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PROJECT DESIGN DOCUMENT FORM (CDM-SSC-PDD) - Version 03
CDM – Executive Board
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CLEAN DEVELOPMENT MECHANISM
PROJECT DESIGN DOCUMENT FORM (CDM-SSC-PDD)
Version 03 - in effect as of: 22 December 2006
CONTENTS
A. General description of the small scale project activity
B. Application of a baseline and monitoring methodology
C. Duration of the project activity / crediting period
D. Environmental impacts
E. Stakeholders’ comments
Annexes
Annex 1: Contact information on participants in the proposed small scale project activity
Annex 2: Information regarding public funding
Annex 3: Baseline information
Annex 4: Monitoring Information
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Revision history of this document
VersionNumber
Date Description and reason of revision
01 21 January
2003
Initial adoption
02 8 July 2005 • The Board agreed to revise the CDM SSC PDD to reflect
guidance and clarifications provided by the Board since
version 01 of this document.
• As a consequence, the guidelines for completing CDM SSC
PDD have been revised accordingly to version 2. The latest
version can be found at
<http://cdm.unfccc.int/Reference/Documents>.
03 22 December
2006
• The Board agreed to revise the CDM project design
document for small-scale activities (CDM-SSC-PDD), takinginto account CDM-PDD and CDM-NM.
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SECTION A. General description of small-scale project activity
A.1 Title of the small-scale project activity:
>>
Yennehole - 1 Mini Hydel Scheme
Version 03
28/04/2010
A.2. Description of the small-scale project activity:
>>
The proposed project activity is a 15MW run-of-river hydro power plant located in the state of
Karnataka, India. The project envisages utilizing the flow of the Swarna river originating at
Kudaremukh, Chikkamangalore district wherein the catchment area receives rainfall. The development
of the project activity would reduce greenhouse gas (GHG) emissions produced by the regional grid
generation mix which is mainly dominated by fossil fuel based power plants. Emission reduction fromhydroelectric power projects arise as they replace grid electricity with a zero-emission source of
electricity generation.
The project relates to the establishment of three 5000kW turbine generators to produce electricity to
export to the Southern grid through sale to the Karnataka Power Transmission Corporation Ltd
(KPTCL). A power purchase agreement will be entered into with the KPTCL for the export of the
electricity. The project activity has chosen a renewable crediting period and is expected to reduce 39,049
tCO2e per year. In the absence of the project activity the electricity will continue to be generated by the
existing generation mix operating in the grid.
Contribution of the project activity to sustainable development
The project activity will contribute to sustainable development through socio-economic development in
the region. The proposed project activity will generate new job opportunities for the local community
and hence help in development of basic amenities leading to an improvement in living standard of the
local community. People from the local area will be employed during the construction and operation
phase of the project activity which will indirectly lead to economic benefits in the area. The project
activity will also improve connectivity of the area through the construction of roads to the site which will
benefit the villagers located on and nearby these roads. The project is run-of river and hence there is no
displacement of population and no rehabilitation and resettlement (R&R) issues occur.
Contribution of the project activity to environmental well being
Through the generation of hydro electricity for supply to the grid the project activity will have a direct
environmental benefit. The generation of power from hydro has long term benefits related to climatechange given that the alternative is a fossil fuel based generation system. Local pollution will be reduced
as hydro power is a zero emission source. The project does not invoice any environmental impacts and
there are no adverse effects on the flora and fauna.
A.3. Project participants:
>>
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Name of Party involved (*)
((host) indicates a host
Party)
Private and/or public entity (ies)
project participants
(as applicable)
Kindly indicate if the Party
involved wishes to be considered as
project participant (Yes/No)
India (host) Private Entity: GVP InfraProjects Pvt. Ltd.
No
United Kingdom Private Entity: Agrinergy Pte Ltd No
(*) In accordance with the CDM modalities and procedures, at the time of making the CDM-PDD
public at the stage of validation, a Party involved may or may not have provided its approval. At
the time of requesting registration, the approval by the Party(ies) involved is required.
Contact details as listed in Annex 1.
