under review - adani power
TRANSCRIPT
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 1
CLEAN DEVELOPMENT MECHANISM PROJECT DESIGN DOCUMENT FORM (CDM-PDD)
Version 03 - in effect as of: 28 July 2006
CONTENTS A. General description of 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 project activity Annex 2: Information regarding public funding Annex 3: Baseline information
Annex 4: Monitoring plan
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 2 SECTION A. General description of project activity A.1 Title of the project activity: Energy efficient power generation in Tirora, India
Version 05, October 22, 2009
A.2. Description of the project activity:
Adani Group, a diversified conglomerate has interests in various activities including interests in
commodity trading, edible oil refining and infrastructure projects and services. Adani Enterprises Ltd
(AEL), the flagship company of the group, is an international trading house dealing in nearly 70
commodities in more than 60 countries around the world. Adani Power Maharashtra Limited (APML)
is a subsidiary company of Adani Power Limited. The power division of AEL is a well known name in
power trading in India.
APML will implement the high efficiency power generation project using coal-fired super-critical
technology at Tirora, District Gondia - Maharashtra which would result in reduced consumption of
fossil fuel and associated greenhouse gas (GHG) emissions for thermal power generation.
Purpose of the project activity
Super-critical coal fired power generation plant is being proposed as project activity which will have
an installed capacity of 1320 MW (2 x 660 MW). The efficiency of the super-critical coal fired power
plant is around 41.75%1 which is quite higher than the sub-critical coal fired power plants that are
presently operating in India having average efficiency ~31.80%2 (also refer Table A1 in Annex 3). A
subcritical power plant of 500 x2 MW capacity and constructed in recent years would have a higher
efficiency of about 35.1% (corresponding to a station heat rate of 2450 kCal/kWh)3. The electricity
generated will be exported to the local/regional/national grid. The project activity will be implemented
at Tirora, the installed capacity will be 1320 MW (2 x 660 MW).
Many regions of the world are experiencing fast growing electricity demand. Thermal power plants
are a major source of carbon dioxide, which is one of the GHGs listed under the Kyoto Protocol. Coal
1 Calculated from Station Heat Rate of 2060 kCal/kWh for the proposed project activity 2 Sources: http://www.cea.nic.in/god/opm/Thermal_Performance_Review/0607/SECTION-13.pdf http://www.cea.nic.in/god/opm/Thermal_Performance_Review/0708/highlights.pdf 3 http://www.cercind.gov.in/03022007/Pet_106-2006%20RihandSTPS-II.pdf
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 3 is an abundant fuel resource in many of the world’s developing regions and forecasts show that it is
likely to remain a dominant fuel for electricity generation in many countries for years to come.
Capital scarcity and competition which are maintaining downward pressure on prices of new power
plants. It is against this backdrop that power plant suppliers have invested heavily in generation
technologies that produce power more efficiently. Enhanced plant efficiency reduces emissions of CO2
and all other pollutants by using less fuel per unit of electricity generated. Improvement in efficiency
can be achieved by using supercritical steam conditions. One percent increase in efficiency reduces by
two percent, specific emissions such as CO2, NOx, SOx and particulates4.
The steam generation in the project activity will be occurring at super-critical conditions (at boiler
outlet, steam temperature of 5710C and pressure of 25.40 MPa (g)) and this steam is further utilised in
power generation through condensing type steam turbine. The super-critical cycle has a higher
efficiency of steam generation as compared to that of conventional sub-critical technology. Higher
steam generation efficiency and hence higher overall cycle efficiency will lead to lower specific coal
(i.e. fossil fuel) consumption.
Salient features of the proposed project activity
Installed capacity of the proposed project activity will be 1320MW (2 x 660 MW units).
The boiler which is being used for generating steam (hereafter referred to as ‘main steam’) at super-
critical conditions of 25.40 MPa (g) pressure and 5710C temperature is a once-through coal fired type
boiler. The reheat steam5 will be at a temperature of 5690C and pressure of 4.52 MPa. At super-
critical condition, the fluid conditions eliminate the requirement of re-circulating boiler. Keeping the
steam parameters at super-critical conditions will increase the efficiency of overall power generation
cycle of the super-critical power plant over that of a sub-critical power plant. In India, the generation
efficiency of a typical sub-critical power plant is around 31.80% (also refer to Table A1 of Annex-3)
whereas the super-critical technology offers generation efficiency of around 41.75%. Now, higher
overall generation efficiency of the plant would lead in lower fossil fuel consumption and which in turn
to less GHG emissions.
4 http://power4georgians.com/supercritical.aspx 5 The Steam after passing through the HP turbine is reheated in the reheater before passing through the IP/LP turbine. This is referred to as the reheat steam. Refer to Figure 2 (part marked 3).
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 4 Thus the implementation of the proposed project activity will reduce fossil fuel combustion for the
generation of same amount of electricity and thus will lead to lessening of global warming.
Project’s contribution to sustainable development
The proposed project’s contribution to the sustainable development of India is elaborated under the
following four pillars of sustainable development:
Social sustainability
Due to its location, the project activity will contribute towards poverty alleviation by generating both
direct and indirect employment for the local community. During the construction activity of the
project, local people will be employed. Due to better technology usage, the project activity would help
adding to the knowledge and skill base of the power plant operators. It will also contribute to
improvement of the power deficit situation, which will improve quality of life and facilitate accelerated
implementation of rural electrification initiatives in India.
Environmental sustainability
The higher efficiency of power generation would reduce fossil fuel consumption. Less coal
consumption will improve the local environmental condition by reducing emissions of carbon dioxide
and other air pollutants like SPM, SO2 etc.
Economic sustainability
The project activity will contribute towards sustainable development of the region, not only through
reduced emissions contributions, but also through various initiatives to be undertaken by the project
Sustainable Development
Social Well Being
Environmental Well Being
Economic Well Being
Technological Well Being
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 5 proponent. These include the local employment during project implementation and operational phases
and extending the medical care facility to the employees. It will also lead to the local employment for
the resources with low and medium skilled services often required in the project activity. The proposed
project activity will lead to huge investment being made in the State of Maharashtra. The proposed
project activity will reduce the supply deficit of electricity in India and contribute to the infrastructural
and economic growth of India. The technical consultants, equipment suppliers all would be benefited
economically because of the proposed project activity.
Technological sustainability
The technology employed being the first-of-its-kind in the thermal power generation sector of
Maharashtra and the project activity will initiate capacity building, development of new skills and the
knowledge base which could be used as a reference for the next coming entrants. The usage and
development of such technologies in developing countries like India will help in greater extent in
fulfilling its energy generation need in a very environment friendly way.
A.3. Project participants: Name of Party involved Private and/or public entity
(ies) project participants Kindly indicate if the Party involved wishes to be considered as project participant (Yes/ No)
Government of India (Host Country)
Adani Power Maharashtra Ltd – Private Entity
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.:
Maharashtra
A.4.1.3. City/Town/Community etc:
Tirora, Gondia District
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 6 A.4.1.4. Detail of physical location, including information allowing the unique identification of this project activity (maximum one page):
The site is located about 2.5 km east of Tirora town in Gondia District, Maharashtra. The site is about
122 km from Nagpur airport, and 45 km from Gondia railway station. The latitude and longitude of
plant site are 21O 24’ 42.9” North and 79O 58’ 14.9” East respectively. The site is encompassed by
villages Chikhali, Churdi, Bhiwapur, Tamsar and Mendipur Bhandara Road – Gondia Section of
South Eastern Railway is passing within 500 m of the site. The state highway connecting Khairanji
and Bhandara Road grazes past the plant site and connects Tirora Town.
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 7 A.4.2. Category (ies) of project activity:
The project activity is a large scale potential CDM project, which fits into the Category 1: Energy
industries (renewable / non renewable sources) as per ‘List of Sectoral Scopes’6.
A.4.3. Technology to be employed by the project activity:
"Supercritical" is a thermodynamic expression describing the state of a substance where there is no
clear distinction between the liquid and the gaseous phase (i.e. they are a homogenous fluid). Water
reaches this state at a pressure above 22.1 MPa. The molecular structure of water as function of
Pressure and Temperature is shown in figure 1 below:
Figure 1: Molecular structure of water as a function of Pressure and Temperature
Thermodynamic Cycle:
The thermodynamic cycle for 660 MW unit will consider super-critical steam parameters. The unit
comprises the boiler, the steam turbine generator, the condenser, the condensate extraction and boiler
feed systems along with all other necessary equipment for single/double reheat-regenerative cycle. The
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 8 steam parameters at the outlet of the boiler have been considered to be 259.01 kg/cm2 (a), 571°C with
steaming capacity of about 2111 TPH. Corresponding steam parameters at the turbine inlet would be
246.77 kg/cm2 (a) at 566°C and reheated steam parameters would be about 46.091 kg/cm2 (a) and
569°C. The HP/IP cylinders may be single/double casing design as per manufacturers’ standard. The
exhaust from HP-IP turbine will further expand in the double flow LP Turbines.
The exhaust steam from the LP turbine will be cooled in the main steam condenser by circulation of
required quantity of cooling water and its vacuum will be maintained by two of the four 50% capacity
vacuum pumps maintaining a backpressure of 76 mm Hg (abs). The condenser would be twin flow,
double pass, horizontal, shell and tube type, cooled by circulation of cooling water (inlet water
temperature 33°C max) in a re-circulating cooling water circuit using wet cooling tower.
