec = Q * C.Vc *E.Fc

Where

C.Ec - oxide emission due to coal t project site MT

Q ity

C. - c value of coal burned Tj/Ton

IPCC Standard em or Ton of co2/Tj - 94.68 Tons of co2/Tj

ula used for to calculate the Carbon-dioxide em

el instead o

Carbon-diburning a

-

Vc

Quant of coal burned in MT

Calorifi

E.Fc - ission fact

D.2.1.3. Relevant data necessary for determining the baseline of anthropogenic emissions by sources of GHGs within the project boundary and how such data will be co d arcllected an hived : ID number (Please use numbers to ease cross-referencing to table D.3)

Dat e a Data unit Measured (m),

calculated (c),

estimated (e),

Recording frequency

Proportion of data

to be monitored

How will the data be archived? (electronic

/ paper)

a variabl Source of dat Comment

M1

recording

and paper

Electricity Gross electricity generated

MWh measured Monthly 100% Electronic Direct measurement from electronic meter

M2 Electricity consumption

m3 measured Monthly

recording

100% Electronic

and paper

Measured as consumed Start up Fuel


PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 02 CDM – Executive Board page 32 M3 (EGy)

recording

by receipt of sales Electricity Electricitysupplied to

the Tamilnadu

State electricity

Board

MWh measured Monthly 100% Electronic Double check

and paper

M4 (EFy) Emission factor

tCO2eq/MWh Calculated Yearly 100% Electronic eighted sum of emission factors nd Build Margin

GHG emission

factor of the southern grid

Calculated as a wof Operating Margin a

M5 (EF_OMy)

Emission tCO eq/MWh Calculated Yearly 100% Electronic Calculated as TEM divided by TGENfactor

GHG emission factor of

the southern grid

(Operating Margin)

2 Y Y

M6 (EF_BMy)

Emission e

tCO eq/MWh Calculated Yearly 100% Electronic Calculated as per the ACM0006 Baseline , baseline scenario

development and baseline emission rate, using combined margin) for small grid connected zero-emission renewable electricity generation taking

factor GHG mission

factor of the southern

grid (Build

Margin)

2methodology (barrier analysis

into account data availability.

M7 ( )

Emission Total em

tCO2eq/year Calculated Yearly 100% Electronic alculated as the sum of GHG emissions of all TEMy

GHG issions of

the southern grid

Cplants



M8 (TGENy)

kWh/ year

and

Paper xcluding zero or

from the Central Electricity Authority

http://www.cea.nic.in

Electricity Totalelectricity

generation of the southern

grid excluding

zero or low operating

cost sources

Calculated Yearly 100% Electronic Calculated as the sum of electricity generated of the grid e low operating cost sources and obtained

(CEA) Website:

M9 (Fi,y) Fuel

fuel consumed

(Heat rate) in the southern

grid

Physic-al unit Calculated

and

Paper

Central Electricity Authority (CEA) the performance of thermal power plants Report from website: http://www.cea.nic.in/opm/0405/start.pdf

Amount ofeach fossil

Yearly 100% Electronic

M10 (i.COEFi)

CO2 coefficient

GHG emission

coefficient of each fuel i

tCO2eq/(physical unit of the fuel

i)

Calculated Yearly 100% Electronic IPCC default values are used

M11 (j.GENj,y)

Electricity Electricity generation of

the plant j

MWh/ year Measured Yearly 100% Electronic Central Electricity Authority (CEA) Website: http://www.cea.nic.in/newweb/opt2_mon_gena.htm

M12 Plant name Plant - Measured Yearly 100% Electronic Central Electricity Authorityidentification

for OM

(CEA) Website: http://www.cea.nic.in/newweb/opt2_mon_gena.htm



M13 Plan Plant identification

- ed Y 100% nic Central Electricity Authority (CEA) Website: http://www.cea.nic.in/newweb/opt2_mon_gena.htm

t name

for BM

Measur early Electro

M14 (wOM and wBM)

Non-dimensional

number

100% Default weight factor of 0.5 each is used. Weight factor of OM

(BM)

- - Yearly Electronic

M15 Fu tonnes Measured Monthly (aggregate)

100% Electronic per

Minimum of two years after last issuance of CERs el Amount ofBiomass

combusted and pa

M16 Efficiency T fuel / MWh Measured Minim of four

times per

-

Electronic and paper

Minimum of two years after last issuance of CERs Efficiency (Heat rate)

of the Boiler

um

year

)

D.2.1.4. Description of formulae used to estimate baseline emissions (for each gas, source, formulae/algorithm, emissions units of CO2 equ. The formula used for to estimate the baseline emissions are already discussed in the section: B 2.



S.No Details Phase-I 8

Phase-II W

Total MW .5 MW 12.5 M 21

1 Total gros er

generation for the 10

crediting period i

557,532 200 33,732

s pow

year

n MWh

676, 1,2

2 Total Auxiliary

Consumption

for the 10 year crediting 66,904

81,144 148,048

period in MWh

3 Total Net power

crediting period in MWh

1,085,684 generation for the 10 year 490,628

595,056

4 Baseline emission factor in

tCO2/MWh 1.098 1.098 1.098

5

Baseline emissions for the

10 y

in MWn tCO2/year

538,710 3 081 ear crediting period

,371

65 1,192,

D. 2.2. Option 2: Direct monitoring of emission reductions from the project activity (values should be consistent with those in section E). Option 2 is not selected D.2.2.1. Data to be collected in order to monitor emissions from the project activity, and how this ill be rchived: data w aThis template shall not be altered. It shall be completed without modifying/adding headings or logo, format or font.

PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 02

e Board page 36

his template shall not be altered. It shall be completed without modifying/adding headings or logo, format or font.

CDM – Executiv

T

(Please use ID number

numbers to ease cross-

D.3)

Data variable

S ata unit

Measured (m),

calculated (c),

ted

Recording frequency

Proportion of data

to be monitored

How will the data be

archived? (electronic/

paper) referencing to table

ource of data

D

estima (e),

Comment

D.2.2.2. Description of formulae used to calculate project emissions (for each gas, source, formulae/algorithm, emissions units of CO2 equ.): Option 2 is not selected. .Therefore no formulae used here D.2.3. Treatment of leakage in the monitoring plan D.2.3.1. If applicable, please describe the data and information that will be collected in order to monitor leakage effects of the project activity ID number(Please use numbers to ease cross-referencing to table D.3)

Data variable

Source of data 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)

Comment

N 1 Distance Average

distance for 1 trip

km calculated Weekly 100% Electronic and Paper

Average distance between the plant and the fuel supply site will be calculated

N2 Truck Trips

Number of trips per day

Mere number calculated Daily 100% Paper Number of trips will be monitored using

an entry registry

N3 Fuel Fuel L estimated Daily 100% Paper


e Board page 37


Consumer tr

tr

ption p uck per

ip

y ed. Estimated b the fuel consum

N4 Em

Fissiacto

on r

ission of the sed for ortation

tCO2eq/ An p

t va e used

er

IPCC defaul

Pa100% nually atedcalculm3

Emactoruel uansp

ff

tr

lues ar

CDM – Executiv

PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 02 CDM – Executive Board


.2.3.2. Description of formulae used to estimate leakageD (for each gas, source, formulae/algorithm, missions units of CO2 equ.) e

As described in the methodology ACM0006, the main indirect emissions potentially giving rise to

ons ari e as power plant

onstruction, fuel handling (extraction, processing, and transport), and land inundation (for hydroelectric

f emis on fro omass transportation and ash

he leakage activity identified, which contributes GHG emissions outside the project boundary are given

. CO2 emission due to Ash transportation

leakage in the context of electric sector projects are emissi sing due to activiti s such

c

projects). In the case of the AAEPL two leakage sources o si m bi

are taken into account.