A.4. Technical description of the small-scale project activity:
A.4.1. Location of the small-scale project activity:
>>
A.4.1.1. Host Party(ies):
>>
India
A.4.1.2. Region/State/Province etc.:
>>
Karnataka
A.4.1.3. City/Town/Community etc:
>>District Udupi, Taluk Karkala
A.4.1.4. Details of physical location, including information allowing the
unique identification of this small-scale project activity :
>>
The project is proposed on Swarna river which originates at Kudaremukh, Chikkamangalore district in
Karnataka State. The power station is located near downstream of existing barrage/ Road Bridge
connecting Jarkala and Karkala near Tallaru village on Swarna river. The geographical coordinates1 of
the project activity location are:
Latitude: 13° 35’ N
Longitude: 74° 75’ E
The location of the project is highlighted in the map below:
1 http://www.fallingrain.com/world/IN/19/Udipi.html
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A.4.2. Type and category(ies) and technology/measure of the small-scale project activity:
>>
Sectoral Scope 1: Energy Industries (Renewable/non-renewable sources)
Type I: Renewable Energy Projects
Category D: Grid Connected renewable energy generation
Project
Activity
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The project produces renewable energy by utilizing hydro power as an energy source and converting the
potential energy available in the water flow into mechanical energy using turbine and then to electrical
energy using generators.
The proposed project activity is a run-of-river development without any storage of water, utilizing the
water of Swarna river by harnessing a maximum gross head of 12.5m. Allowing a loss of 0.5m in the
head regulator penstock the net head available is 12m to generate 15MW of power. The project proposes
to install three generating sets of 5000kW each and total design discharge of 149m3 /s. After power
generation the water is discharged into the stream through a 175m long tail race channel.
The power will be generated at 11kV and will be evacuated through a 110kV transmission line to be
terminated at the Karkala sub-station and finally fed into the Southern grid of India.
The principal technical parameters of the scheme are as follows:
TURBINE
Type of turbine Horizontal Full Kaplan ‘S’
type
Number of Units 3
Rated capacity (kW) 5000
Continuous overloading 20%
Speed (rpm) 1500
Runner diameter (mm) 2900
GENERATOR
Type Synchronous
Rated capacity (kW) 5000
Power factor 0.85
Voltage (V) 415
Frequency (Hz) 50
Speed (rpm) 750
PENSTOCK
Length of penstock 50m
Diameter of penstock 4m
The main operational parameters are:
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Tail water level EL 19.5m
Design discharge/ unit 49.7 m3 /sec
Catchment area of Swarna
River
60 km2
Gross annual energy 45,330 MWh
Losses 50MWh
Net saleable energy 45,280 MWh
The unit and station auxiliary supply will be obtained through the auxiliary transformer which can be fed
either from the generator or the 11 kV system. The backup power supply in the event of station shut
down will be grid supply. The in-feed from the diesel set will be kept as a second backup to be used to
start up the generators in case of a station shut down coupled with the failure of the grid supply. Therating of diesel generator set will be 125 kVA.
The technology employed is environmentally safe and tested. There is no transfer of technology to the
host country since the technology is available in, and supplied from, India.
A.4.3 Estimated amount of emission reductions over the chosen crediting period:
>>
A seven year renewable crediting period has been chosen.
Years Estimation of annual emission reductions in tonnes
of CO2e
Year 1 39,049
Year 2 39,049
Year 3 39,049
Year 4 39,049
Year 5 39,049
Year 6 39,049
Year 7 39,049
Total estimated reductions (tonnes of CO2e) 273,343
Total number of crediting years 7
Annual average of the estimated emission
reductions over the crediting period (tCO2e)
39,049
A.4.4. Public funding of the small-scale project activity:
>>
The project will not receive any public funding from parties included in Annex I of the UNFCCC.
A.4.5. Confirmation that the small-scale project activity is not a debundled component of a
large scale project activity:
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Appendix C, paragraph 2 of the Simplified Modalities and Procedures for Small-Scale CDM project
activities states:
“A proposed small-scale project activity shall be deemed to be a debundled component of a large project
activity if there is a registered small-scale CDM project activity or an application to register another
small-scale CDM project activity:
• With the same project participants;
• In the same project category and technology/measure; and
• Registered within the previous 2 years; and
• Whose project boundary is within 1 km of the project boundary of the proposed small-scale
activity at the closest point.”
As there is currently no registered CDM project or applied for registration at the site either large scale or
small scale, the project proponents undertake that the project activity is not a debundled component of alarge scale project.
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SECTION B. Application of a baseline and monitoring methodology
B.1. Title and reference of the approved baseline and monitoring methodology applied to thesmall-scale project activity:
>>
AMS I D – Grid connected renewable electricity generation
Version 13
B.2 Justification of the choice of the project category:
>>
Project type: Type I
Category: D
Paragraph 1 of the methodology states – “This category comprises renewable energy generation units,
such as photovoltaics, hydro, tidal/wave, wind, geothermal and renewable biomass, that supplyelectricity to and/or displace electricity from an electricity distribution system that is or would have been
supplied by at least one fossil fuel fired generating unit.”
The project activity is the generation of hydro power that will be fed into the southern grid of India. In
the absence of the project activity this power would have been produced by the current grid generation
mix which is predominantly fossil fuel based, thus the project activity meets the requirements of
paragraph 1.