The regenerative feed heating system will consist of three/four stages of low pressure heaters, one
gland steam condenser, one separate condenser, one separate drain cooler, one spray-cum-tray type
deaerator, two parallel chains of three high pressure heaters having 50% capacity. The condensate
drawn from condenser hot well by 3 x 50% capacity steam turbine driven condensate extraction
pumps will be pumped to the de aerator through condensate polishing unit, gland steam condenser,
drain cooler and the LP heaters. The feed water would be drawn by the boiler feed pumps and pumped
to the respective boilers to the three higher pressure heaters. Three nos. boiler feed pumps [two nos.
turbine driven of 50% capacity each and one no. motor driven of 30% capacity] have been envisaged
for each unit.
Steam Generator Set:
The steam generator for super-critical unit consists of a number of parallel circuits connected by inlet
and outlet headers. Pressurized water enters the circuit at one end and leaves as super critical steam at
other end. Thus boiler is of “Once-through type”. Once-through boilers may be designed in both two-
pass & tower type design. Since flow is once-through furnace wall tube temperature tends to increase
at low load. The volume of the evaporator system is much smaller compared to a natural circulation
boiler. Due to smaller inventory of stored water & steam, theoretical rate of response is much faster
than drum unit. Furnace has low thermal inertia resulting in a shorter start up time, faster rate of load
change & shorter time of forced cooling operation during emergency shut down. Due to elevated
6 Reference: http://cdm.unfccc.int/DOE/scopes.html
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 9 pressure and temperature, cycle efficiency improves which results in reduction of fuel consumption per
unit electricity generated which in terms reduces CO2, NOx & SOx emissions. To limit the dust load
at the inlet to the chimney to a value of 75 mg/Nm3, adequately sized electrostatic precipitators would
be provided.
Turbine Generator Set:
The steam turbines would be standard multi-stage, 3000 rpm, tandem compound, single/double reheat,
regenerative, condensing, multi-cylinder unit with eight/nine uncontrolled extractions for regenerative
feed water heating. The proposed turbine will have one single flow HP cylinder, one double flow IP
turbine and two double flow LP casings. The LP turbine will exhaust against a condenser pressure of
76 mm Hg (abs) and maximum cooling water temperature of 33°C. The unit would have horizontally
split double flow LP cylinder with the LP turbine exhausting steam directly into spring mounted
surface type, two-pass condenser having divided water box. The turbo-generator sets would be
designed for a maximum throttle steam flow at turbine valve wide open (VWO) condition of 105% of
turbine MCR flow. The steam turbines will be directly coupled to the horizontally mounted, three
phase, two-pole, cylindrical rotor type electric generators and will have a nominal rating of 660 MW
at generator terminal after meeting power requirement for excitation system.
The mode of operation of the super-critical boiler differs from that of the sub-critical boiler. The
super-critical boiler is a once through type of boiler. In sub-critical boiler, water and steam remains in
saturated condition in the boiler drum and water is re-circulated for generation of steam which is not
the case in super-critical boiler. The once through boiler does not require any circulating pump or
drum except for boiler feed water (BFW) pump. Energy required for circulation is provided by the
feed pump.
Details of the Rankine cycle are being illustrated in Figure 2 given below. As shown in the Figure,
cycle starts with point 1 which indicates the super-critical steam conditions. After expansion through
the High Pressure (HP) Turbine, at point 2, steam enters the re-heater and then into the Low Pressure
(LP) Turbine. From points 4 to 5, the steam condenses to form saturated liquid. It is then mixed with
make up water, if required, and pumped to a deaerator. The Boiler Feed Pump pumps the water from
the deaerator to the boiler.
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 10
Figure 2: T-S diagram for super-critical Rankine Cycle
Figure 2: Super-critical Rankine Cycle
Two super-critical coal fired power generation units will be set up in proposed project activity, each of
which has 660 MW (Nominal) capacity, providing a total installed capacity of 1320 MW (Nominal).
The steam generator (SG) would be once through type of boiler and would be designed for firing on
100% domestic coal. The characteristics of the SG would be radiant, single reheat, balanced draft and
outdoor type. The parameters for the SG are as below.
Table 1: Parameters for Steam Generators
Parameter Value Super heater outlet pressure 25.40 MPa(g) at TMCR7 Super heater outlet temperature 571OC Super heater outlet flow 2111 ton/h Re-heater outlet pressure 4.52 MPa (g)
7 Turbine Maximum Continuous Rating
1-2 HP Expansion Turbine 2-3 Reheat 3-4 IP/LP Turbine Expansion 4-5 Condenser 5-6 Low pressure Feed Water Heating 6-7 Feed water Pumping 7-8 High pressure Feed Water Heating 8-1 Evaporator / Superheater
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 11
Re-heater outlet temperature 569 0C Re-heater outlet flow 1766.58 ton/h Feed water inlet temperature to economizer 277 0C
The water wall would be spiral wound plain tubes.
The steam parameters at the condensing steam turbine generator (STG) inlet will be as below.
Table 2: Parameters for Steam Turbo-Generator
Parameter Value Pressure 24.2 MPa (a) Main Steam temperature 566 0C Reheat Steam temperature 566 0C
A.4.4 Estimated amount of emission reductions over the chosen crediting period:
Operating Years CO2 Emission Reductions (tonnes of CO2)
Aug 2011-Jul 2012 964567 Aug 2012-Jul 2013 1218401 Aug 2013-Jul 2014 1218401 Aug 2014-Jul 2015 1218401 Aug 2015-Jul 2016 1218401 Aug 2016-Jul 2017 1218401 Aug 2017-Jul 2018 1218401 Aug 2018-Jul 2019 1218401 Aug 2019-Jul 2020 1218401 Aug 2020-Jul 2021 1218401
Total estimated reductions (tonnes of CO2 e) 11930172 Total number of crediting years 10 Annual average over the crediting period of estimated reductions (tonnes of CO2 e)
1193017
A.4.5. Public funding of the project activity: There is no availability of public funding for the proposed project activity.
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 12 SECTION B. Application of a baseline and monitoring methodology B.1. Title and reference of the approved baseline and monitoring methodology applied to the project activity:
Title: Consolidated baseline and monitoring methodology for new grid connected fossil fuel fired
power plants using a less GHG intensive technology
Reference: ACM0013, Version 02.1, www.unfccc.int
B.2 Justification of the choice of the methodology and why it is applicable to the project activity:
The methodology ACM0013, Version 02.1 is applicable to “new electricity generation plants” and
thus can be considered for the proposed project activity under consideration since the proposed project
activity of APML involves development of Greenfield coal based power generation capacity using
super-critical technology and supplying power to the Western Regional Grid of India.
Further, the project activity meets the applicability criteria of ACM0013, Version 02.1 as under.
“The project activity is the construction and operation of a new fossil fuel fired grid-connected
electricity generation plant that uses a more efficient power generation technology than what would
otherwise be used with the given fossil fuel”- The proposed project activity of APML involves
construction of the new super-critical coal fired power plant at Village Tirora, District Gondia. As
already depicted in section A.2., the project activity uses super-critical technology which is more
efficient than the conventional coal fired sub-critical power generation technology, an established and
conventional practice in the Indian scenario.
“The project activity is not a co-generation power plant”- The proposed project activity generates
only power and is not a cogeneration power plant. A fully condensing turbine will be used in the
proposed project activity. The turbine will operate at a pressure of about 24.2 MPa (a), main steam
temperature and reheat steam temperature both are of about 566 0C.
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 13 “Data on fuel consumption and electricity generation of recently constructed power plants is
available.”- The relevant data/ information on electricity generation and fuel consumption are
available with Central Electricity Authority (CEA), Govt. of India and the same have been used by
CEA for calculation of baseline emission factor which has been published by CEA8. The same factor
is used by the project proponent to arrive at the baseline emissions for the project activity9.
“The identified baseline fuel is used in more than 50% of total generation by utilities in the
geographical area, as defined later in the methodology, within a country or country10. To
demonstrate this applicability condition data for latest three year shall be used. Maximum value of
same fossil fuel generation estimated for three years should be greater than 50%”-The identified
baseline fuel is coal which is used in more than 50% of total generation by utilities within India which
is clearly shown in the below given data. Data for latest three years have been given below.
Table 3: All India Electricity Generation Data in GWh
Generation (GWh) Type of Generation 2007-081 2006-071 2005-062
Coal 476726.57 461339.98 435096.64 Gas + Diesel 72227.9 66207.38 62117.66 Total Thermal 558990.05 527547.36 497214.30 Hydro 123424.12 113358.77 101293.1 Nuclear 16776.91 18606.75 17238.89 Total 699191.08 662522.96 617510.44 % Coal in total Generation
68.18 69.63 70.45
% of gas + diesel in Total Generation
10.33 9.99 10.05
1http://www.cea.nic.in/god/opm/Monthly_Generation_Report/18col_A_08_03/FILE-04.pdf 2http://www.cea.nic.in/cea-archive/body/Reports/Monthly%20Generation%20Report/2006/18col_06_03.pdf
8 As per CEA website (http://www.cea.nic.in/planning/cdm.pdf), “The CO2 Baseline Emission factor for coal based power units as applicable to new coal fired power generating units with supercritical steam parameters has been worked out as 0.941 tCO2/MWh ( based on net generation ) for the year 2007-08. The calculations are based on CDM Executive Board approved methodology ACM0013 Ver 01 “ New Grid connected fossil fuel fired power plants using a less GHG intensive technology”. Since the calculation procedure for emission factor is the same for ACM0013 version 01 and ACM0013 version 02, hence the value of 0.941 tCO2/MWh has been used for the project activity as well. 9 http://www.cea.nic.in/ 10 For the purpose of demonstrating compliance with the applicability condition the geographical area has to be limited by the physical borders of the host country and cannot be extended to neighboring non-Annex I countries, even if such an extended geographical area is used for the calculation of a benchmark emission factor.