T

below:

A

B. CO2 emission due to biomass transportation

The formula used to estimate the leakage due to off site transportation is given below

A. CO2 emission due to Ash transpo tatr ion

ear) Total ash generated by the project (t/y

Truck capacity (tons/trip) for ash transportation

= XA

= YA

for ash transportation = ZA

otal distance travelled by the truck for ash transportation (km/year) = TA

( 2 /k

TA x Ef

Distance travelled per trip (km)

T

CO2 Emission factor for Diesel tCO m) = Ef Diesel

XA x ZA T =

A

YA

CO2 emission due to ash transportation (tCO2 /year) A =

B. CO2 emission due to biomass transportation

Total biomass consumed by the project (t/year) = XB

B

Distance travelled per trip (km) for biomass transportatio = ZB

uck for biomass collection (km/year) = TB

O2 Emission factor for Diesel (tCO2 /km) = Ef Diesel

Truck capacity (tons/trip) for biomass transportation = Y

n

Total distance travelled by the tr

C



CO emission due to biom2 ass transportation (tCO

ue to off site t rtation (tCO

(Ash and Biomass transportation)

D.2.4. Description of formula to estimate

2 /year) B = TB x Ef Diesel

Total emission d ranspo 2 /year) = A + B

e used emission reductions for the project activity (fo

ts of COr each

gas, source, formulae/algorith issions unim, em 2 equ.)

X x ZB B

TB = YB

Step 1 : Calculation of Baseline emission factor: The formula used for to estim

ate th issions factor are alr

of Operating M :

of Build Marg

:

e Emission

e baseline em eady discussed in the section: B 2.

Emission factor argin 1.094tCO2/MWh

Emission factor in : 1.102 tCO2/MWh

Baseline emission factor

1.098tCO2/MWh

Step 2 : Baselin :

2) Units exported to southern grid by

Baseline em

t Emission

Baseline emission (Tons CO = this project (MWh) * ission factor (Tons CO /MWh) 2

Step 3 : Projec :

2) = Emissions by sources (Tons CO 2)

This is a biomass power project.Emission by sour

estimate the e n due to leak Step 4 : Emission reduction:

Project emissions(Tons CO

2) + Emission due to leakage (Tons CO

ces are Zero for this project activity

Formula used to missio age is already explained in the section D.2.3.2

CO2 emission reduction due to project activity (C

ER) = Baseline emission (Tons CO2) -

Project emissions (Tons CO2)



D.3. Quality control (QC) uality assur ata and q ance (QA) procedures are being undertaken for dmonitored Data

ndicate table and Uncertainty level of data (High/Medium/Low)

Explain QA/QC procedures planned for these data, or why such procedures are not necessary. (I

ID number e.g. 3.-1.; 3.2.) D.2.1.3. M1 Use of electronic meter. Meters will undergo

Low maintenance subject to appropriate industry standard.

D.2.1.3. M2 Low

Use of electronic meter. Meters will undergo maintenance subject to appropriate industry standard.

D.2.1.3. M3 Low

Use of electronic meter. Meters will undergo maintenance subject to appropriate industry standard. Meter reading will be checked with the purchase receipt and inventory data.

D.2.1.3. M4 Low Calculated by using published official data










D.2.1.3. M14 Low Published official data

D.2.1.3. M15 Low

Trucks carrying biomass will be weighed twice, upon entry and exit. Meters at the weighing station will undergo maintenance subject to appropriate industry standards.

D.2.1.3. M16 Low Standard test procedures will be used to calculate the heat rate of the boiler

D.2.3.1. N1 Low be compared to the average distance between the plant and the fuel supply site.

The distance records submitted by the truckers will

D.2.3.1. N2 Low Entry and exit registry will be maintained D.2.3.1. N3 Medium Fuel purchase invoices will be verified

PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 02 CDM – Executive Board D.2.3.1. N4 Low Use of officially published data and laboratory

certificates D.4 Please describe the operational and management structure that the project operator will implement in order to monitor emission reductions and any leakage effects, generated by the project activity

To address all O&M issues, though the overall authority and responsibility belongs the management, it

has formed a team of Supervisors and Field Representatives headed by a Plant Manager to effectively

control and monitor the complete process of fuel procurement, quality issues, and the handling and

storage of material in the plant area.

The monitoring data required are taken by labours/ supervisors and it is reported to the shift in charges.

The shift in charges report daily to the Plant Manager. The Plant manager submits a weekly report to the

management, which will be documented and stored in the project office. By this operational structure, the

management can monitor the project activity and make amendments immediately, if needed.

Management

Plant Manager

Shift in Charge

Supervisor

Labourer


PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 02 CDM – Executive Board No additional CDM related training is required at any level as the monitoring data required for the

verification are taken from the regular digital meters and manual logs.

The monitored parameters have low level of uncertainty. Therefore the possible monitoring data

a

Reported e previous results and data and will be thoroughly

checked for any

D

djustments are not envisaged for the project.

results and data will be compared with th

inconsistency.

.5 Name of person/entity determining the monitoring methodology:

Organization: Asia Carbon International B V Street/P.O.Box: Kodambakkam high Road, Nungambakkam Building: 167 City: Chennai State/Region: Tamilnadu Postfix/ZIP: 600 024 Country: In a diTelephone: + 44 3991 180501 FAX: +91 44 39180505 E-Mail: di sh@ane siacarbon.com URL: w .asiaww carbon.com



.

SECTION E. Estimation of GHG emissions by sources E.1 . Estimate of GHG emissions by sources: Biom cts. The CO2 released by the biomass is

con lf. Other than biomass posed ximum

20 % coal on an annual basis for power generation.

Carbon-dioxide emissions due to annual burning of coal to the extent of 20 %:

The CO2 emissions released from the combustion of the coal for power generation annually is

Detailed calculation are furnished in the Annexure 3 E.2. Estimated leakage

ass is the main fuel used for this power proje

sumed by the biomass plantations itse , it is pro to use ma

calculated as follows.


Where

C.Ec - Carbon-dioxide emission due to coal burning at project site MT

Q - Quantity of coal burned in MT per year

C.Vc - Calorific value of coal burned Tj/Ton

E.Fc - IPCC Standard emission factor Ton of CO2/Tj

C.Ec = 16,924*0.02679*94.68

C.Ec = 42,927 Tons of CO2 per year

:

The leakage activity ntifi tes GHG emissions outside the project boundary are

given below: The lea ge ac hich contributes sions outside the project

boundary are given below:

A. CO2 e sion nsportation

B. CO2 e sion nsportation

A. CO

ide ed, which contribu

ka tivity identified, w GHG emis

mis due to Ash tra

mis due to Biomass tra

2 emission due to Ash transportation

Biomass required for this project is estimated to be 117,734 tons per year. The ash percentage

in the biomass is generally 4%. The ash generated from the power plant would be sent back to

fields to be utilised as manure.

Total ash generated by the project : 4 709 MT per year


.

Truck capacity : 10 MT

Total Return trip distance travelled between project

/year

CO2 emission per annum : 20 t CO2/ year

. CO

site and ash disposal centre : 100 km

Number of return trips : 470.9 per year

Total Distance travelled between t projec site

and biomass collection centres : 47 090 km

CO2 Emission factor for Diesel : 0.00042482 t CO2/Km

B 2 emission due to biomass transportation

The primary fuel for this power plant is Prosopis julif s cies a

assively for quite some decades, due to soil and other related environmental features. It is

rs. It grows with little

r no maintenance and organized trimming and watering use of fertilizer. Keeping the root

n n e years. So the plantation area remains

ondary biomass for this power plant

re Euc yptus w od, C nut R ugarcane Trash.

lora. Thi spe is prevailing in this are

m

grown in all type of unproductive lands owned by Govt. & the private farme

o

undisturbed, the stem and bra ches are cut o ce in thre

same and no permanent decrease in the carbon stock. The Sec

a al o oco esidues, Chilly Stalks and S

Surplus Biomass available in Sivaganga District

S.No Biomass Surplus

tons/year

1 Prosopis Juliflora 358,308

2 Eucalyptus wood 308,350

3 ocon 42,893 C ut Residues

4 C Stalks 155,268 hilly

5 Sugarcane Trash 15,102

Total 879,921

More details about the biomass availability are provided in Annexure 5

Total biomass consumed by the project : 117,734 MT per year


.