Paragraph 2 of the methodology states – “ If the unit added has both renewable and non-renewable
components (e.g. a wind/diesel unit), the eligibility limit of 15MW for a small-scale CDM project activity
applies only to the renewable component. If the unit added co-fires fossil fuel1, the capacity of the entire
unit shall not exceed the limit of 15MW.”
The project activity involves the installation of three turbines of 5000kW each running on renewable
resources, thus remaining within the 15MW limit required by the above paragraph.
Paragraph 3 of the methodology states – “Combined heat and power (co-generation) systems are not
eligible under this category.”
The project activity is not a cogeneration unit.
Paragraph 4 of the methodology states – “ In the case of project activities that involve the addition of
renewable energy generation units at an existing renewable power generation facility, the added
capacity of the units added by the project should be lower than 15 MW and should be physically distinct2
from the existing units.”
There was no power generation on site before the project activity hence this paragraph is not applicable.
Paragraph 5 of the methodology states – “Project activities that seek to retrofit or modify an existing
facility for renewable energy generation are included in this category. To qualify as a small-scale
project, the total output of the modified or retrofitted unit shall not exceed the limit of 15 MW.”
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There is no existing power generation on the site of the project activity thus negating the above
paragraph.
It is therefore concluded that the project activity qualifies as a Type I.D. project.
B.3. Description of the project boundary:
>>
As per paragraph 6 of the methodology “The project boundary encompasses the physical, geographical
site of the renewable generation source.”
The project boundary includes the equipments installed for the operation of a new hydro power plant –
the main elements of which are the turbine, generator and the transformer.
Electricity to Southern grid
In terms of gases, the project boundary is restricted to CO2. For the purpose of the project activity the
relevant grid is defined by the power generating units serving the same grid as the project activity. The
Indian power grid system is split into two regions by the Central Electricity Authority (CEA) – NEWNE
and southern. The regional grids facilitate the transfer of electricity between states, which is supplied by
state-owned and central sector power generating stations. The state of Karnataka falls within the
southern region, hence the southern grid is chosen for the analysis. The boundary for the calculation of
the grid emission coefficient for the project activity is thus the southern grid in India which falls in
spatial extent of the project boundary.
B.4. Description of baseline and its development:
>>
Two possible baseline scenarios for the project activity have been identified as:
CDM Boundary
Swarna River (Water
Source)
Power House (TG,
generators etc.)
Main Transformer
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1. The proposed project activity without CDM i.e. the construction of a new hydro electricity
generation plant with an installed capacity of 15MW connected to the regional grid, implemented
without CDM.
2. Continuation of the current situation i.e. electricity will continue to be generated by the existing
generation mix operating in the grid.
Alternative 1 – The investment analysis in Section B.5 shows that the proposed project faces an
investment barrier that would prevent its implementation without the CDM revenues. Hence this is not a
suitable baseline scenario.
Alternative 2 – This represents a plausible baseline scenario and it does not face any barriers.
From the above analysis and the demonstration of additionality, Alternative 2 i.e. the regional grid has
been taken as the baseline and baseline emissions have been calculated in accordance with paragraph 9 of
the methodology.
Paragraph 9 of the methodology states - “For all other systems, the baseline is the kWh produced by the
renewable generating unit multiplied by an emission coefficient (measured in kg CO2e/kWh) calculated
in a transparent and conservative manner as:
(a) A combined margin (CM), consisting of the combination of operating margin (OM) and build margin
(BM) according to the procedures prescribed in the ‘Tool to calculate the emission factor for an
electricity system’.
OR
(b) The weighted average emissions (in kg CO2e/kWh) of the current generation mix. The data of the year in which project generation occurs must be used .
Calculations must be based on data from an official source (where available) and made publicly
available.”
The emission coefficient for the southern grid has been provided by Central Electricity Authority (CEA)
following the approach in paragraph 9(a) as a combined margin consisting of combination of operating
margin and build margin2.
Paragraph 10 of the methodology states – “In the case of project activities that involve the addition of
renewable energy generation units at an existing renewable power generation facility, where the existing
and new units share the use of common and limited renewable resources (e.g. streamflow, reservoir
capacity, biomass residues), the potential for the project activity to reduce the amount of renewableresource available to, and thus electricity generation by, existing units must be considered in the
determination of baseline emissions, project emissions, and/or leakage, as relevant.”
2 See Annex 3.
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The project does not involve addition of renewable energy generation units at an existing renewable
power generation facility as there is currently no power generation on the site, thus negating baseline
scenario specified above.
Paragraph 11 of the methodology states – “For project activities that seek to retrofit or modify an
existing facility for renewable energy generation the baseline scenario is the following:”
The project does not seek to retrofit or modify an existing facility as there is currently no power
generation on the site, thus negating baseline scenario specified in paragraph 11 above.