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 14
Table 4: All India Installed Generating Capacity in MW
All India Generating Installed Capacity (MW) Thermal Total Year Hydro
Coal Gas Diesel Total Nuclear R.E.S@
% Coal in total Generating Installed Capacity
As on 31-03-20061
32325.77 68518.88 12689.91 1201.75 82410.54 3360.00 6190.86 124287.17 55.13
As on 31-03-20072
34653.77 71121.38 13691.71 1201.75 86014.84 3900.00 7760.60 132329.21 53.75
As on 31-03-20083 35908.76 76048.88 14656.21 1201.75 91906.84 4120.00 11125.41 143061.01 53.16 1 Source : http://www.cea.nic.in/power_sec_reports/executive_summary/2006_03/6.pdf 2 Source : http://www.cea.nic.in/power_sec_reports/executive_summary/2007_03/6.pdf 3 Source : http://www.cea.nic.in/power_sec_reports/executive_summary/2008_03/8.pdf
Using tables 3 and 4, it can be concluded that the identified baseline fuel, coal is used as a fuel in more
than 50% of the generation utilities in India.
B.3. Description of the sources and gases included in the project boundary
The circumference of the project boundary includes the power plant at the project site and all power
plants considered for the calculation of the baseline CO2 emission factor (EFBL,CO2,y). In calculating the
project emissions and Baseline emissions, only CO2 emissions from fossil fuel combustion in power
plant(s) are taken.
Table 5: Overview on emissions sources included in or excluded from the project boundary
Source Gas Included? Justification / Explanation CO2 Yes Main emission source. CH4 No Excluded for simplification.
This is conservative.
Bas
elin
e
Power generation in baseline
N2O No Excluded for simplification. This is conservative.
CO2 Yes Main emission source. CH4 No Excluded for simplification.
Proj
ect
Act
ivity
On-site fuel combustion in the project plant N2O No Excluded for simplification.
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 15 The project boundary includes the top 15% coal fired power plants constructed in the last 5 years,
operating in India with a capacity of 500 MW at base load. Besides these power plants, the proposed
project activity at Tirora is also included in the project boundary.
B.4. Description of how the baseline scenario is identified and description of the identified baseline scenario:
Step 1: Identify plausible baseline scenarios
As postulated in the methodology, project activity should be seek out in various possible and credible
alternative baseline scenarios given that all outputs and services are in accordance with the proposed
CDM project activity (including the proposed project activity without CDM benefits), i.e., need to
seek out all type of power plants that could be constructed as alternative to the project activity within
the project boundary, as defined in the section “Project boundary” and in Step 2 of the section
“Baseline emissions” below. As mentioned earlier for discussion on baseline each of the 2x 660 MW
super-critical coal fired unit located in a single location have been considered as single power plant.
The following Alternatives have been identified and analyzed as below.
Alternative 1. The project activity not implemented as a CDM project
Implementation of the proposed project activity but not as a CDM project activity. This alternative is
in compliance with all local and national laws and regulations and hence is considered further for
arriving at the baseline scenario.
Alternative 2. Power generation using coal-fired sub-critical power generation technologies
Sub-critical coal-fired technologies can be carried out for the same output for the proposed project
activity using but this activity will lead to higher GHGs emissions. This alternative is in compliance
with all laws and regulations of the country and hence is considered further for arriving at the baseline
scenario.11
11 For supercritical power plant, unit sizes are available in 660 MW and 800 MW. The project activity uses the 660 MW configuration. For subcritical power plants, unit sizes are available in 250 MW and 500 MW (these two units “form the backbone of the Indian Power Sector” as per page 5 of the report made available by CEA, “REPORT OF THE COMMITTEE TO RECOMMEND NEXT HIGHER SIZE OF COAL FIRED THERMAL POWER STATIONS” at http://www.cea.nic.in/thermal/Special_reports/Report%20of%20the%20committee%20to%20recommend%20next%20hi
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 16
Alternative 3. Power generation using energy sources (natural gas) other than coal
Natural gas can be used for power generation and this alternative is in compliance with all laws and
regulations of the country. In this case, the power plants will emit GHGs associated with combustion
of natural gas. However, given the deficit situation of natural gas supply and the projection of long-
term natural gas price, it is unlikely that any new thermal power generation capacity of 1320 MW will
come with natural gas as fuel. Hence this alternative is not considered further for arriving at the
baseline scenario.
As per CEA data of 2006-07, in the Indian Grid, coal based generation capacity is about 69.63% of
the total generation capacity while gas and diesel together account for only 9.99%. Nuclear and
renewable energy sources contribute a small amount to the energy requirement of India. Considering
these facts, it can be concluded that electricity generation comparable to the proposed project activity
in India can only be achieved by coal fired generation technology.
Alternative 4: Power generation using energy sources (diesel/ fuel oil/naphtha) other than coal
Diesel/ fuel oil/naphtha based power generation as an alternative to the project activity can be taken by
the project proponent. This alternative would be in order with all applicable laws and regulations of
the country. However, in this alternative the project proponent would face high operational cost barrier
on account of spiraling diesel/ fuel oil/naphtha prices for consumers. Under merit order purchasing or
compared to low cost of generation through other fuel alternatives, selling of power would be
extremely difficult from such power stations. In fact, the highest capacity power plant running on
diesel in India is of 128 MW (Kozhikode DG)12 only. Hence this alternative is not considered further
gher%20size%20of%20coal%20fired%20thermal%20power%20stations.pdf . To implement an installed capacity to the tune of 1320 MW, it is more reasonable that the project proponent would have gone ahead with the implementation of 2-3 units of 500 MW (at a single location or at different locations). 500 MW units would ensure economies of scale and it would be more practical for the project proponent to install two 500 MW units rather than four 250 MW units. Moreover the 500 MW units is more efficient and have better performance than the smaller size units (Page 2-3 of http://cea.nic.in/thermal/Special_reports/Report%20of%20the%20committee%20to%20recommend% 20next%20higher%20size%20of%20coal%20fired%20thermal%20power%20stations.pdf). More number of units at different locations would also mean more difficulty in land acquisition for the project and operational/ monitoring issues. 12 According to the report of Working Group on Petroleum and Natural Gas for XIth Plan (2007-12), [Ref: Planning Commission, Govt. of India] there is a natural gas demand–supply gap (shortfall in supply) to the extent of 67.98 MMSCMD in 2007-08 which may fall to 42.81 MMSCMD in 2008 – 09. According to the same projections, from this level, the gap would increase steadily to 91.13 MMSCMD by 2011-12. At present in India, only the industries in Power and fertilizer sector and small-scale users deserve the supply of Government regulated natural gas under Administered Price Mechanism (APM). According to a policy document (L-12015/5/04-GP (i) of Ministry of Petroleum and Natural
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 17 for arriving at the baseline scenario since this alternative is associated with the barriers mentioned
above.
Alternative 5: Power generation using energy sources (renewable energy sources) other than
coal
In this alternative scenario, the project proponent could have considered generation of power using
renewable energy sources which includes hydro power, wind power, biomass energy etc. In this option
there would be no GHG emissions and this alternative is in compliance with all applicable laws and
regulations of the country. However, generation of power to the tune of 1320MW (which would be
running on a base load) using renewable resources like small hydro, wind, biomass etc is not a
technically and economically feasible proposition on account of inconsistent availability of renewable
sources and high risk associated with renewable technologies. The project proponent would face high
investment, technological and other barriers in order to implement this alternative. Furthermore,
renewable resource based power generating stations typically used for peak load services. Wind
energy generation is seasonal and intermittent during the seasons. Highest plant load factor achieved
by the wind based generation projects in a coastal Indian state like Maharashtra, is at a maximum of
33%, which is not comparable to the proposed project activity13. Biomass based generation projects
are planned to encourage utilization of waste land and active utilization of biomass available.
According to Ministry of New and Renewable Energy, Govt. of India, maximum load factor
achievable is 75%, which is less than that of the proposed project activity14. Typically biomass based
power stations are to the tune of 10 MW and hence is not a feasible alternative to the proposed project
activity.
Gas the power and fertilizer sector and some other specific units will receive NG supply against their existing allocation. Also, in case of reduction in availability of this gas in future, the supplies to APM consumer would be reduced on a pro-rate basis. The project proponent – APML does not have any existing allocation of NG. Furthermore, considering the declining volume of APM gas supply in future (Ref: CRISIL Research Natural Gas Update – November 2007) it is highly unlikely that the 1320 MW or nearing power generation capacity would come up based on APM gas supply.
http://72.14.235.132/search?q=cache:jtfvfuTUOp0J:powermin.nic.in/whats_new/PFR/Kearla/Perijankutty.pdf+powermin+Brahmapuram&hl=en&ct=clnk&cd=1&gl=in 13 Page 30 of Maharashtra Electricity Regulatory Commission Order, Case No. 17 (3), 3, 4 & 5 of 2002 found at http://mercindia.org.in/pdf/Detail_Wind_Energy_Order.pdf 14 http://mnes.nic.in/annualreport/2006_2007_English/HTML/ch2_pg5.htm
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 18 Large hydro projects face huge risks of geological and hydrological uncertainties and could cause
dislocation of significant population15.