Truck capacity : 10 MT

: 100 km

Number of return trips : 11 773.4 per year

To stance en pro and biomass collection centres : 1 177 340 km

CO2 Emission factor for Diesel 0.00042482 t CO2/km

CO ssion per an 5 t CO2

Total estim age due t = + B

= 0 + 500

= 20 tons of C

E.3.The sum of E.1 and E.2 representing the project activity

Total Return trip distance travelled between project site and biomass collection centres

ta il D travelled betwe ject site

:

/year

2 emi num : 00 / year

ated leak o project A

2

5 O2/year

emissions:

42 927 + 520

ns of CO2/year

.4.Estimated anthropogenic emissions by sources of greenhouse gases of the baseline:

E.3 = + E.1 E.2

=

= 43 447 to E

he b line emissions are calculated as following: T ase

Where:

EF seline emission factor (calculated in B2)

= 1.098 tCO2/MWh EG = Net electricity supplied to the southern regional grid by

1,085,684 MWh

Total n 1.098* 1,0 = 1,192,081 t E.5. D the emission reductions of the p

BE = EG * EF

= Ba

the

project

=

an ual baseline emission (BE) = 85,684 CO2/year

ifference between E.4 and E.3 representing roject activity:


.

The difference between E.4 and E.3 which is the emission reductions of the project activity are shown below :

Sse line

Emission tCO2/year

(E.4) (E.3)

EmredtCO2/year

(E.5)

.No

Year

Net electricity MWh

Ba Project emission tCO2

ission uction

1 2006 18,850 20,697 6,321 14,376 2 2007 52,420 57,557 17,578 39,979 3 2008 107,860 118,430 36,169 82,261 4 2009 129,508 142,200 43,428 98,771 5 2010 129,508 142,200 43,428 98,771 6 2011 129,508 142,200 43,428 98,771 7 2012 129,508 142,200 43,428 98,771 8 2013 129,508 142,200 43,428 98,771 9 2014 129,508 142,200 43,428 98,771

10 2015 129,508 142,200 43,428 98,771 Total 1,085,684 1,192,081 364,066 828,015

Total estimated emission reductions (tons of CO2) 828,015 10 Total number of crediting years Annual average over the crediting period

of estimated reductions (tons of CO2/year) 82,801 E.6. Table providing values obtained when applying formulae above: Summary of the above calculations is shown in below table

s Unit Value Parameter

1. Capacit MW 21 y

2. Annual net electricity generation MWh 1,085,684

3. e Bas line carbon emission

− The “approximate operating margin” tCO2/MWh 1.094

− The “build margin” tCO2/MWh 1.102

− Ba tCO2/MWh 1.098 seline emission factor

− Total baseline carbon emcrediting period of 10 years tCO2

1,192,081

ission during the


.

4. Total project carbon emission during the crediting period of 10 years tCO2

364,066

5. Total CO2 emissions reductions during the crediting period of 10 years tCO2

828,015

6. Annual average over the crediting period of estimated reductions (tons of CO2)

tCO2 /year 82,801

SECTION F. Environmental impacts F.1. Documentation on the analysis of the environmental impacts, including transboundary impacts:

ven though the biomasE s based power plant is eco-friendly in nature, the waste hot flue gas

A) study to

scertain the pollutants from various parts of project activity have no negative impact on the

e impact of the proposed power plant covering the following

Sewage disposal

T

i. Dust particles from fly ash in flue gas

gas

generated in the project activity consists of pollutants and it must be removed before going to the

environment. So the project promoter took an Environmental Impact Assessment (EI

a

nvironment. The environmental

aspects is briefly discussed in this chapter.

Air pollution

Water pollution

Thermal pollution

Noise pollution

Pollution monitoring and surveillance system

AIR POLLUTION

he air pollutants from the proposed units are:

ii. Nitrogen oxides in flue


.

For thermal power stations, the Central Pollution Control Board stipulate the limits for particulate

atter emission. 150 mg/Nmm

l

m mitted to

atmosphere and will be designed such that the outlet dust concentration meets the CPCB /

T Board stipulation of 115mg/Nm3.

S

f

x &

el is negligible, therefore, SOx and NOx emissions to atmosphere is not envisaged.

nerator blow down water

i) Effluent from water tre

The DM water requirement of the plant is only 1m3/hr, however, the DM plant is sized for 3 m3/

hr considering regeneration and th this plant is ve w. Hydrochloric acid and

caustic soda would be used as regeneration in the proposed water treatment plant. The acid and

alkali generated during the regeneration process of the ion exchangers would be drained into a

neutralising pit. The effluent would be neutralised by the addition of either acid or alkali to

achieve the required pH before disposing off for dust suppression or for horticultural purpose.

3 for protected area and 350 mg/ Nm3 for other areas and the same

imits are followed by all State Pollution Control Board. The electrostatic precipitator will remove

ost of the fly ash from the flue gas; thereby limiting the quantity of fly ash e

amilNadu State Pollution Control

tack height of minimum 4 m will be provided considering the fuel characteristics, to disperse the

lue gas into atmosphere.

NO SO2 Emissions Since biomass is used as fuel in this project activity the fuel bound nitrogen or sulphur content in

fu

WATER POLLUTION The water pollutants from the proposed units are

i. Effluent from water treatment plant

ii. Steam ge

iii. Cooling tower blow down

atment plant

e effluent from ry lo

ii) Steam Generator Blow down


.

The sal lution are the pH

wn water will

however meet the pollution Control Board norms of 1200 ppm.

THERMAL POLLUTION

e heat dissipated to atmosphere is negligible.

ll equipment in the power plant would be designed / operated to have a noise level not

edi Administration

Duration per day

( hours) Sound Level (dBA)

slow response

ient characteristic of the blow down water from the point of view of pol

and temperature of water, since suspended solids are negligible. The pH would be in the range of

9.5 to 10.3 and the temperature of the blow down ware would be about 100 oC, since it is first

flashed in an atmospheric flash tank and the effluent from the flash tank is negligible.

iii) Cooling Tower Blow down

The cooling tower blow down water will be high TDS only. The blow down water would be

taken to the neutralising pit and blended with other effluents. The TDS of blow do

Since the plant capacity is only of 21 MW level, th

NOISE POLLUTION A

exce ng 85 to 90dBA as per the requirement of occupational Safety and Health

Standard (OSHA). As per this Standard protection from noise is required when sound levels

exceed those as specified below when measured on the A scale at slow response on a standard

sound level matter.

PERMISSIBLE NOISE LEVELS

8 90 6 92 4 95 3 97 2 100 1 102 1 105 1 110 1 115

In addition since most of the noise generating equipment would be in closed structures, the nois

transmitted outside would be still lower.

e


.

POLLUTION MONITORING AND SURVEILLANCE SYSTEMS For thermal power stations, the CPCB / TNPCB stipulate the limits of 115 mg/ NM3 for

ater quality- monitoring programme

various sources will be monitored regularly and

ualified persons would be in charge of monitoring the parameters by using suitable instruments.

IMPACT OF POLLUTION / ENVIRONMENTAL DISTURBANCE

n the emission levels of dust particles,

e and nitrogen oxide within the permissible limits would be taken and necessary

water quality

this project activity green belt of minimum 25 metre width will be provided all around the

resi d for the

reen belt. The area to be occupied is an uninhabited dry agricultural land. Hence there is no

If environmental impacts are considered significant by the project participants or

particulate matter emission and minimum stack heights to be maintained for keeping the sulphur

dioxide and nitrogen dioxides levels in the ambient within the air quality standards. The

characteristics of the effluent from the plant would be maintained so as to meet the requirements

of the state pollution Control Board and the minimum National standards for Thermal Power

plants stipulated by the Central Board for Prevention and Control of Water Pollution. The air

quality will be periodically monitored and reported by using adequate instruments.

W The quality of the effluent generated fromcorrective action will be taken. Q

Since all necessary pollution control measure to maintai

sulphur dioxid

treatment of effluents would be carried out, there would be no adverse impact on either air or

in and around the power station site on account of installation of the proposed plant.

GREEN BELT In

plant boundary limits. In addition, avenue trees will be planted all along the roads. Droughts

stant trees (Babul, Neem or Date Palms) suitable for the local climate will be selecte

g

displacement and resettlement of population.