B.5. Description of how the anthropogenic emissions of GHG by sources are reduced below
those that would have occurred in the absence of the registered small-scale CDM project activity:
In line with Attachment A to Appendix B of the Simplified Modalities and Procedures for Small-Scale
CDM Project Activities, demonstration of additionality focuses on the barriers facing the project. In
showing that the project is additional we demonstrate that it is not part of the baseline scenario, which in
the case of the project activity would be the continuation of the power generation in the regional grid.
In terms of the specific barriers facing the project activity these fall under the investment barrier as
outlined in Attachment A to Appendix B of the Simplified Modalities and Procedures for Small-Scale
CDM Project Activities.
To analyze the feasibility of the project, the project proponents have analyzed the project internal rate of
return (IRR) for the project. The project will be financed with a mix of debt and equity in 70:30 ratio.
Given the subjectivity of the return on equity and the variation across companies, we have provided the
estimates of the cost of financing as a benchmark. To obtain this the commercial lending rates have to be
adjusted by guarantees required for India in line with the paragraph 6(b) of the additionality tool. The
cost of commercial lending is reported on the website of Reserve Bank of India (RBI) through the prime
lending rate (PLR) and which is quoted at 12.25 to 12.75%3
relating to the time of investment decision.The risk premium for India was calculated as 3.75%
4 by Dr. Aswath Damodaran in his published report –
“Country Default Spreads and Risk Premiums” which results in a benchmark of 16% for the project
activity5.
The most suitable indicator for comparison with the chosen benchmark is the project internal rate of
return (IRR). The only source of revenue for the project activity is from the sale of electricity using a
tariff of Rs 2.80/kWh, fixed for the first 10 years of operation as per the tariff order of Karnataka
Electricity Regulatory Commission (KERC). The total expenses include the costs to be incurred on
operation and maintenance and the interest paid on the working capital. The depreciation on various
components of the project has been worked out considering the life and also the lease period.
The project IRR has been calculated for the lifetime of the project activity i.e. 20years and includes all
the relevant revenues and costs associated with the project. The IRR of the project activity without
3 http://www.rbi.org.in/scripts/WSSView.aspx?Id=12213
4 2007
5 It should be recognized that as a project is funded by a mix of debt and equity, an unadjusted commercial lending
rate would not be suitable as this only represents the return on debt.
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taking into account the CER revenue is 10.25% which goes up to 14.29% with the inclusion of CDM
revenues. The input parameters of the investment analysis have been highlighted in the table below:
S. No. Parameter Unit Value1 Installed capacity MW 15
2 Plant Load Factor (PLF) % 35
3 Annual Gross generation MWh 45,990
4 Annual Auxiliary consumption & Losses MWh 50
5 Net exportable units (annual) MWh 45,940
6 Debt component % 70
7 Equity component % 30
8 Rate of interest for term loan % 13
9 Moratorium period Year 3
10 Repayment period Year 9
11 Operation & Maintenance cost % of project cost 1.5
11a Escalation on Operation & Maintenance cost % 4%12 Electricity tariff Rs/kWh 2.80
13 Interest on working capital % 12.25
14 Working capital components
14a O&M expenses Month 1
14b Receivables Months 2
14c Maintenance spares % of project cost 1
15 Book depreciation % 4.50
16 IT depreciation % 3.40
17 MAT rate % 11.33
18 Company tax rate % 33.99
19 Investment cost INR 1000 802,851
20 Operational lifetime Years 20
Sensitivity Analysis
The sensitivity analysis has been carried out in accordance with the – Guidance on the assessment of
investment analysis, version 02. The following parameters are expected to have a major impact on the
financial returns of the project activity and as per the guidance have been varied by ±10%:
1. Electricity tariff
2. Plant Load Factor (PLF)
3. Investment cost
4. Operation & Maintenance cost
The only revenue of the project activity comes from the export of power to the grid. Power will beexported to southern grid through a power purchase agreement with KPTCL. The results of the variation
are shown below:
Electricity Tariff
-10% -5% Base Case 5% 10%
IRR without 8.63% 9.45% 10.25% 11.01% 11.76%
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CDM
IRR with CDM 13.03% 13.66% 14.29% 14.89% 15.48%
An increase or decrease in Plant Load Factor (PLF) of the project activity will have an impact on thepower available for export to the grid thereby affecting the revenues of the project. The PLF has been
given a variation of ±10% to determine its effect on the financial situation of the proposed project.
PLF
-10% -5% Base Case 5% 10%IRR withoutCDM 8.63% 9.45% 10.25% 11.01% 11.76%
IRR with CDM 12.51% 13.41% 14.29% 15.13% 15.95%
The investment cost is unlikely to decrease due to time over runs related to small hydroelectric projects.