Plant Load Factor for Hydro Power Plants in India16
Therefore, the nature of the project activity and this baseline option on delivering similar services vary
significantly17.
Hence this alternative is not considered further for arriving at the baseline scenario.
Alternative 6. Power generation using energy sources (nuclear) other than coal
As an alternative to the project activity, the project proponent could have opted for nuclear power
generation. In this option there would be very less GHG emissions and this alternative will be in
compliance with all applicable laws and regulations of the country. However, as per the present
Atomic Energy Act of India nuclear power generation is restricted to Government or Government
owned companies only and not so far open to any private sector participation18. The project proponent
has to face stiff regulatory barriers in order to implement this option. Hence this alternative is not
considered further for arriving at the baseline scenario.
15 Policy on Hydro Power Development, Govt of India, Page 2-3 found at http://www.powermin.nic.in/whats_new/pdf/hydro_power_policy_developmemt.pdf 16 http://www.cea.nic.in/power_sec_reports/general_review/0405/ch2.pdf, http://www.cea.nic.in/power_sec_reports/executive_summary/2006_03/6.pdf, http://www.cea.nic.in/power_sec_reports/Executive_Summary/2007_03/6.pdf,
http://www.cea.nic.in/god/opm/Monthly_Generation_Report/18col_07_03.pdf, http://www.cea.nic.in/power_sec_reports/general_review/0405/ch3.pdf 17 As per Ministry of Power Guidelines for development of Hydro Electric projects sites by private developers, GoI, several potential risks of natural calamities such as inter-state water sharing disputes, ecological imbalance, displacement and land submergence. For e.g. seven tribunals were set-up by Ministry of Water Resources for resolving various disputes including the inter-state. As a result of these disputes, large hydro generation projects are withheld for execution among various Indian states.
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 19 Alternative 7: Import of electricity from connected grids, including the possibility of new
interconnections.
This alternative involves import of electricity from connected grid to meet the power demand of India.
Table 6: Import of Electricity in India
All India Energy Generation data Generation (GWh) Type of Generation
2007-08 2006-07 2005-06 Thermal 558990.05 527547.36 497214.30 Nuclear 16776.91 18606.75 17238.89 Hydro 123424.12 113358.77 101293.13 Bhutan Import 5290.1 3010.08 1764.12 Total 704481.18 662522.96 617510.44 % of import in Total Generation 0.75 0.45 0.29 http://www.cea.nic.in/god/opm/Monthly_Generation_Report/18col_A_08_03/FILE-04.pdf http://www.cea.nic.in/cea-archive/body/Reports/Monthly%20Generation%20Report/2006/18col_06_03.pdf
http://www.cea.nic.in/power_sec_reports/executive_summary/2008_03/6.pdf
This alternative is in coherence with all applicable laws and regulations of the country. However, the
import of power by India has been 0.75% in 2007-08 and 0.45% in 2006-07. Considering this
historical trend of import of power and also considering the fact that large scale power import in India
is constrained by inadequate power transmission infrastructure and lack of grid integration among
neighboring countries, it can be concluded that the import of electricity from connected grids is not a
realistic and credible alternative and the imported amount of electricity will not be sufficient to meet
the power deficit situation in India. Hence this alternative is not considered any further.
Step 2: Identify the economically most attractive baseline scenario alternative
Most attractive baseline scenario alternative is identified using investment analysis. As per the
guidance of the methodology the levelized cost of electricity generation in INR/kWh has been used as
financial indicator for comparison of economic attractiveness of baseline alternatives.
The major assumptions to arrive at the levelized cost of power generation have been tabulated below.
18 National Report to the Convention on Nuclear Safety, Fourth Review Meeting of the Contracting Parties, April 2008, Govt. of India
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 20
Assumptions Sub critical Super Critical
Project Size MW 1320 1320
Project Cost INR Millions 34937 65600
Debt % 70.00% 70.00%
Equity % 30.00% 30.00%
Rate of Interest on Loan
Capital
% 11.25% 11.25%
Rate of interest on Working
Capital
% 12.00% 12.00%
Return on Equity % 14.00% 14.00%
Loan Repayment Period Years 10 10
Depreciation % 3.60% 3.60%
O&M Costs (Fixed) Million INR/MW 0.8 0.8
O&M Cost (Variable) Million INR/MW 0.00 0.00
Escalation % of Capital Cost 4% 4%
Insurance % of Capital Cost 1.00% 1.00%
Maintenance Spares % of Capital Cost 1.00% 1.00%
Plant Life Years 25 25
PLF % 85% 85%
Auxiliary Consumption % 7.50% 7.50%
Gross generation Million kWh 9828.72 9828.72
Net generation Million kWh 9091.57 9091.57
Discounting Rate % 11.1% 11.1%
Gross Calorific Value kCal/kg 4895 4895
Station Heat Rate (SHR) kCal/kWh 2450 2060
Fuel Price INR/ton 1077.8 1077.8
Fuel Price Escalation % P.A. 5.00% 5.00%
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 21 The values for the subcritical power plant have been taken from a CERC approved order of a power
plant of similar capacity (500 x 2 MW) and approved at the same time when the project activity was
being conceptualized. The cost has been extrapolated for a plant of 1320 MW capacity.
The 70:30 debt/equity for the subcritical power plant is as per standard CERC guidelines and the
same has been used for the supercritical power plant.
The fuel (coal) price has been considered at INR 1077.8 per ton. This figure is arrived at by
considering a coal price of INR 750 per ton, a transportation and handling charge of INR 220 per ton
and a transportation loss of 0.1%19. The coal price of INR 750 per ton20 has been calculated
considering:
a) a royalty for the coal block allocated to the project proponent (including cess etc) (about INR
120/ton)
b) operational costs including manpower cost, power, stores etc
Table 7: Economic analysis of all the realistic and credible alternatives available with APML in absence of the proposed project activity
Description of Alternative Levelized Cost of electricity
production (INR/kWh)
Alternative 1 The project activity not implemented as a
CDM project
2.01
Alternative 2 Power generation using sub-critical coal-
fired power generation technologies
1.64
Note: The calculation sheet is attached as Appendix 2.
As the data shows in above Table 7, the occurrence of Alternative -1 is prohibited by the higher
levelized cost of electricity generation. Hence, this alternative can not be considered as baseline option.
Alternative 2 “Power generation using sub-critical coal-fired power generation technologies” is
therefore the baseline for the proposed project activity.
19 Project Information Memorandum by SBI Capital Markets Limited for Adani Power Maharashtra Limited 20 Advance Coal Management & Marketing Pvt Ltd: Assessment of estimated project cost and operational cost at Lohara West & Lohara Extension Opencast Project
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 22 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 CDM project activity (assessment and demonstration of additionality): >> As per the approved methodology (ACM0013, Version 02.1) followed in this PDD,
“A power plant is a facility for the generation of electric power from thermal energy from
combustion of a fuel. In case where several power generation units have been installed at one site in
a single location, each unit should be considered as a power plant.”
Therefore, each of the 660 MW super-critical technology based unit (in project activity scenario) or
500 MW sub-critical units (in baseline scenario) have been considered as separate power plant for
subsequent discussion on emission reduction computation.
Even though this super-critical technology is already in practice in other nations like UK and Japan, no
super-critical power plant is yet operational in India21. In India, out of total installed power generation
capacity of 143061.01 MW the installed capacity of coal based thermal power constitutes 76048.88
MW as on 31.03.2008 (Refer to Table 4). However, till date not a single thermal power plant in India
has come up with super-critical technology. This demonstrates the real uniqueness of the project. The
technology has achieved very limited penetration in India due to the investment, technology and other
barriers as elaborated below.
The “Tool for the demonstration and assessment of additionality” version 05.2 has been followed to
demonstrate the additionality of this proposed project activity.
21 Page 141 of UMPP Risk Analysis Report by Mott MacDonald, British High Commission found at the link http://www.defra.gov.uk/environment/climatechange/internat/devcountry/pdf/umpp-risk-analysis.pdf
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 23
Step 1: Identification of alternatives to the project activity consistent with current laws and regulations Realistic and credible alternatives to the proposed project activity which are consistent with mandatory
laws and regulations and can be part of the baseline scenario have been identified in Section B.4. Thus
Option 2, which involves power generation using sub-critical coal fired technology, has been selected
as the most representative baseline for this proposed project activity.
Step 2: Investment Analysis
The project proponent has performed investment analysis to establish project additionality.
Sub-step 2a: Determine appropriate analysis method
Investment comparison analysis has been applied to establish additionality of the project activity.
Sub-step 2b: Option II
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 24 As per the additionality tool, levelized cost of electricity production may be selected as a financial
indicator of the project. For the project activity under consideration, levelized cost of electricity
production has been identified as the most suitable financial indicator for the project type.