F.2. the host Party, please provide conclusions and all references to support documentation of an


.

environmental impact assessment undertaken in accordance with the procedures as required by the host Party:

he biomass based grid connected power plant implemented by Aurobindo Agro Energy Pvt.ltd

asse

asse Aurobindo Agro Energy Pvt.ltd, is according to the

pol lementing this project and

as received relevant clearnces for the same from the Tamilnadu Pollution Control Board

T

is an environmental friendly project .As mentioned in section F.1, as per environmental impact

ssment studies, the project activity has no remarkable effect in the atmosphere. The

ssment studies undertaken by the

pollution control board norms. The Green House Gas emissions, thermal pollution and dust

lution will be reduced by Aurobindo Agro Energy Pvt.Ltd by imp

h

(TNPCB).

SECTION G. Stakeholders’ comments G.1. Brief description how comments by local stakeholders have been invited and compiled: The following Statutory bodies have examined and studied about all the aspects of the project and

e issued necessary clearances to establish the project:

al Body:

hav

Loc

Village Panchayat, an elected body of representatives administrating the local area by the

Electricity

Board (TNEB), Lr.No. SE/SEDC/SVGA /DFC/F.Agreement /2003 Dt. 17/06/2003.

TamilNadu Fire Service has issued a Fire Service License (under Section 13 of the Tamilnadu

ilizing biomass as a fuel. Licence No. 29/2003 Dated 28/08/2003

•

local people, has issued the plant layout approval for the Biomass Power Project.

State Government of TamilNadu:

• The project proponent has signed Power Purchase Agreement with TamilNadu

•

Fire Service Act 1985 and with Tamilnadu Services Rules 1990 – Apendix – III) License for

power plant by ut


.

• District Collector of Sivaganga District (Highest Administrative officer in the District) has

03.

Tamil Nadu Pollution Control Board (TNPCB) has issued the consent for establishment of

the biomass power project, Consent order No: 2825 Proceedings No.

T11/TNPCB/F.838/SVG/W/2004.

• Tamil Nadu Forest Department has issued a No Objection Certificate for setting up Biomass

based Thermal power project C.No 2327/2003 D dated 3/06/2003

• The public Works Department has issued a Ground Water Clearance Certificate for drawal of

02.40 lakhs lpd of ground water for the proposed Biomass Power plant at Virgadi

Kadambankulam village ( Hamlet of Sevavoorani), Kalayarkoil Block, Sivagangai District –

Permission granted – reg.

Government of India:

• Airport Authority of India, New Delhi’s has issued the No Objection Certificate for

Chimney’s height clearance, vide letter No.AAI/20012/1162/2003-ARI (NOC) dated

11/02/04

The project proponent has conducted discussions with members of the local population. The local

populations welcome the project due to various benefits, such as development of infrastructure in

the area, increase of income due to the supply of biomass and improvement in their standards for

living. The project proponent has already established good relationship with local people who

ensure co-operation for the successful and continuous operation of the power plant.

G.2. Summary of the comments received:

issued the No Objection Certificate D.Dis/D4/43088/2003 dated 14/11/20

•

The project proponent received no negative comments from the public as well as from

government bodies.

G.3. Report on how due account was taken of any comments received:


.

The comments were carefully reviewed. All of them are positive comments.


.

Annex 1

CONTACT INFORMATION ON PARTICIPANTS IN THE PROJECT ACTIVITY Organization: Au

robindo Agro Energy Pvt Ltd

Street/P.O.Box: Anna Nagar

Building: H.No.1004, 6th Avenue

City: Chennai

State/Region: Tamilnadu

Postfix/ZIP: 600 020

Country: India

Telephone: 91-44-52611139

FAX: 91-44-52611140

E-Mail: [email protected]: Represented by: Mr.M.S Chandra Bose Title: Director Salutation: Mr Full Name: M.S Chandra Bose Department: Mobile: 9444416492 Direct FAX: 91-44-52611140 Direct tel: 91-44-52611139 Personal E-Mail: aaepl_sgproject@rediffm ail.com


.

Annex 2

INFORMATION REGARDING PUBLIC FUNDING

There is no public funding for this Project

ANNEX 3


.

EL

BAS INE INFORMATION

T wing data are obta various sources and were used while estimating the baseline he follo ined from

emissions.

d Capacity a r G o R

Name of the power P

Instacapa(MW

Gross Generation (MUs)

Installe nd Powe ener natio f in Southern egion

lant

lled city )

COAL AND LIGNITE BASED POWER PLANTS T (2003-04) (2004-05) 20 amilnadu 05-06Ennore 450.00 8 223 1 1,25 1, 60Tuticorin 1,050.00 4 180 4 8,08 8, 767Mettur 840.00 6,735 684 6519 6,N 30.00 4,347 3,916 1 orth Chennai 6 400N 0 258 LC I * 600.00 4,40 4, 3990 N 1 3 247 4 LC II * ,470.00 10,00 9, 917N 3 238 2 LC I Ext 420.00 1,99 3, 308N 0 336 0 LC 0 Unit 250.00 1,65 1, 145Andhra Pradesh V 1,260.00 10,104 851 9755 ijay Wada 9,R 3,331 3,354 9 ayalaseema 420.00 236Kothagudem 3 364 670.00 4,18 5,Kothagudem-V Stage 500.00 3,994 140 8213 4,R am B 1 496 7 amagund 62.50 47 39Nellore 30.00 6 154 7 14R TPS 2,600.00 16,332 17,169 19691 amagundam SSimhadri 1,000.00 7,722 8,122 1 774K arnataka Raichur 0 718 3 1,470.00 11,40 10, 917Torangallu IMP 260.00 766 516 1383 Total 13,982.50 96,919 97,967 95,222


.

Name

of the power ity

(MW)

Gross Generation (MUs) InstalledcapacPlant

Gas power plants Tamilnadu (2003-04) (2004-05) (2005-06) Basen Bridge 120.00 89 40 40 Nariman 10.00 0 0 0 Kovilkalapal 107 7 763 573 .88 45Valantharvi 52.80 0 0 98 Valuthur 95 671 5 697 .00 58Karuppur 119.80 0 0 357 Kuttalam 101.40 108 641 674 PP Nallur 1,314 330.50 464 429 Andhra Pradesh Vijjeswaram Gas

2,147 1,993 1837 Station 272.30 Peddapuram CCGT 1,249 1,141 842 220.00 Jegurupadu 235.40 1,505 1,420 1294 Kondapalli GT 350.00 2,238 2,246 2116 Godavari 208.00 1,100 1,373 1331 Karnataka

Tanir B 1,631 630 241

avi 220.00

Kerala Cochin 174.00 991 112 37 Kayamkulam 2,1 359 350.00 18 621 Pondichery

PPCL G.T.G 22

32.50 77 276 57

Total 2, 16,183 12,278 11183 999.58


.

he power nt

Inca(M

s Gen (MUs)

Name of tPla

stalled pacity

W)

Gros eration

Hydro Power Plants Tamilnadu (2003-04) (2004-05) (2005-06) Pykara 70.00 141 213 257 Pykara Dam 2.00 0 5 11 Moyar 36.00 53 90 175 Kundah I- V 5 1 155.00 429 ,567 972 Mettur Dam 40.00 15 26 90 Mettur Tunnel 200.00 70 309 639 Periyar 1 213 493 440.00 41 Kodayar 100.00 141 207 245 Sholayar 95.00 199 350 379 Aliyar 6 86 162 20.00 06 Sarkarpathy 30.00 51 115 1 15 Papanasam 28.00 47 89 13 0 Suruliyar 3 41 101 125.00 6 Servalar 2 19 35 0.00 54 Lower Mettur 1 2 320.00 97 55 41 Kadamparai 4 408 200.00 57 581 Vaigai 6.00 5 12 18 Lower Bhavani 16.00 9 62 63 Sathanur 7.5 2 10 23

Name of the power Instacap(MW)

Gross G ation (MU

Plant

lled acity

ener s)

Diesel power plants Tamilnadu (2003-0 2004-05 (2005-06)4) ( ) GMR Vasavi 2 99200.00 762 745 Samalpatti 10 458 3 333 6.00 57 Madurai 10 457 382 326.00 9 Andhra Pradesh L V S Power 3 0 6.80 0 0 Karnataka Yelhanka 12 384 20.00 71 97 Bellary 25.20 42 40 17 Belgaum 81.30 235 238 133 Kerala Bramhapuram 1 266 13 56 06.50 6 Kojikode 1 313 161 93 28.80 Kasargode 78 1 8 21.90 6 Total 9 3,225 762.22 1811 32.50


.