However the parameter has been given a variation of ±10% as per the investment guidance and the
results highlight the importance of CDM revenues for the setting up of the project activity.
Investment Cost
-10% -5% Base Case 5% 10%IRR withoutCDM 12.07% 11.12% 10.25% 9.43% 8.66%
IRR with CDM 16.41% 15.30% 14.29% 13.34% 12.46%
The operation and maintenance cost associated with the project have been varied and the results are
tabulated below:
O&M cost
-10% -5% Base Case 5% 10%IRR withoutCDM 10.44% 10.34% 10.25% 10.15% 10.05%
IRR with CDM 14.43% 14.36% 14.29% 14.21% 14.14%
The project IRR reaches the benchmark when either of the condition is met:
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1. The project just crosses the benchmark and achieves an IRR of 16.11% when the electricity tariff
is increased by 6.5% annually for the lifetime of 20 years. However such a situation is not
possible to occur since the tariff has been fixed by the Karnataka Electricity Regulatory
Commission (KERC).2. Even when the operation and maintenance cost is reduced to zero the IRR is 12.10% i.e. below
the benchmark. This condition is also not possible to achieve as there ought to be expenditure on
running the power plant during the technical lifetime of 20years.
3. The project attains an IRR of 16.00% and reaches the benchmark if there is a reduction of 27%
in the investment cost. This is a highly unrealistic condition since due to time over run in small
hydro power projects; the investment cost is always expected to increase.
4. The project achieves an IRR of 16.05% when the PLF increases by 40% i.e. PLF of 49%.
However such a situation is not possible as the PLF has been calculated in the DPR based on the
historical discharge data for the river and hence the PLF fluctuation to such a great extent is not
expected.
CDM Consideration
In line with Annex 46, EB41 since the start date of the project activity is after 2nd
August 2008, the
project proponents have notified the Designated National Authority (DNA) of India and the UNFCCC
about their intention to seek CDM status. The email and letters have been provided to the validator
during the site visit.
B.6. Emission reductions:
B.6.1. Explanation of methodological choices:
>>
Baseline Emissions
In line with paragraph 9 of the methodology the baseline emissions have been calculated by the followingformula:
yCM grid y y EF EG BE ,,∗= Equation 1
Where:
BEy Baseline emissions in year y, tCO2e
EGy Net electricity exported by the project activity to the grid in year y, MWh
EFgrid,CM,y Combined margin CO2 emission factor for grid connected power generation in year y
, tCO2 /MWh
Since the combined margin CO2 emission factor determined in section B4 has been fixed ex-ante, this
equation may be simplified to the following:
85.0∗= y y EG BE Equation 2
Project emissions
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The project activity will not give rise to project emissions, as no fossil fuel will be combusted in the
project activity. Project emissions are therefore zero.
Leakage
Paragraph 12 of the methodology states – “ If the energy generating equipment is transferred from
another activity or if the existing equipment is transferred to another activity, leakage is to be
considered.”
No equipment transfer takes place thus no leakage is envisaged for the project activity.
Emission Reductions
y y y y LPE BE ER −−=
Equation 3
Where:ERy Emissions reductions generated in year y, tCO2e
BEy Baseline Emissions in year y, tCO2e
PEy Project emissions in year y, tCO2e
Ly Leakage emissions in year y, tCO2e
Since project emission and leakage values are zero the above equation reduces to:
y y BE ER =
Equation 4
Substituting the value of BEy from equation 2 emission reductions value becomes:
85.0∗= y y EG ER Equation 5
B.6.2. Data and parameters that are available at validation:
Data /
Parameter:
EFgrid,CM,y
Data unit: tCO2 /MWh
Description: Combined margin CO2 emission factor for grid connected power generation in year y
Source of data
used:
Central Electricity Authority - CO2 baseline database, version 04
http://cea.nic.in/planning/c%20and%20e/Government%20of%20India%20website.ht
m
Value applied: 0.85
Justification of
the choice of
data or
description of
measurement
methods and
procedures
The emission factor value has been provided by the Central Electricity Authority
(CEA), a government body for the southern grid in India.
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actually applied
:
Any comment: This parameter has been fixed ex-ante.
Data /
Parameter:
EFgrid,BM,y
Data unit: tCO2 /MWh
Description: Build margin CO2 emission factor for grid connected power generation in year y
Source of data
used:
Central Electricity Authority - CO2 baseline database, version 04
http://cea.nic.in/planning/c%20and%20e/Government%20of%20India%20website.ht
m
Value applied: 0.71
Justification of
the choice of
data ordescription of
measurement
methods and
procedures
actually applied
:
The build margin emission factor value has been provided by the Central Electricity
Authority (CEA), a government body for the southern grid in India.