Sub-step 2c: Calculation and comparison of financial indicators
Options
Levelized cost of electricity production
(INR/kWh)
Baseline: Power generation using sub-critical
coal-fired power generation technologies
1.64
Project activity not implemented as a CDM
project
2.01
Since, the levelized cost of electricity production of the proposed project activity is substantially
higher than the levelized cost of electricity production for the baseline case, it can be concluded that
the proposed project activity is additional from the financial point of view. The above comparison
between levelized costs of electricity production signifies that it is not a financially attractive
proposition for the project proponent to invest in the proposed project activity. However, the revenue
flow to the project activity through CDM would make the project financially viable.
Sub-step 2d: Sensitivity Analysis
The sensitivity analysis has been performed for a -/+10% variation in parameters of the plant load
factor, project cost, station heat rate, rate of interest on loan capital and coal cost for both subcritical
and supercritical power plants of realistically comparable capacity. The sensitivity analysis further
proves the robustness of the financial additionality of the proposed project activity.
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 25
Step 3: Barrier Analysis
As investment analysis has been carried out to prove the additionality of the project activity, hence
barrier analysis is not done.
Step 4. Common practice analysis
Sub-step 4a. Analyze other activities similar to the proposed project activity
As per the definition of the term “similar activities” (as indicated in Tools for the demonstration and
assessment of additionality - Version 05.2), plants are considered similar only if they rely on a broadly
similar technology or practices, are of a similar scale, take place in a comparable environment with
respect to regulatory framework and are undertaken in the relevant country/region.
The employment of super-critical technology and at large scale is a new addition in India. At present
there is no operating super-critical power plant in India at this scale (installed capacity of 1320 MW)
which is running on coal and supplying electricity to the grid. At the time of project conception, the
Mundra UMPP, Sasan UMPP, Krishnapatnam UMPP, North Karanpura (NTPC) and Adani Power
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 26 (Phase 3), Mundra were being conceptualized. However the UMPPs are of a higher capacity (4000
MW) and use a different unit size (800 MW). The NTPC plant is also of a higher capacity (1980
MW). Only the Adani Power Plant in Mundra satisfies the criteria to similar activities. (All the five
projects i.e. the Mundra UMPP, Sasan UMPP, Krishnapatnam UMPP, NTPC North Karanpura
projects and Adani –Phase 3 have been conceptualized considering CDM revenues)22.
Sub-step 4b. Discuss any similar options that are occurring
As there are no similar activities observed, this authenticate similar activities are not commonly
carried-out. Hence the need to any similar options that are occurring would not arise.
Since similar activities are not observed, hence Step 4 is satisfied.
Thus, it may be concluded that the proposed project activity is additional as it satisfies all the criteria
of the “Tool for the demonstration and assessment of additionality”, Version 05.2.
The objective of the proposed project activity is to generate and supply power to consumers in India
through electricity distribution agencies on a long term basis. The objective holds true irrespective of
the technology and investment chosen for the power plant. Under the proposed project activity, the
project proponent will be supplying 1320 MW of power to Maharashtra State Electricity Distribution
Co. Ltd as per the competitive tariff based mutually signed contractual agreement. In absence of the
said Power Purchase Agreement with the Maharashtra State Electricity Distribution Co. Ltd for the
proposed project activity, the project proponent would have generated power and sold it to other
authorities/ third party etc. The agreement with any other distribution authority would have also been
based on a similar competitive tariff based bidding process.
Even though there are other cost effective options (coal based subcritical power plant), yet the project
proponent decided to go for implementation of a supercritical coal based power plant. The tariff of
22 The Mundra UMPP was the first supercritical power plant based on 800 MW units (http://www.ifc.org/ifcext/spiwebsite1.nsf/1ca07340e47a35cd85256efb00700cee/1584EA74DA3979AB852573A0006847BB), which was awarded in April 2007 (http://news.oneindia.in/2007/04/23/tata-power-takes-over-mundra-umpp.html). The Sasan and Krishnapatnam UMPPs were awarded between May-October 2007 (http://www.business-standard.com/india/news/reliance-power-bags-krishnapatnam-umpp/29907/on. The fourth UMPP at Tilaiya was to be awarded at a much later date in December 2008 (http://www.projectsmonitor.com/detailnews.asp?newsid=16355). All these projects are of a higher capacity (4000 MW) as compared to the proposed project activity. All the UMPPs have been conceptualized with CDM consideration (Page 7 of http://www.pfcindia.com/Tariff_Policy.pdf). The supercritical plant at North Karanpura which is also of a higher capacity as compared to the proposed project activity, was also conceptualized with CDM consideration. (http://cdm.unfccc.int/methodologies/PAmethodologies/publicview.html?meth_ref=NM0217)
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 27 power generation from this power plant is also independent of the technology or investment chosen for
the power plant. The project proponent decided to go for the implementation of a coal based
supercritical power plant due to the reason that the flow of CDM revenue to the supercritical coal
based power plant would improve the cost effectiveness of the project activity and the energy efficient
supercritical power plant would contribute to the cause of mitigation of climate change.
The major milestones in the CDM chronology of the proposed project activity have been tabulated
below. The table demonstrates that the project proponent was well aware of the CDM modalities and
procedures before they decided to go ahead with the project activity and that CDM was the major
decisive factor for them to go ahead with the proposed project activity.
Sr. No.
Subject / Activity Date Remark
1 Email communications with CDM consultants 29.9.2007 Awareness of CDM
05.10.2007 2 Information Memorandum by SBI Caps Nov-07 3 Proposal placed by Vineet Jain, for implementation of
the project activity 07.02.2008 CDM
consideration 4 Approval for implementation of project activity by group
Chairman 08.02.2008
5 Email communications with CDM consultants for appointment
20.2.2008
22.2.2008 6 EPC Contract with M/s. SCMEC for 2 x 660 MW coal
based Thermal Power Project on Super Critical Technology
28.02.2008 Start date of project activity
7 Preparation of PDD Mar-Jun 2008 8 PPA Signed with MSEDCL 08.09.2008 9 Communications with validator for appointment 16.09.2008 10 Presentation to DNA (Ministry of Environment &
Forests, Govt of India) 17.11.2008
11 Validator appointment 28.11.2008 12 Webhosting 01 Jan-30 Jan 2009 13 Receipt of Host Country Approval 17.04.2009
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 28 B.6. Emission reductions:
B.6.1. Explanation of methodological choices: The relevant methodological steps are described below. Baseline Emissions Baseline emissions are calculated by multiplying the electricity generated in the project plant (EGPJ,y)
with a baseline CO2 emission factor (EFBL,CO2,y), as follows:
yCOBLyPJy xEFEGBE ,2,,=
Where:
BEy Baseline emissions in year y (tCO2)
EGPJ,y Net quantity of electricity generated in the project plant in year y (MWh)
EFBL,CO2 Baseline emission factor in year y (tCO2/MWh)
EFBL,CO2 is determined using the lower value between the emission factor of the technology and fuel
type that has been identified as the most likely baseline scenario and a benchmark emission factor
determined based on the performance of the top 15% power plants that use the same fuel as the project
plant and any technology available in the geographical area as defined in Step 2 below.
To calculate EFBL,CO2,y the lowest value among the following two options will be used.
Option 1: The emission factor of the technology and fuel identified as the most likely baseline scenario
under “Identification of the baseline scenario” section above, and calculated as follows:
Where:
EFBL,CO2,y Baseline emission factor in year y (tCO2/MWh)
EFFF,BL,CO2,y CO2 baseline emission factor of the baseline fossil fuel type that has been identified as the most likely baseline scenario (tCO2 / Mass or volume unit)
EFFF,PJ,CO2,y Average CO2 emission factor of the fossil fuel type used in the project plant in year y (tCO2 / Mass or volume unit)
ηBL Energy efficiency of the power generation technology that has been identified as
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 29
the most likely baseline scenario
For the proposed project activity, the baseline fossil fuel type that has been identified as the most
likely baseline scenario is coal and the fossil fuel to be used in the proposed project activity is also
coal.
Option 2: The average emissions intensity of all power plants j, corresponding to the power plants
whose performance is among the top 15 % of their category, as follows:
∑∑
=
jxj
jxjCOxjxj
yCOBL EG
EFNCVFCEF
,
,,2,,
,2,
**
Where:
EFBL,CO2,y Baseline emission factor in year y (tCO2/MWh)
FCj,x Amount of fuel consumed by power plant j in year x (Mass or volume unit)
NCVj,x Net calorific value of the fossil fuel type consumed by power plant j in year x (GJ / Mass
or volume unit)
EFCO2,j,x CO2 emission factor of the fossil fuel type consumed by power plant j in year x (tCO2 /
Mass or volume unit)
EGj,x Net electricity generated and delivered to the grid by power plant j in year x
X Most recent year prior to the start of the project activity for which data is available
J Top 15% performing power plants (excluding cogeneration plants and including power
plants registered as CDM project activities), as identified below, among all power plants
in a defined geographical area (India) that have a similar size, are operated at similar
load (i.e. at base load) and use the same fuel type (coal) as the project activity
For determination of the top 15% performer power plants j, the following step-wise approach is used:
Step 1: Definition of similar plants to the project activity
The sample group of similar power plants should consist of all power plants (except for cogeneration
power plants):
• Those use the same fossil fuel type as the project activity, where fuel types are defined in the
following categories:
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 30
-Coal
-Oils (e.g. diesel, kerosene, residual oil)
-Natural gas
• Those have been constructed in the previous five years;
• Those have a comparable size to the project activity, defined as the range from 50% to 150% of the
rated capacity of the project plant;
• Those are operated in the same load category, i.e. at peak load (defined as a load factor of less than
3,000 hours per year) or base load (defined as a load factor of more than 3,000 hours per year) as the
project activity; and
• Those have operated (supplied electricity to the grid) in the year prior to the start of the project
activity.