Parsons Valley 30.00 18 56 53 Pykara ULT 1 150.00 0 0 89 Andhra Pradesh Machkund 114.70 529 901 628 Upper Sileru 240.00 401 544 473 Lower Sileru 460.00 977 1,171 1037 T.B.Dam 36.00 102 148 168 Hampi 36.00 0 0 58 Nagarjunasagar 1810.00 369 502 560 NS Right Canal 290.00 0 48 74 NS Left Canal 60.00 0 5 121 Donkarayi 2 111 132 15.00 15 Srisailam Right 77 30 94 1490.00 9 1 0 Srisailam Left 1 2900.00 328 ,412 233 Pochampad 27.00 64 2 112 Nizamsagar 10.00 6 0 10 Penna Ahobilam 20.00 0 0 10 Singur 15.00 6 1 9 Mini Hydro 30.00 8 6 25 Kerala Kuttiadi 125.00 259 371 516 Idukki 780.00 1,246 2,003 2699 Sabarigiri 300.00 1469 698 1,225 Idamalayar 75.00 155 338 375 Kakkad .00 126 210 249 50Sholayar 54.00 202 263 290 Sengulam 48.00 128 167 189 Narimanglam 45.00 196 232 245 Pallivasal 37.50 93 3 1 22 238 Poringalkuttu 32.00 142 182 165 Poringalkuttu l 6.00 88 108 105 1Panniar 30.00 76 160 142 Kallada 36 64 15.00 77 Lower periyar 63 2 631 180.00 3 51Malankara 0 3 20 10.50Chembukadavu 6.50 0 6 11 Urumi 6.20 0 1 13 Peppara 3.00 1 6 6 Madhupatty 2.00 8 4 5 Other hydro 5.00 0 0 41 Maniyar 10.00 21 34 48 Kuthungal 21.00 19 36 516 Karnataka Jog 174 238 120.00 160 Si rum 192 vasamund 42.00 79 261

PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 02 CDM – Executiv

.

e Board

Shimsapura 17.20 57 94 93 Munirabad 27.00 69 83 41 Sharavathy 891.00 3,316 3,854 4,866 Kadra 150.00 223 231 346 Kodasali 120.00 214 215 314 Kalinadi 810.00 1,718 1,720 2,162 Kalinadi Supa 100.00 241 295 358 Liganamakki 55.00 120 194 276 Varahi 230.00 721 973 972 Bhadra 33.40 11 41 76 Ghat Prabha 32.00 62 97 123 Mani DPH 9.00 11 23 21 Malllarpur 9.00 0 0 0 Gerusuppa 240.00 358 438 557 Almatti DPH 125.00 0 139 599 Shivpura 18.00 54 72 86 Shahpur 6.60 22 25 22 Harangi 9.00 0 0 0 Mad mantri 3.00 13 hava 23 23 Narayanpur 6.60 38 42 6 Total 10,532.20 16,670 25,280 33,506

Name of the power Plant

Installed capacity (MW)


Nuclear power plants Tamilnadu (2003-04) (2004-05) (2005-06)

Ka 340.00 1,577 1,480 lpakkam

1,853

Karnataka

Kaiga 440.00 3,123 2,926

2,860

Total 780.00 4,700 4,406 4,713 Source: CEA Annual generation Report, 2003-04, 2004-05 and 2005-06

Data considered for emission calculation

Type of Auxiliary Net Heat Rate Carbon Remarks

PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 02 CDM – Executiv

.

e Board

Generation Consumption, %

kCal/kW emission ( h)factor (tc/TJ)

Coal 825.

Lignite

8.3

6

All Govt. Coal and Lignite based w la , al lu r

consumption for every power plant was taken from Section 13, CEA Report (Review of

n m Po

Gross Heat Rate and auxiliary va

h o tion CEA Report 2004-2005. Carbon emission factor as per IPCC

2700

27.

poHeat Rate and auxiliary

er p nts actu va e of G oss

performStations2004-05). For private Coal and Lignite based power plants

a ce of Ther al wer

consumof

ption use the average Sout

lue 13 ern Regi n: Sec

Guidelines.

Gas 1 2929

Gas (CCGT) 3

x y t a eat for gas power plant is taken from

(Baseline projects under clean development mechanism). Carbon emission factor as per IPCC Guidelines.

2062

15.3

Au iliar consump ion nd h rate

TERI project report No 2000RT64 for Renewable Energy

Diesel 4

ption and from TERI project report No 2000RT64 (Baseline for Renewable

echanism . Average a of all power plants in Southern

Region is considered. Carbon ission factor as IPid e

2062 20.2

Diesel power plants AuxiliaryConsum

heat rate was taken

Edevelopmv

nergy

lue

pent m

rojects under )

clean

emGu

per CC elin s.

PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 02 CDM – Executive Board page lxii

BASELINE CALCULATION FOR THE YEAR 2005-06

Power Plant Installed capacity

(MW)

Fuel type

Gross Heat rate (kCal/kWh)

Gross Heat Rate Tj/MWh


Auxiliary consumptio

n (%)

Net Generation

(MUs)

Net Heat Rate

(kCal/kWh)

Carbo

Net Heat Rate

Tj/MWh

n Emission Factor tC/TJ

Mass Conversion Tco2/Tc

CO2 emissio

n (Tons/MWh)

CO2 emissions

(05-06) tons

Tamilnadu

450.00 Coal 32440.01357

9Ennore 601 12.3 527 3697 0.015477 25.8 3.67 1.4654 772

1050.00 Coal 24930.01043

6 7674 7.9 7070 2706 0.011327 25.8 3.67 1.0725 75Tuticorin 83

Mettur 840.00 Coal 26220.01097

6 6519 8.3 5977 2860 0.011972 25.8 3.67 1.1336 6775

North Chennai 630.00 Coal 2450.01028

1 4001 9.2 3633 2705 0.011321 25.8 3.67 1.0720 386 95

NLC I * 600.00 Lignite 39810.01666

3990 10.7 3565 4456 0.018653 27.6 3.67 1.8894 64 736

NLC II * 1470.00 Li 28710.01201

8 9174 8.7 8372 3146 0.013169 27.6 3.67 1.3339 11167 gnite

NLC I Ext 420.00 Li 27000.01130

gnite 2 3082 9.0 2805 2967 0.012420 27.6 3.67 1.2580 3529

NLC 0 Unit 250.0 0 Lignite 2700.01130

2 1450 8.3 1330 2944 0.012323 27.6 3.67 1.2482 10 661 Andhra Pradesh

Vijayawada 1260.00 Coal 24350.01019

3 9755 9.6 8821 2693 0.011273 25.8 3.67 1.0674 9415 .

PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 02 CDM – Executive Board page lxiii

Rayalaseema 420.00 22880.00957

8Coal 2369 9.4 2147 2525 0.010569 25.8 3.67 1.0007 2148

Kothagudem 1180.00 Coal 25940.01085

8 8213 8.8 7491 2844 0.011905 25.8 3.67 1.1272 8444

Ramagundam B 62.50 Coal 27230.01139

8 397 9.0 361 2992 0.012526 25.8 3.67 1.1860 429

Nellore 30.00 Coal 27000.01130

2 7 9.0 7 2967 0.012421 25.8 3.67 1.1761 8 Ramagundam STPS 2600.00 Coal 2700

0.011302 19691 6.6 18393 2890 0.012100 25.8 3.67 1.1457 21073

SIMHADRI 1000.00 Coal 2700.01130

2 774 5. 730 286 0.01197 25. 3.6 1.134 8280 1 7 4 2 9 8 7 2 5 Karnataka

Raichur 1470.00 Coal 24970.01045

2 9173 8.8 8364 2739 0.011464 25.8 3.67 1.0854 9079

Torangallu IMP 260.00 Coal 27000.01130

2 1383 8.3 1268 2944 0.012323 25.8 3.67 1.1668 1480 Tamilnadu

Basen Bridge 120.00 Gas 34870.01459

5 40 1.0 39 3522 0.014743 15.3 3.67 0.8278 33 Nariman 10.00 Gas 0 0 0.0 2929 0.012261 15.3 3.67 0.68850 0