Any comment: This parameter has been fixed ex-ante.
Data /
Parameter:
EFgrid,OM,y
Data unit: tCO2 /MWh
Description: Operating margin CO2 emission factor for grid connected power generation in year y
Source of data
used:
Central Electricity Authority - CO2 baseline database, version 04
http://cea.nic.in/planning/c%20and%20e/Government%20of%20India%20website.ht
m
Value applied: 0.99
Justification of
the choice of
data or
description of
measurement
methods and
procedures
actually applied:
The operating margin emission factor value has been provided by the Central
Electricity Authority (CEA), a government body for the southern grid in India.
Any comment: This parameter has been fixed ex-ante.
B.6.3 Ex-ante calculation of emission reductions:
>>
The emission reductions are calculated from equation 5 in Section B.6.1.
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85.0∗= y y EG ER
The project activity is expected to generate gross 45,990MWh of electricity annually and the saleable
energy is 45,940MWh after deduction of auxiliaries and losses amounting to 50MWh. The annual
emission reductions from the project activity are therefore estimated at 39,049 tCO2 from the above
equation.
2049,39 tCO ER y =
B.6.4 Summary of the ex-ante estimation of emission reductions:
>>
Year Estimation of
project activity
emission reductions
(tCO2 e)
Estimation of
baseline emissions
(tCO2 e)
Estimation of
leakage (tCO2
e) Estimation of
emission reductions
(tCO2 e)
Year 1 0 39,049 0 39,049
Year 2 0 39,049 0 39,049
Year 3 0 39,049 0 39,049
Year 4 0 39,049 0 39,049
Year 5 0 39,049 0 39,049
Year 6 0 39,049 0 39,049
Year 7 0 39,049 0 39,049
Total
(tonnes of
CO2 e)
0 273,343 0 273,343
B.7 Application of a monitoring methodology and description of the monitoring plan:
B.7.1 Data and parameters monitored:
Data / Parameter: EGgross
Data unit: MWh
Description: Gross electricity generated by the project activity in year y
Source of data to be
used:
Plant records
Value of data 45,990
Description of
measurement methods
and procedures to be
A logbook will be maintained on site to record hourly readings from the energy
meter. The readings will be taken by the shift supervisor. This hourly data
will be signed off at the end of every shift by the engineer in charge of the shift
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applied: and again at the end of each day by the power plant manager.
QA/QC procedures to
be applied:
The generation energy meter will be calibrated at least once in three years6 by
an accredited independent third party. The accuracy level for active energy
measurement shall be as defined in the power purchase agreement.Any comment: All data will be kept for a minimum of 2 years following issuance of certified
emission reductions or the end of the crediting period, whichever is later.
Data / Parameter: EGaux
Data unit: MWh
Description: Auxiliary consumption by the project activity in year y
Source of data to be
used:
Plant records
Value of data 50
Description of
measurement methods
and procedures to beapplied:
A logbook will be maintained on site to record hourly readings from the energy
meter. The readings will be taken by the shift supervisor. This hourly data
will be signed off at the end of every shift by the engineer in charge of the shiftand again at the end of each day by the power plant manager.
QA/QC procedures to
be applied:
The auxiliary meter will be calibrated at least once in three years by an
independent accredited third party. The accuracy level for active energy
measurement shall be as defined in the power purchase agreement.
Any comment: All data will be kept for a minimum of 2 years following issuance of certified
emission reductions or the end of the crediting period, whichever is later.
Data / Parameter: EGy
Data unit: MWh
Description: Net electricity exported by the project activity to the grid in year y
Source of data to be
used:
Plant records
Value of data 45,940
Description of
measurement methods
and procedures to be
applied:
Joint meter readings will be taken at the interconnection point monthly by
representatives from the project activity and KPTCL. The accuracy level for
active energy measurement shall be as defined in the power purchase
agreement.
QA/QC procedures to
be applied:
The energy meter is a two way tri vector meter and will be calibrated as per the
power purchase agreement or at least once in three years by an independent
accredited third party. Invoices from KPTCL may be used as cross check for
net electricity used to calculate emission reductions.
Any comment: All data will be kept for a minimum of 2 years following issuance of certified
emission reductions or the end of the crediting period, whichever is later.
B.7.2 Description of the monitoring plan:>>
Monitoring shall consist of metering the gross generation, auxiliary consumption of electricity in the
project activity and the net electricity delivered to the grid at the interconnection point. The emission
6 As per paragraph 12(c), Annex 20, EB41, Indicative Simplified Baseline And Monitoring Methodologies For
Selected Small Scale CDM Project Activity Categories
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reductions will be calculated on the net electricity received by the grid. The power plant manager will
act as the overall authority for the monitoring of the project activity.