The sample group of plants identified consists of coal based sub-critical power plants that have a
capacity between 330MW to 990MW, have been constructed in last 5 years, operate at base load and
have supplied electricity to the grid before start of the proposed project activity.
Step 2: Definition of the geographical area
As per the methodology ACM0013, Version 02.1, the geographical area to identify similar power
plants is chosen in a manner that the total number of power plants “N” in the sample group comprises
at least 10 plants. As a default, the grid to which the project plant will be connected should be used.
As the number of similar plants, as defined in Step 1, within the Western regional grid boundary is
less than 10, the geographical area is extended to India. The number of similar plants is now greater
than 10.
Step 3: Identification of the sample group
Identify all power plants n that are to be included in the sample group. Determine the total number
“N” of all identified power plants that use the same fuel as the project plant and any technology
available within the geographical area, as defined in Step 2 above.
The sample group should also include all power plants within the geographical area registered as
CDM project activities, which meet the criteria defined in Step 1 above.
Step 4: Determination of the plant efficiencies
Calculate the operational efficiency of each power plant n identified in the previous step. The most
recent one-year data available is used. The operational efficiency of each power plant n in the sample
group is calculated as follows:
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 31
8.277** ,,
,,
xnxn
xnxn NCVFC
EG=η
Where:
EGn,x Net electricity generated and delivered to the grid by the power plant n in the year x
(MWh)
FCn,x Quantity of fuel consumed in the power plant n in year x (Mass or volume unit)
NCVn,x Net calorific value of the fuel type fired in power plant n in year y (GJ / mass or volume unit)n are all power plants in the defined geographical area that have a similar size, are
operated at similar load and use the same fuel types as the project activity
277.8 Conversion factor from TJ to MWh
x Most recent year prior to the start of the project activity for which data are available
Step 5: Identification of the top 15% performer plants j
Sort the sample group of N plants from the power plants with the highest to the lowest operational
efficiency. Identify the top 15% performer plants j as the plants with the 1st to Jth highest operational
efficiency, where the J (the total number of plants j) is calculated as the product of N (the total number
of plants n identified in step 3) and 15%, rounded down if it is decimal.4 If the generation of all
identified plants j (the top 15% performers) is less than 15% of the total generation of all plants n (the
whole sample group), then the number of plants j included in the top 15% performer group should be
enlarged until the group represents at least 15% of total generation of all plants n. All Steps should be
documented transparently, including a list of the plants identified in Steps 3 and 5, as well as relevant
data on the fuel consumption and electricity generation of all identified power plants.
The emission factor has been calculated by Central Electricity Authority, Govt of India and published
on their website (http://www.cea.nic.in/planning/cdm.pdf).
Project emissions
The CO2 emissions from electricity generation in the proposed project activity (PEy) is calculated
using the latest approved version of the “Tool to calculate project or leakage CO2 emissions from
fossil fuel combustion” (Version 02, EB 41), where the process j in the tool corresponds to the
combustion of fossil fuels in the project plant. Here the process j corresponds to combustion of coal
for power generation using super-critical technology in the proposed project activity. As per this tool,
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 32 CO2 emissions from fossil fuel combustion in process j are calculated based on the quantity of fuels
combusted and the CO2 emission coefficient of those fuels, as follows:
∑=i
yiyjiyjFC xCOEFFCPE ,,,,,
Where:
PEFC,j,y CO2 emissions from fossil fuel combustion in process j during the year y (tCO2 / yr)
FCi,j,y Quantity of fuel type i combusted in process j during the year y (mass or volume unit /
yr);
COEFi,y CO2 emission coefficient of fuel type i in year y (tCO2 / mass or volume unit);
I Fuel types combusted in process j during the year y
The CO2 emission coefficient COEFi,y can be calculated following two procedures, depending on the
available data on the fossil fuel type i, as follows:
Option A: The CO2 emission coefficient COEFi,y is calculated based on the chemical composition of
the fossil fuel type i, or
Option B: The CO2 emission coefficient COEFi,y is calculated based on net calorific value and CO2
emission factor of the fuel type i.
Option A is followed here.
12/44,,, xwCOEF yicyi =
Where:
COEFi,y CO2 emission coefficient of fuel type i in year y (tCO2 / mass or volume unit);
wc,i,y Weighted average mass fraction of carbon in fuel type i in year y (tC / mass unit of the
fuel)
i Fuel types combusted in process j during the year y
Note: For ex-ante calculation of emission reduction, the value of wc,i,y is estimated to be 0.416 or
41.6%. As this is a future project, hence the data sources (fuel supplier invoices or measurement by
project proponent) as mentioned in the “Tool to calculate project or leakage CO2 emissions from fossil
fuel combustion” (Version 02) are not applicable here. The value of 41.6% is an estimated value taken
from the technical specifications of the supply contract between the project proponent and SCMEC
(signed on 28th February 2008). The same will be monitored ex-poste as mentioned in section B.7.2 in
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 33 line with the “Tool to calculate project or leakage CO2 emissions from fossil fuel combustion”
(Version 02).
Leakage
The methodology does not require the consideration of any leakage emissions.
LEy=0
LEy are the leakage emissions during the year y (tCO2e).
Emission reductions
Emission reductions (ERy) by the project activity during year y are the difference between the baseline
emissions (BEy), project emissions (PEy) and emissions due to leakage (LEy), and are expressed as
follows:
ERy = BEy − PEy − LEy……………………………………….. (15)
where:
ERy Emission reductions due to the project activity during the year y (tCO2e)
BEy Baseline emissions during the year y (tCO2e)
PEy Project emissions during the year y (tCO2e)
LEy Leakage emissions during the year y (tCO2e)
B.6.2. Data and parameters that are available at validation: (Copy this table for each data and parameter) Data / Parameter: EFFF,BL,CO2,y Data unit: tCO2/GJ Description: CO2 baseline emission factor of the baseline fossil fuel type that has been
identified as the most likely baseline scenario Source of data used: 2006 IPCC Guidelines for National Greenhouse Gas Inventories, Table
2.2, Default Emission Factor for Sub bituminous Coal Value applied: 0.0961 Justification of the choice of data or description of measurement methods and procedures actually applied :
IPCC default value is internationally accepted and hence used.
Any comment: -
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 34 Data / Parameter: ηBL
Data unit: - Description: Energy efficiency of the power generation technology that has been
identified as the most likely baseline scenario Source of data used: This parameter is calculated as part of the baseline scenario selection
procedure. Value applied: 0.351 Justification of the choice of data or description of measurement methods and procedures actually applied :
The efficiency has been taken as the higher efficiency between: a) Efficiency (35.1%) calculated as per the station heat rate (of 2450 kCal/kWh as given in tariff order of CERC, Govt of India) of baseline subcritical power plants b) Efficiency (31.8%) calculated as per the weighted average station heat rate (of 2703.9 kCal/kWh as given in Annex 3, Table A1) of thermal power plants in India in 2007-08 published by CEA, Govt of India.
Any comment: Data / Parameter: EFFF, PJ,CO2,y Data unit: tCO2e/GJ Description: CO2 emission factor of the fossil fuel type consumed by the proposed
project activity Source of data used: 2006 IPCC Guidelines for National Greenhouse Gas Inventories-Table
2.2 for sub bituminous coal Value applied: 0.0961 Justification of the choice of data or description of measurement methods and procedures actually applied :
The proposed project activity will use sub-bituminous coal. Hence IPCC default value of emission factor for sub-bituminous coal is used as it is internationally accepted. (IPCC values are used as well documented and reliable regional/national values are not available).
Any comment: Data / Parameter: EFBL,CO2,y Data unit: tCO2e/MWh Description: Baseline emission factor in the year Source of data used: i) 2006 IPCC Guidelines for National Greenhouse Gas Inventories (IPCC
values are used as well documented and reliable regional/national values are not available) ii) CEA Website (www.cea.nic.in)
Value applied: 0.941 Justification of the choice of data or description of measurement methods and procedures actually applied :
The baseline emission factor as per the two options namely Option 1 and Option 2 have been calculated and the lower value of the two options (in this case Option 2) have been used for calculation of baseline emissions. Option 1: Calculated from the three parameters ηBL, EFFF,BL,CO2,y and EFFF,PJ,CO2,y. The value is calculated as 0.964 tCO2/MWh Option 2: This factor is published on the CEA website
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 35
(http://www.cea.nic.in/planning/cdm.pdf) and the value stands at 0.941 tCO2/MWh
Any comment: Since Option 2 is the lower between Options 1 and 2, hence the Option 2 emission factor has been used for emission reduction calculation. Also as per the methodology ACM0013, version 02.1, in case of option 2, EFBL,CO2,y is not monitored annually but only calculated once at the start of the crediting period and updated at the renewal of a crediting period.
Note: The parameters FCj,x, FCn,x, NCVj,x, NCVn,x, EGj,x and EGn,x are required to calculate the
baseline emission factor (as per Option 2). Since the baseline emission factor EFBL,CO2,y is calculated
and published by CEA, Govt of India, hence the parameters FCj,x, FCn,x, NCVj,x, NCVn,x, EGj,x and
EGn,x have not been included in this section of data and parameters available at validation.