Kovilkalapal 107.88 Gas 19860.00831

3 573 1.0 567 2006 0.008397 15.3 3.67 0.4715 267 Valantharvi 52.80 Gas 0 98 1.0 97 2929 0.012261 15.3 3.67 0.6885 67

Valuthur 95.00 Gas

(CCGT) 2107 0.00882 697 3.0 676 2172 0.009093 15.3 3.67 0.5106 345 Karuppur 119.80 Gas 0 357 1.0 354 2929 0.012261 15.3 3.67 0.6885 244

Kuttalam 101.40 Gas

(CCGT) 3000.01256

8 674 3.0 654 3095 0.012956 15.3 3.67 0.7275 472 6

PP Nallur 330.50 Gas

(CCGT) 0 42 3. 41 206 0.00862 15. 3.6 0.484 209 0 6 1 7 3 7 4 2 Andhra Pradesh Vijjeswaram Gas Station 272.30

Gas (CCGT) 0 1837 3.0 1782 2062 0.008632 15.3 3.67 0.4847 864

Peddapuram 220.00 Gas 2022 0.00846 842 3.0 817 2084 0.008724 15.3 3.67 0.4898 400

.

PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 02 CDM – Executive Board page lxiv

CCGT (CCGT) 2

Jegurupadu 455.40 Gas (CCGT) 2074

0.008681 1294 3.0 1255 2138 0.008950 15.3 3.67 0.5025 631

Kondapalli GT 350.00 Gas (CCGT) 1969

0.008241 2116 3.0 2053 2030 0.008496 15.3 3.67 0.4771 979

Godavari 208.00 Gas (CCGT) 2719

0.011382 1331 3.0 1291 2803 0.011734 15.3 3.67 0.6589 851

Karnataka

Tanir Bavi 220.00 Gas 2075

0.008686 241 3.0 234 (CCGT) 2139 0.008955 15.3 3.67 0.5028 118

Kerala

Cochin 174.00 Gas

(CCGT) 18580.00777

8 37 3.0 36 1916 0.008018 15.3 3.67 0.4502 16

Kayamkulam 350.00 Gas

(CCGT) 19800.00828

9 359 3.0 348 2041 0.008546 15.3 3.67 0.4798 167 Pondichery

PPCL G.T.G 32.50 Gas

( 2480.01038

4 257 3.0 249 255 0.01070 15. 3.6 0.601 15CCGT) 1 7 6 3 7 1 0 Tamilnadu

GMR Vasavi 200.00 Diesel 2020.00846

9 745 4.0 716 210 0.00882 20. 3.6 0.654 463 8 2 2 7 0 8

Samalpatti 106.00 Diesel 21580.00903

5 333 4.0 319 2248 0.009411 20.2 3.67 0.6977 223

Madurai 106.00 2150.00903

4 329 4.0 315 224 0.00941 20. 3.6 0.697 22Diesel 8 8 1 2 7 7 0 Andhra Pradesh L V S Power 36.80 Diesel 0 0 4.0 0 206 0.00863 20. 3.6 0.6392 2 2 7 9 0 Karnataka

Yelhanka 127.80 2082.0.00871

7 97 4.0 93 216 0.00908 20. 3.6 0.673 6Diesel 4 9 0 2 7 1 2 Bellary 25.20 Diesel 0 17 4.0 17 2062 0.008632 20.2 3.67 0.6399 11 Belgaum 81.30 2130.3 0.00891 133 4.0 128 221 0.00928 20. 3.6 0.688 8Diesel 9 9 9 2 7 7 8

.

PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 02 CDM – Executive Board page lxv

8Kerala

Bramhapuram 10 6.60 Diesel 2170.40.00908

5 56 4.0 53 226 0.00946 20. 3.6 0.701 34 1 4 2 7 6 8

Kojikode 128.80 Diesel 2110.20.00883

3 93 4.0 90 2198 0.009201 20.2 3.67 0.6821 61 Kasargode 21.90 Diesel 0 8 4.0 8 2062 0.008632 20.2 3.67 0.6399 5 Tamilnadu Pykara 70.00 Hydro 257 0.5 256 Pykara Dam 2.00

Hydro 11 0.5 10 Moyar 36.00 Hydro 175 0.5 175 Kundah I- V 555.00

Hydro 1972 0.5 1962 Mettur Dam 40.00

Hydro 90 0.5 90 Mettur Tunnel 200.00

Hydro 639 0.5 636 Periyar 140.00 Hydro 441 0.5 439 Kodayar 100.00 Hydro 245 0.5 243 Sholayar 95.00 Hydro 379 0.5 377 Aliyar 60.00 Hydro 206 0.5 205 Sarkarpathy 30.00

Hydro 115 0.5 115 Papanasam 28.00

Hydro 130 0.5 129 Suruliyar 35.00 Hydro 12 0. 126 5 5 Servalar 20.00 Hydro 54 0.5 54 Lower Mettur 120.00

Hydro 341 0.5 340 Kadamparai 400.00

Hydro 581 0.5 579

.

PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 02 CDM – Executive Board page lxvi

Vaigai 6.00 Hydro 18 0.5 18 Lower Bhavani 16.00

Hydro 63 0.5 63 Sathanur 7.5 Hydro 23 0.5 23

Parsons Valley 30.00 Hydro 53 0.5 53 Pykara ULT

150.00 Hydro 189 0.5 188 Andhra Pradesh Machkund 114.90 Hydro 628 0.5 625 Upper Sileru 240.00 Hydro 473 0.5 471 Lower Sileru 460.00 Hydro 1037 0.5 1032 T.B.Dam 36.00 Hydro 168 0.5 167 Hampi 36.00 Hydro 58 0.5 57 Nagarjunasagar 810.00 Hydro 1560 0.5 1552 NS Right Canal 90.00 Hydro 274 0.5 273 NS Left Canal 60.00 Hydro 121 0.5 120 Donkarayi 25.00 Hydro 11 0. 115 5 4 Srisailam Right 770.00 Hydro 1490 0.5 1483 Srisailam Left 900.00 Hydro 2233 0.5 2222 Pochampad 27.00 Hydro 112 0.5 111 Nizamsagar 10.00 Hydro 10 10 0.5 Penna Ahobilam 20.00 Hydro 10 0.5 10

15.00 Hydro 9 9 Singur 0.5 Mini Hydro 15.00 Hydro 25 0.5 25

Kerala KUTTIADI 125.00 Hydro 516 0.5 513

780.00 Hydro 2 2685 IDUKKI 699 0.5 SABARIGIRI 300.00 Hydro 1469 0.5 1461 IDAMALAYAR 75.00 Hydro 3 374 75 0.5 KAKKAD 50.00 Hydro 249 0.5 247 SHOLAYAR 54.00 Hydro 2 289 90 0.5

.


e Board page lxvii

SENGULAM 48.00 Hydro 189 0.5 188 NARIMANGLAM 45.00 Hydro 245 0.5 244 PALLIVASAL 37.50 Hydro 238 0.5 237 PORINGALKUTTU 32.00 Hydro 165 0.5 164 PORINGALKUTTU L 16.00 Hydro 105 0.5 105 PANNIAR 30.00 Hydro 160 0.5 159 KALLADA 15.00 Hydro 64 0.5 64 LOWER PERIYAR 180.00 Hydro 631 0.5 628 MALANKARA 10.50 Hydro 20 0.5 20 CHEMBUKADAVU 6.50 Hydro 11 0.5 11 URUMI 6.20 Hydro 13 0.5 13 PEPPARA 3.00 Hydro 6 0.5 6 MADHUPATTY 2.00 Hydro 5 0.5 5 MANIYAR 10.00 Hydro 41 0.5 41 KUTHUNGAL 21.00 Hydro 48 0.5 48 Karnataka Jog 139.20 Hydro 238 0.5 237 Sivasamundrum 42.00 Hydro 261 0.5 259 Shimsapura 17.20 Hydro 93 0.5 93 Munirabad 27.00 Hydro 83 0.5 83 Sharavathy 1006.20 Hydro 4866 0.5 4841 Kadra 150.00 Hydro 346 0.5 344 Kodasali 120.00 Hydro 314 0.5 312 Kalinadi 855.00 Hydro 2162 0.5 2151 Kalinadi Supa 100.00 Hydro 358 0.5 356 Liganamakki 55.00 Hydro 276 0.5 274

CDM – Executiv

.