Internal AuditsAn internal audit will be carried out every year to ensure that the monitoring parameters are being
monitored in accordance with Section B.7.1. The audit reports will be provided to the DOE undertaking
periodic verification.
Monitoring procedures
There will be three 8 hour shifts and the readings from energy meters will be taken on a hourly basis by
the operators and recorded in logbooks. This hourly data will be signed off at the end of every shift by
the engineer in charge of the shift and again at the end of each day by the power plant manager. The
power plant manager will analyze the data every month and report to the head office. The joint meter
reading will be taken monthly at the interconnection point in the presence of representatives of KPTCL
and the project owner.
Period of archiving
The monthly data will be archived electronically at the end of the month and invoices of electricity
export and import will be maintained on site.
Training requirements
The suppliers of the equipments will train the staff in- charge during erection, to operate and maintain the
equipments efficiently. Apart from this, the equipment supplier will provide complete manuals and
documentation providing details for the maintenance schedule and the required activities associated with
it. After commissioning of the power plant, periodic training of employees would ensure that there are
no discrepancies in transferring of data from logbooks to soft copy.
Calibration of equipments
The monitoring meters will be calibrated according to national standards as defined in Section B.7.1.The calibration certificates will be made available at the time of verification.
QA/ QC of monitored data
The monitored data will be reported through GVP Infra Projects Pvt. Ltd. to Agrinergy Pte Ltd on a
monthly basis for the calculation and estimation of emission reductions. This data will be checked
against initial estimates and a summary report will be provided quarterly by Agrinergy. If the project is
not performing as expected or if there are any negative impacts on the volume of emission reductions
obtained, on the basis of the monthly data being monitored, a report will be sent to GVP Infra Projects
Pvt. Ltd. outlining where the project is deviating in its generation of emission reductions and the
immediate measures which need to be undertaken to maintain the expected generation of emission
reductions from the operation of this project. Should there be significant changes to the set-up or
operation of the plant, these will be notified to Agrinergy and amendments to the PDD will be requested
through a DOE.
B.8 Date of completion of the application of the baseline and monitoring methodology and the
name of the responsible person(s)/entity(ies)
>>
06/02/2009
Bhawna Singh
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Agrinergy Consultancy Pvt Ltd
bhawna.singh@agrinergy.com
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SECTION C. Duration of the project activity / crediting period
C.1 Duration of the project activity:
C.1.1. Starting date of the project activity: >>
08/07/2009 – Letter of Intent to TG manufacturer
C.1.2. Expected operational lifetime of the project activity:
>>
20y-00m
C.2 Choice of the crediting period and related information:
The project activity has opted for a 7 year renewable crediting period.
C.2.1. Renewable crediting period C.2.1.1. Starting date of the first crediting period:
>>
01/07/2010 or date of registration (whichever is later)
C.2.1.2. Length of the first crediting period:
>>
7y-00m
C.2.2. Fixed crediting period:
C.2.2.1. Starting date:
>>
Not Applicable
C.2.2.2. Length:
>>
Not Applicable
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SECTION D. Environmental impacts
>>
D.1. If required by the host Party, documentation on the analysis of the environmental impacts
of the project activity:
>>
Existing Indian environmental legislation does not require an Environment Impact Assessment (EIA)7 to
be carried out for the project activity.
The project activity is a run-of-river project. As there is no storage structure, therefore, no submergence
is involved. The effects of project construction on flora and fauna aspects are negligible. There is no
displacement of any local inhabitants and therefore no rehabilitation measures are required. In terms of
air and water pollution the only anticipated pollution during construction phase of the project will be the
dust levels. Measures such as spraying water to combat dust and SPM levels will be followed during
construction to mitigate this.
The project thus does not endanger the species of flora and fauna in the area. The components of the
project are proposed on barren land and no forest cover is affected. The construction of project facilities
also does not involve any felling of any tree. The danger of erosion is minimal. The flows available in
the stream are proposed to be utilized without creating any additional storage. There will be no
disturbance to the existing eco-system.
D.2. If environmental impacts are considered significant by the project participants or the host
Party, please provide conclusions and all references to support documentation of an environmental
impact assessment undertaken in accordance with the procedures as required by the host Party:
>>
No environmental impacts were considered significant.
7 http://www.nlsenlaw.org/environmental-management/eia-public-hearing/law-policy/s-o-1533-e-14-09-2006-environmental-
impact-assessement-notification-2006-english/
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SECTION E. Stakeholders’ comments
>>
E.1. Brief description how comments by local stakeholders have been invited and compiled: >>
Comments from the local stakeholders regarding the project activity have been sought through publishing
a notification of the project activity in English and local language in the following newspapers:
1. The Times of India, Mangalore dated 17/02/2009
2. Vijaya Karnataka dated 17/02/2009
The notices provided information on the project activity and informed the local people of the company’s
intention to seek CDM status.