CEA has publicly made available a document which says that the factor of 0.941 tCO2/MWh has been
calculated as per the methodology ACM0013, considering data upto 2007-08 and is applicable to new
coal fired power generating units with supercritical steam parameters. The same is available at:
http://www.cea.nic.in/planning/cdm.pdf
The detailed step wise procedure and calculation based on the methodology ACM0013 to calculate the
emission factor (of 0.941 tCO2/MWh) as per Option 2 can also be found in pages 20-26 of “CO2
Baseline Database for the Indian Power Sector, User Guide”, Version 4.0, October 2008 published by
Government of India, Ministry of Power, Central Electricity Authority (CEA) and publicly available
at: http://www.cea.nic.in/planning/c%20and%20e/user_guide_ver4.pdf
B.6.3 Ex-ante calculation of emission reductions: The list of power plants that are coal based sub-critical power plants with a capacity between 330MW
to 990MW, constructed in last 5 years, operating at base load and supplying electricity to the grid
before start of the proposed project activity have been included in the sample group.
Table 11: Power Plants included in the sample group
S. No. Name Unit No. Capacity Location Date of
Commissioning
1. TALCHER STPS 3 500 Orissa 4-Jan-03
2. TALCHER STPS 4 500 Orissa 25-Oct-03
3. TALCHER STPS 5 500 Orissa 13-May-04
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 36 4. TALCHER STPS 6 500 Orissa 6-Feb-05
5. R_GUNDEM STPS 7 500 Andhra Pradesh 26-Sep-04
6. VINDH_CHAL STPS 9 500 Madhya Pradesh 27-Jul-06
7. VINDH_CHAL STPS 10 500 Madhya Pradesh 8-Mar-07
8. RIHAND 3 500 Uttar Pradesh 31-Jan-05
9. RIHAND 4 500 Uttar Pradesh 24-Sep-05
10. KAHALGAON 6 500 Bihar 16-Mar-2008
11. BELLARY TPS 1 500 Karnataka 3-Dec-07
12. SANJAY GANDHI 5 500 Madhya Pradesh 18-Jun-07
13. SIPAT STPS 1 500 Chhattisgarh 27-May-07
14. KAHALGAON 5 500 Bihar 31-Mar-2007
Source: Baseline Carbon Dioxide Emission Database Version 4.0 – LATEST
http://www.cea.nic.in/planning/c%20and%20e/Government%20of%20India%20website.htm
Out of these power plants-only the plants has been considered that satisfy the criteria to be included in
the top 15% power plants. Accordingly, two units of 500MW i.e. Talchar STPS unit 3 and 4 are
identified as 15% top performing units. These units also cover more than the 15% of the total net
generation of all plants selected in the sample Group. CEA has calculated the baseline emission factor
based on the net electricity generation and unit wise coal consumption by the top power plants as per
Option 2 given in the methodology ACM0013.
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 37
Table 12: Baseline Emissions
Baseline Emissions
Option 1 Option 2
Year PLF Auxiliary Consump
tion
EGPJ,y EFFF,BL,CO2,
y
EFFF,PJ,CO2,y ηBL EFBL,CO2,y EFBL,CO2
,y
BEy
% % MWh tCO2/GJ tCO2/GJ tCO2/MWh
tCO2/MWh
tCO2
Sub-bituminous
coal
Coal used in project
Aug 2011-Jul 2012
85 7.50% 7197490 0.0961 0.0961 0.351 0.986 0.941 6772838
Aug 2012-Jul 2013
85 7.50% 9091566 0.0961 0.0961 0.351 0.986 0.941 8555164
Aug 2013-Jul 2014
85 7.50% 9091566 0.0961 0.0961 0.351 0.986 0.941 8555164
Aug 2014-Jul 2015
85 7.50% 9091566 0.0961 0.0961 0.351 0.986 0.941 8555164
Aug 2015-Jul 2016
85 7.50% 9091566 0.0961 0.0961 0.351 0.986 0.941 8555164
Aug 2016-Jul 2017
85 7.50% 9091566 0.0961 0.0961 0.351 0.986 0.941 8555164
Aug 2017-Jul 2018
85 7.50% 9091566 0.0961 0.0961 0.351 0.986 0.941 8555164
Aug 2018-Jul 2019
85 7.50% 9091566 0.0961 0.0961 0.351 0.986 0.941 8555164
Aug 2019-Jul 2020
85 7.50% 9091566 0.0961 0.0961 0.351 0.986 0.941 8555164
Aug 2020-Jul 2021
85 7.50% 9091566 0.0961 0.0961 0.351 0.986 0.941 8555164
Total 83769310
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 38
Table 13: Project Emissions
Project Emissions Year Sub-Bituminous Coal
required ton per MWh FCi,i,y Wc,i,y PEy
ton/MWh ton %C tCO2 Aug 2011-Jul 2012 0.529 3807870 41.6 5808271 Aug 2012-Jul 2013 0.529 4809941 41.6 7336763 Aug 2013-Jul 2014 0.529 4809941 41.6 7336763 Aug 2014-Jul 2015 0.529 4809941 41.6 7336763 Aug 2015-Jul 2016 0.529 4809941 41.6 7336763 Aug 2016-Jul 2017 0.529 4809941 41.6 7336763 Aug 2017-Jul 2018 0.529 4809941 41.6 7336763 Aug 2018-Jul 2019 0.529 4809941 41.6 7336763 Aug 2019-Jul 2020 0.529 4809941 41.6 7336763 Aug 2020-Jul 2021 0.529 4809941 41.6 7336763
Total 47097337 71839138
Table 14: Emission Reductions
Year Baseline Emission Project Emission Emission reduction tCO2 tCO2 tCO2
Aug 2011-Jul 2012 6772838 5808271 964567 Aug 2012-Jul 2013 8555164 7336763 1218401 Aug 2013-Jul 2014 8555164 7336763 1218401 Aug 2014-Jul 2015 8555164 7336763 1218401 Aug 2015-Jul 2016 8555164 7336763 1218401 Aug 2016-Jul 2017 8555164 7336763 1218401 Aug 2017-Jul 2018 8555164 7336763 1218401 Aug 2018-Jul 2019 8555164 7336763 1218401 Aug 2019-Jul 2020 8555164 7336763 1218401 Aug 2020-Jul 2021 8555164 7336763 1218401
Total 83769310 71839138 11930172
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 39
B.6.4 Summary of the ex-ante estimation of emission reductions:
Year
Estimation of
proposed project
activity
emission
(tonnes of CO2 e)
Estimation of
baseline
emissions (tonnes
of CO2 e)
Estimation of
leakage
(tonnes
of CO2 e)
Estimation of
emission
reductions
(tonnes of
CO2 e)
Aug 2011-Jul 2012 5808271 6772838 0 964567
Aug 2012-Jul 2013 7336763 8555164 0 1218401
Aug 2013-Jul 2014 7336763 8555164 0 1218401
Aug 2014-Jul 2015 7336763 8555164 0 1218401
Aug 2015-Jul 2016 7336763 8555164 0 1218401
Aug 2016-Jul 2017 7336763 8555164 0 1218401
Aug 2017-Jul 2018 7336763 8555164 0 1218401
Aug 2018-Jul 2019 7336763 8555164 0 1218401
Aug 2019-Jul 2020 7336763 8555164 0 1218401
Aug 2020-Jul 2021 7336763 8555164 0 1218401
Total (tonnes of CO2 e) 71839138 83769310 0 11930172 B.7 Application of the monitoring methodology and description of the monitoring plan:
B.7.1 Data and parameters monitored: (Copy this table for each data and parameter) Data / Parameter: EGPJ,y Data unit: MWh Description: Net quantity of electricity generated in the project plant in year y Source of data to be used:
Power plant records
Aug 2011-Jul 2012 7197490 Aug 2012-Jul 2013 9091566 Aug 2013-Jul 2014 9091566 Aug 2014-Jul 2015 9091566 Aug 2015-Jul 2016 9091566 Aug 2016-Jul 2017 9091566 Aug 2017-Jul 2018 9091566 Aug 2018-Jul 2019 9091566
Value of data applied for the purpose of calculating expected emission reductions in section B.5
Aug 2019-Jul 2020 9091566
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 40
Aug 2020-Jul 2021 9091566 Description of measurement methods and procedures to be applied:
-This data will be monitored continuously by cumulative type kWh meter. The same will be recorded on a daily basis. The kWh meter will be calibrated on a regular interval by an accredited agency. The Plant In-charge will be responsible for the regular calibration of the meter. -Data will be recorded in paper/electronic format and archived for Crediting Period + 2 years.
QA/QC procedures to be applied:
The data can be cross verified with the electricity sales invoices.
Any comment: The installed meter will monitor the gross generation and auxiliary consumption of the proposed project activity. The same meter will also display the net generation based on the difference between the gross generation and auxiliary consumption.
Parameters to be monitored to calculate Project Emissions as per Tool to calculate project or leakage CO2 emissions from fossil fuel combustion/Version 02
Data / Parameter: FCi,j,y Data unit: Ton/year Description: Quantity of fuel type i combusted in process j during the year y Source of data to be used:
Power plant records
Aug 2011-Jul 2012 3807870 Aug 2012-Jul 2013 4809941 Aug 2013-Jul 2014 4809941 Aug 2014-Jul 2015 4809941 Aug 2015-Jul 2016 4809941 Aug 2016-Jul 2017 4809941 Aug 2017-Jul 2018 4809941 Aug 2018-Jul 2019 4809941 Aug 2019-Jul 2020 4809941
Value of data applied for the purpose of calculating expected emission reductions in section B.5
Aug 2020-Jul 2021 4809941 Description of measurement methods and procedures to be applied:
This data will be monitored continuously with the help of a weighing machine installed at each power generation unit. The same will be recorded on a daily basis. The weighing machine will be calibrated annually by an accredited agency. The Plant In-charge will be responsible for the regular calibration of the instrument. -Data will be recorded in paper/electronic format and archived for Crediting Period + 2 years.