Varahi 230.00 Hydro 972 0.5 967 Bhadra 39.20 Hydro 76 0.5 76 Ghat Prabha 32.00 Hydro 123 0.5 122 Mani DPH 9.00 Hydro 21 0.5 21


CDM – Executiv

.

Malllarpur Gerusuppa Almatti DPH Shivpura Shahpur Harangi Madhavamantri Mandagere Narayanpur Tamilnadu Kalpakkam Karnataka Kaiga

e Board page lxviii

9.00 Hydro 0 0.5 0 240.00 Hydro 557 0.5 554 290.00 Hydro 599 0.5 596

18.00 Hydro 86 0.5 85 6.60 Hydro 22 0.5 22 9.00 Hydro 0 0.5 0 4.50 Hydro 23 0.5 23 3.50 Hydro 6 6.60 Hydro 56 0.5 56

390.00 Nuclear 1853 1853

440.00 Nuclear 2860 2860

Source: All Power Plants Gross Power Generation from CEAs Month wise Performance Status Report All Govt . Coal and Lignite based power plants Gross Heat Rate: Section 13 CEA Report (Actual value of every power plants) All Govt . Coal and Lignite based power plants Auxiliary Consumption: Section 11, CEA Report (Actual value of every power plants) All private Coal and Lignite based power plants Gross Heat Rate: Section 13 CEA Report (Average Value of Southern Region) All private Coal and Lignite based power plants Auxiliary Consumption: Section 11, CEA Report (Average Value of Southern Region) All Govt .and Private Gas based power plants Net Heat Rate : Page No:31,Table 2.4, TERI Report ( Average value of all power plants in Southern Region ) All emission factor from IPCC guideline


.

BUILD MARGIN

S.No Power plant

Installed Capacity in MW Fuel

Net Power Generation in GWh

Emission factor

TCO2/MWh

Emission TCO2/year

1

R'gundam STPS 2600 Coal 18,393 1.1457 21,073

2

Valuthur CCGT 95 Gas 676 0.5106 345

3 Raichur 1470 Coal 8,364 1.0854 9,079

4 Peddapuram CCGT 220 Gas 817 0.4898 400

5 Simhadri 1000 Coal 7,304 1.1342 8,295

Total 5385 35,554 39,192

Operating Margin

Build Margin Combined Margin

Net Power Generation in mu

100,043 35,554

CO2 Emission 109,460

39,192

Emission factor

1.094

1.102

1.098


.

Carbon-dioxide emission by the project due to burning of 20 % coal at project site: Other than biomass, maximum 20 % Coal also allowed to use as fuel instead of biomass. The CO2

released by the 20 % coal is calculated as follows.


Where

C.Ec - Carbon-dioxide emission due to coal burning at project site MT

Q - Quantity of coal burned in MT

C.Vc - Calorific value of coal burned Tj/Ton

E.Fc - IPCC Standard emission factor Ton of co2/Tj

Plant Capacity : 21 MW

Plant Load Factor : 80 %

Gross power generation : 147,168 mu/year

Calorific value of the Imported coal (C.Vc) : 6,400 kCal/kg

(or) 0.0267 Tj/kg

Design Heat Rate of the proposed power plant : 3 680 kCal/kWh

IPCC Standard emission factor for coal (E.Fc) : 94.68 Tons of co2/Tj

Quantity of coal required for the power plant (if 20 %) = Gross power generation* Heat Rate*0.20 Calorific value of the coal = 147 168 * 3680*0.20 6,400 Quantity of coal burned (Q) = 16 924 tons of coal/year

Carbon-dioxide emission (C.Ec ) = Q * C.Vc *E.Fc

= 16 924 * 0.02679 * 94.68

= 42 927 Ton of CO2/year

= 42 927 Ton of CO2/year


.

Annex 4

MONITORING PLAN

Please refer to section D of this PDD.

Annex 5


.

BIOMASS AVAILABILITY

Major Biomass Potential at Sivagangai - A Glance

Primary Biomass : 1 Prosopis juliflora

(Woody Biomass) 2 Eucalyptus

Secondary Biomass : 1 Coconut Residue

2 Chilly Stalks

3 Sugarcane Trash

Total Surplus Biomass : 879,921 tons/year

MAJOR BIOMASS DETAILS - A GLANCE

Details Biomass I 1 Name of the Biomass Prosopis Juliflora 2 Generation Point Waste Land 3 Surplus biomass (tons /y)

358,308

4 Present Use Domestic & Industries fuel

Cost of Fuel at Site (Rs. per ton) 1100 - 1200

Fuel Cost at Source (Rs. Per ton) 800 -850

Transportation Cost (Rs. Per ton) 200 -225

5

Load & Unload Cost (Rs. Per ton) 100 -125

6 Moisture Content at Source % 10 to 15

7 Seasonality Throughout the Year

8 Calorific Value (Kcal/kg) (on air dry basis) 4225

Annex 5…contd.

Annex 5..Contd..


.


Details Biomass II 1 Name of the Biomass Eucalyptus wood 2 Generation Point Agro- Field 3 Surplus biomass (tons /y)

308,350

4 Present Use Domestic fuel, Industrial Fuel

and Raw material for paper mill

5 Cost of Fuel at Site (Rs. per ton) 1100 - 1200

Fuel Cost at Source (Rs. Per ton) 800 -850

Transportation Cost (Rs. Per ton) 200 -225

Load & Unload Cost (Rs. Per ton) 100 -125

6 Moisture Content at Source % 10-15 7 Seasonality Throughout

the Year 8 Calorific Value (Kcal/kg)

(on air dry basis) 3 888

Annex 5…contd.


.

MAJOR BIOMASS DETAILS - A GLANCE Details Biomass III

1 Name of the Biomass Coconut Residue 2 Generation Point Agro- Field 3 Surplus biomass

(tons/y) 42,893

4 Present Use Domestic fuel, Thatching material

5 Cost of Fuel at Plant

(Rs. per ton) 650 -750

Fuel Cost at Source (Rs. per ton)

400-450

Transportation Cost (Rs. per ton) 150 -200

Load & Unload Cost (Rs. per ton.) 100 -125

6 Moisture Content at Source %

25-30

7 Seasonality Throughout the Year

8 Calorific Value (Kcal/kg) (on air dry basis)

3 722

Annex 5…contd.


.


Details Biomass IV 1 Name of the Biomass Chilly Stalks 2 Generation Point Agro- Field 3 Surplus biomass

(tons/y) 155,269

4 Present Use Fodder and Domestic Fuel

5 Cost of Fuel at Plant (Rs. per ton)

500-650


200-250

Transportation Cost (Rs. per ton)

200-250

Load & Unload Cost (Rs. Per ton.)

100-150


20-25

7 Seasonality

Throughout


(on air dry basis) 3300

9 Biomass Preprocessing Required

No

Annex 5…contd.


.


Details Biomass V 1 Name of the Biomass Sugar cane Trash 2 Generation Point Agro- Field 3 Surplus biomass

(tons/y) 15,102

4 Present Use Fodder and Domestic Fuel

5 Cost of Fuel at Plant (Rs. per ton)

500-650


200-250

Transportation Cost (Rs. per ton)

200-250

Load & Unload Cost (Rs. per ton.)

100-150


20-25

7 Seasonality

Throughout


(on air dry basis) 3295


.

Annex 6

The Power Scenario in India

Power Generation and Distribution System in India In India, power is a concurrent subject between the state and the central governments. The perspective

planning, monitoring of implementation of power projects is the responsibility of Ministry of Power,

Government of India. At the state level the state utilities or State Electricity Boards (SEBs) are

responsible for supply, transmission, and distribution of power. In addition, there are different central/

public sector organizations involved in generation like National Thermal Power Corporation (NTPC),

National Hydro Power Corporation (NHPC), etc. in transmission e.g. Power Grid Corporation of India

Ltd. (PGCIL) and in financing e.g. Power Finance Corporation Ltd. (PFC).