In addition to this the project is required to obtain mandatory approvals from other institutions. The
other stakeholders consulted are:
Stakeholder Name Function
Karnataka Renewable Energy
Development Limited (KREDL)
Policy implementation body in respect of renewable energy
projects in Karnataka. KREDL reviews the project
documentation and accords clearance for utilizing renewable
energy sources in the state
Karnataka Power Transmission
Corporation Limited (KPTCL)
The state owned electricity utility company that manages the
electricity transmission in Karnataka state. Any electricity
generation project proposed in Karnataka shall approach
KPTCL for power evacuation arrangements.
Karnataka State Pollution Control
Board (KSPCB)
A statutory local body that oversees the pollution control
aspects in the state. Any project activity shall obtain consent to
establish from the KSPCB before implementation.
Karnataka Irrigation Department Is part of Government of Karnataka and overseas utilization of
water in the state of Karnataka.
Local Village Panchayat Elected statutory body of the local populace will issue NOC for
implementing any project in the jurisdiction of the panchayat.
This body represents the local population.
Karnataka State Fisheries Department Accords clearance for the utilization of downstream flow of
water and disposal of silt.
Karnataka Urban Water Supply &
Drainage Board
The body grants permission for the construction of projects to
draw water.
Department of Energy, Government
of Karnataka
Accords permission to implement power projects in the state of
Karnataka.
Karnataka State Boilers Department Provides approval for any power project activity implemented inthe state.
E.2. Summary of the comments received:
>>
No comments have been received.
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E.3. Report on how due account was taken of any comments received:
>>
Since no comments were received no action has been taken.
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Annex 1
CONTACT INFORMATION ON PARTICIPANTS IN THE PROJECT ACTIVITY
Organization: GVP Infra Projects Pvt. Ltd.
Street/P.O.Box: No.476, Tala Cauvery Layout, Amrutha Halli
Building: Byatarayanapura, New Bangalore Intl. Airport Road
City: Bangalore
State/Region: Karnataka
Postfix/ZIP: 560092
Country: India
Telephone: +91-80-41479522
FAX:
E-Mail:
URL:
Represented by:Title: Executive Director
Salutation: Mr.
Last Name: Rao
Middle Name: Padma
First Name: N
Department:
Mobile:
Direct FAX:
Direct tel: +91-80-41479522
Personal E-Mail: npr_jbel@sify.com
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Organization: Agrinergy Pte Ltd
Street/P.O.Box: 10 Hoe Chiang Road,
Building: #08-04 Keppel TowersCity: Singapore
State/Region:
Postfix/ZIP: 089315
Country: Singapore
Telephone:
FAX:
E-Mail:
URL: www.agrinergy.com
Represented by:
Title: Managing Director
Salutation: Mr
Last Name: AtkinsonMiddle Name:
First Name: Ben
Department:
Mobile:
Direct FAX: +65-63476181
Direct tel: +65-65920400
Personal E-Mail: ben.atkinson@agrinergy.com
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Annex 2
INFORMATION REGARDING PUBLIC FUNDING
The project has not received any public funding.
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Annex 3
BASELINE INFORMATION
The emission coefficient has been provided by Central Electricity Authority (CEA), a government body,
following the approach in paragraph 9(a) as a combined margin consisting of combination of operating
margin and build margin. The CEA has issued the CO2 baseline database, version 04 wherein the
emission factor for NEWNE and southern grid has been calculated as per the “Tool to calculate the
emission factor of the electricity system, version 01.1”. As the project activity lies in the southern part of
India, the southern grid has been taken as the relevant grid and the grid emission factor from CEA
database fixed ex-ante at 0.85tCO2 /MWh as shown in the below table:
Parameter tCO2 /MWh
Operating Margin 0.99
Build Margin 0.71
Combined Margin 0.85
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Annex 4
MONITORING INFORMATION
To implement the monitoring procedures described in Section B.7, the following organization structure
will be followed by the project owners:
The uncertainty in data is low as the meters will be regularly calibrated according to national standardsand also the data will be regularly monitored by Agrinergy Pte Ltd.
At the end of each year of operation Agrinergy will prepare a monitoring report that will be submitted to
a DOE for verification, however visits to the site may be undertaken by Agrinergy during the first year to
check that the procedures and monitoring plan are being followed. All data will be kept for a minimum
of 2 years following issuance of certified emission reductions or the end of the crediting period,
whichever is later.
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