There are five regional grids in India: Northern, Western, Southern, Eastern and Northeastern. Different

states are connected to one of the five regional grids as shown in the below table.

Regional Grid States

Northern Mariana, Hibachi Pradesh, Jammu & Kashmir, Punjab, Rajasthan, Uttar

Pradesh, Uttaranchal, Delhi

Western Gujarat, Madhya Pradesh, Maharashtra, Goa, Chattisgarh

Southern Andhra Pradesh, Karnataka, Kerala, TamilNadu, Pondicherry

Eastern Bihar, Orissa, West Bengal, Zarkhand

North Eastern Arunachal Pradesh, Assam, Manipur, Meghalaya, Mizoram, Nagaland,

Tripura.

The management of generation and supply of power within the state and regional grid is undertaken by

the State Load Dispatch Centers (SLDC) and Regional Load Dispatch Centres (RLDC). Different states

within the regional grids meet the demand from their own generation facilities plus generation by power

plants owned by the central sector i.e. NTPC and NHPC etc. Depending on the demand and generation

there are exports and imports of power within different states in the regional grid. Thus there is an

exchange of power among states in the regional grid. Similarly there exists imports and export of power

between regional grids.


.

Power Generation and Distribution System in Southern Region The project is located in the state of Tamilnadu and connected to the Southern Grid. The southern grid is

common to the four southern states viz. Tamilnadu, Karnataka, Andhra Pradesh and Kerala and one

Union territory, Pondicherry. There is also a common load dispatch centre, namely the “Southern Region

Load Dispatch Centre’ (SRLDC). The four states covered by the southern grid – Andhra Pradesh,

Karnataka, Kerala, Tamilnadu and Pondicherry, have different generation mix.

Promotion of Renewable Energy India’s search for alternative fuels that would ensure sustainable development on the one hand and energy

security on the other began in 1970 itself. Consequently, new and renewable sources of energy have

emerged as an option. Thus India has established policy to tap the potential for renewable energy sources

such as solar, wind, biomass, and small hydro, irrespective of capacity. The Indian scientific

establishment has been working on the development of various renewable energy systems. In 1981, the

Government of India established a Commission for Additional Sources of Energy (CASE) in the

Department of Science and Technology, on the lines of the Space and Atomic Energy Commissions. The

mandate of CASE is to promote R & D activities in the field of renewable energy. CASE was

incorporated in 1982, in the newly created Department of Non-conventional Energy Sources (DNES). In

1992 DNES became the Ministry for Non-conventional Energy Sources.

Renewable Energy Technologies (RETs) hold a lot of promise for India for meeting the burgeoning

electricity requirement and providing energy in rural areas. At present 46 percent of the total energy

consumption is met from various biomass resources i.e. agricultural residues, animal dung, forest wastes,

firewood, etc. India produces a huge quantity of agricultural residues, which can be converted into

energy. The share of renewable in the total power generation capacity of the country have started bearing

fruit.

After persistent pursuance of MNES with the state governments/utilities for implementing a uniform

Renewable Energy power purchase policy since 1992-93, so far 15 of 26 states have announced policies

for grid-connected Renewable energy power projects; still these policies are in varying degrees as

compared to those recommended by MNES.

Though the Electricity Act 2003 contains several provisions to promote accelerated development of

power generation from Renewable energy, the timely intervention and the extent of implementation of

such provisions it yet to be witnessed.


.

There has been a shift in policy away from investment- based to performance based fiscal and financial

incentives and even phasing out of subsidies in few sectors.

What the sector requires now is a synergy between central and state policies towards attracting private

investment in Renewable energy sector, enhanced access to financing and acceleration of indigenous

R&D activities.

In case of renewable energy, there is a strong need for:

Preparation of “private investment plan” for the (high) potential renewable energy sectors based on the consolidation of updated RERA data by the state governments

Accelerate indigenous research and development in developing state-of-art technologies utilizing

renewable energy resources and showcase such technologies through demonstration projects.

Provide easy access to financing renewable energy projects.

Sensitisation of State Electricity Regulatory Commissions (SERCs) in enhancing use of renewable energy based power using Electricity Act 2003 as a promoting tool.

Involve Corporate Sector in propagating renewable energy by implementing few renewable

energy projects both at urban and at rural levels. Promotion of Biomass Energy The promotion of biomass based power generation in the country is being encouraged through conductive policies at the Central and the State levels. A number of policy initiatives have been introduced for encouragement to commercial exploitation of biomass power potential since 1993. Incentives include sales tax and excise duty exemption, reduced customs duty, accelerated depreciation, etc. Electricity Regulatory Commissions set up in the States of Tamilnadu, Andhra Pradesh, Karnataka & Maharashtra have also noted the relevance of these technologies and hence announced policies for purchase/wheeling/banking of power generated from biomass power/co-generation projects.


.

Commissioned capacity of Biomass power projects in India State

Biomass Power MW

Andhra Pradesh 182.20 Chattisgarh 11.00 Gujarat 0.50 Haryana 4.00 Karnataka 36.00 Madhya Pradesh 1.00 Maharashtra 3.50 Punjab 10.00 Rajasthan 7.80 Tamilnadu 34.00 Total 290.00

Source: MNES Annual Report 2004-05


.

REFERENCES

1 Kyoto Protocol to the United Nations Framework Convention on Climate Change (UNFCCC)

2 Website of United Nations Framework Convention on Climate Change, http://unfccc.int

3 UNFCCC decision 17/CP.7: Modalities and procedures for a clean development mechanism as defined in article 12 of the Kyoto Protocol

4 UNFCCC, Clean Development Mechanism, Project Design Document (CDM-PDD)

5 UNFCCC document: Approved consolidated baseline methodology ACM0006.“Consolidated baseline methodology for grid-connected electricity generation from biomass residues”

6 Detailed project report on 21 MW Biomass based power project – Aurobindo Agro Energy Limited

7 Baseline for Renewable energy projects under clean development mechanism-TERI Report No 2000RT64

8 Biomass Resource Assessment study for sivagangai district

9 Website of Central Electric Authority (CEA), Ministry of Power, Govt. of India- www.cea.nic.in

10 Website of Ministry Non-Conventional Energy Sources (MNES), Government of India, www.mnes.nic.in

11 Website of Indian Renewable Energy Development Agency (IREDA), www.ireda.nic.in

12 Website of TNERC www.tnerc.tn.nic.in

13 Website of Kerala Electricity Board www.kseboard.com

14 Website of Karnataka Power Transmission Corporation Limited www.kptcl.com

15 Website of Anthrapradesh Power Generation Company www.apgenco.com

16 Website of TamilNadu Electricity Board www.tneb.org


.

Appendix A Abbreviations

AAEPL Aurobindo Agro Energy Pvt,Ltd. CDM Clean Development Mechanism CEA Central Electricity Authority CER Certified Emission Reductions cm Centimetre CO2 Carbon dioxide DPR Detailed Project Report GHG Greenhouse Gas IPCC Intra governmental Panel for Climate Change IPP Independent Power Producers kCal Kilo Calories kg Kilogram Km Kilometre KP Kyoto Protocol Ksca Kilogram Square Centimetre absolute kv Kilo voltage kW Kilowatt kWh Kilowatt hour LP Low Pressure MNES Ministry of Non-Conventional Energy Sources MT Metric Tons MU Million Units MW Megawatt NGO Non Government Organizations NOC No Objection Certificate PDD Project Design Document PIN Project Idea Note PLF Plant Load Factor PPA Power Purchase Agreement QA Quality Assurance QC Quality Control SIPCOT State Industrial Promotion Corporation of

TamilNadu TEDA TamilNadu Energy Development Agency TNEB TamilNadu Electricity Board TNERC TamilNadu Electricity Regulatory Commission

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AUROBINDO AGRO ENERGY PRIVATE LIMITED. 21 … · The 21 MW grid connected biomass based power plant has been implemented ... (TNEB) grid based on a 15 year Power ... thermal power