QA/QC procedures to be applied:
The consistency of metered fuel consumption quantities would be cross-checked by an annual energy balance that is based on purchased quantities and stock changes. Where the purchased fuel invoices can be identified
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 41
specifically for the CDM project, the metered fuel consumption quantities would also be cross-checked with available purchase invoices from the financial records.
Any comment: Total coal consumption will be monitored at project end and cross verified with audited balance sheet.
Data / Parameter: wc,i,y Data unit: % Description: Weighted average mass fraction of carbon in fuel type i in year y (tC /
mass unit of the fuel) Source of data to be used:
Data source Conditions for using the data
source a) Values provided by the fuel supplier in invoices
This is the preferred source.
b) Analysis reports of coal from a national/international accredited laboratory
If a) is not available
Value of data applied for the purpose of calculating expected emission reductions in section B.5
i=1 for coal whose wc,i,y= 41.6%
Description of measurement methods and procedures to be applied:
-Data will be recorded in paper/electronic format and archived for Crediting Period + 2 years. -Data will be monitored on a monthly basis.
QA/QC procedures to be applied:
The reliability of the parameter is ensured since it is from the fuel supplier or a national/international accredited laboratory. The values under a) or b) would be checked to see if they are within the uncertainty range of the IPCC default values as obtained from Tables 1.2 and 1.3, Vol. 2 of the 2006 IPCC Guidelines. If the values fall below this range additional information from the testing laboratory will be collected to justify the outcome or conduct additional measurements. The laboratories in b) would have ISO 17025 accreditation or would be able to justify that they can comply with similar quality standards.
Any comment: For ex-ante calculation of emission reduction, an estimated value of wc,i,y
has been used.
Actual measurements would be undertaken in line with national fuel standards.
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 42
B.7.2 Description of the monitoring plan: Please refer to Annex 4 for the monitoring plan. B.8 Date of completion of the application of the baseline study and monitoring methodology and the name of the responsible person(s)/entity(ies)
25th March 2009
Name of person/entity determining the baseline:
Consultants and Experts of Adani Power Maharashtra Limited. Please refer to Annex 1 for contact
details.
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 43 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:
28th February 2008 (Agreement Executed) C.1.2. Expected operational lifetime of the project activity: 25 years 0 months C.2 Choice of the crediting period and related information: C.2.1. Renewable crediting period C.2.1.1. Starting date of the first crediting period:
Not applicable. C.2.1.2. Length of the first crediting period:
Not applicable. C.2.2. Fixed crediting period: C.2.2.1. Starting date:
01st August 2011 or on registration at UNFCCC (whichever is later) C.2.2.2. Length:
10 years 0 months
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 44 SECTION D. Environmental impacts D.1. Documentation on the analysis of the environmental impacts, including transboundary impacts:
A comprehensive study on the project’s positive and negative impacts on the local environment and on
society is thus a key element for each CDM project. Article 12 of the Kyoto Protocol requires that a
CDM project activity lead to the sustainable development of the host country. APML proposes to
implement the proposed project activity because of its commitment to ensure maximum global and
local benefits in relation to certain environmental and social issues and is a major step towards
sustainable development.
Assessment of Environmental Impact
The impact of the project on the environment can be seen broadly in two stages:
1. Construction phase
2. Operational phase
Impacts during construction phase
As the construction period is around three years whereas the lifetime of the power plant is around 25
years, so the impacts due to the construction activities are negligible. Associated activities would
cause air pollution which would be short-term and would cease to exist beyond the construction phase.
Impacts during operational phase
Since the operating technology is occurring at super-critical conditions, most of the GHGs emissions
are occurring due to the consumption of coal but if a sub-critical power plant of the same capacity had
been set up, then the coal consumption would have been higher resulting in more GHG emissions.
The nature of the impacts that are evident during the operational and maintenance phases are
discussed in the tables given below. All possible environmental aspects for the proposed project
activity have been identified and discussed for their impacts on the baseline environment (that prevails
before the proposed project activity is executed). The following table summarizes the environmental
scenario before the proposed project activity is executed, proposed project activity’s local and
environmental, social and other impacts, benefits and the mitigation measures taken by APML to
reduce/ minimize negative impacts if any and enhance the positive impacts.
Environment Impacts and Mitigation Measures
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 45 Possible Impact Mitigation during construction Mitigation during operation
Air Impact § Spray water on dry surface
generating dust particles
§ Regulate vehicle emission
§ Implementation of ESP and bag
filters
§ Provide proper ash utilization
Plan
§ Green belt development
§ Space Provision for FGD
Soil Quality
Degradation
Removing top soil for construction,
turfing and plantation after civil
works
§ Continuous monitoring of soil
quality
§ Green belt development
§ Proper ash utilization
Drainage and irrigation Seawater will be the source of water for the power plant. So, there will be
no impact on local drainage and irrigation system
Groundwater depletion
& quality degradation
Seawater will be the source of water for the power plant. So, there
will be no impact on groundwater system
Surface water pollution Discharge of effluent will be based on the study done by National Institute
of Oceanography.
Terrestrial ecosystem
(disruption to flora and
fauna)
Suitable site selection avoiding
unnecessary disruption of existing
vegetation
Green belt development conserve
local biota
Disruption of road
traffic
Practice caution in use of vehicles Monitoring road trafficking
situation
Disturbance to water
supply
Establish adequate alternative water
supply
Establish adequate alternative
water supply & Continuous
monitoring
Occupational health
hazard
§ Providing health inspection and
vaccination
§ Organizing proper disposal
procedure of waste
§ Providing adequate sanitary
§ Providing health inspection
and vaccination
§ Periodic health check-up
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 46
facilities to personnel and workers
Safety of workers § Adopt appropriate safety
measures
§ Provide first aid services
§ Make workers aware of risks and
how to avoid these
§ Workers would be provided
with hand gloves ear muffs,
safety boots, safety goggles,
helmets etc
§ Workers should be trained to
follow safe working practices
§ Proper hospital facility would
be provided
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: For the proposed project activity under consideration, the total investment is about INR 6560 crore.
As per Ministry of Environment and Forests Notification, New Delhi, 14th September, 2006, an
Environment Impact Assessment (EIA) study need not be done for a project activity if the investment
is less than INR 100 crore for new project and less than INR 50 crore for expansion / modernization
project23. Therefore, EIA is required for this proposed project activity. Accordingly, a separate
Environment Impact Assessment or EIA study had been developed for the proposed project activity.
The assessment of Environmental Impact for the proposed project activity has also been carried out as
required under Environmental (Protection) Act 1986, Government of India, mandatory for expansion
or modernization of any activity or for setting up new projects listed in Schedule I of the notification.
For the project activity under consideration, Environmental Clearance (EC) received from the Ministry
of Environment & Forest (MoEF), New Delhi for 2x660 MW Tirora Project vide their letter No.: J-
13011/4/2008-IA.II (T) dated 29.5.2008.
23 Source: EIA Notification Amendment dated June 13, 2002
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 47 SECTION E. Stakeholders’ comments E.1. Brief description how comments by local stakeholders have been invited and compiled: Identification of Stakeholders
The proposed 660 x 2 MW super critical project will be implemented by APML. The project activity will use more efficient technology for power generation in comparison to conventional sub critical technology. The GHG emissions will be substantially less as compared to conventional technology based power plant.
The stakeholders identified for the project activity are as under.
• SCMEC – Technology Suppliers
• Elected body of representatives administering the local area (village Panchayat)
• Statutory environmental and pollution boards of government.
• Technical Consultants
• Employees of APML
Stakeholders list includes the government and non-government parties, which are involved in the
project activity at various stages. APML applied / communicated to the relevant stakeholders to get
the necessary clearances. APML had invited all the identified stakeholders for the meeting by sending
invitation letters well in advance. The invitation letter copy as well as the list to whom it had been sent
will be submitted to the DOE. The purpose of convening a local stakeholder meeting was to appraise
the stakeholders about the project activity and get their feedback on the same. The detailed report of
stakeholder consultation will be submitted to the DOE.
E.2. Summary of the comments received:
Stakeholders Involvement
APML has communicated to the relevant stakeholders about the project. As project activity is
environmental friendly which will lead to sustainable development of the local area. Since proposed
project activity does not involves any displacement of the local population which in turn has not
disturbed the local social structure but rather has helped in improving their quality of life.
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 48 Several industries are stakeholders to the project. Project consultants were involved in the project to
take care of various pre-contract and post contract project activities like preparation of reports,
preparation of engineering documents, selection of vendors / suppliers and supervision of project
implementation.
Equipment suppliers will supply the equipments as per the specifications finalized for the project
activity and equipment supplier/APML are responsible for successful erection and commissioning of
the same at the site.
Stakeholders’ Comments
The comments from the local stakeholders have been taken in a very transparent way by the APML
and no adverse comments are being received from any stakeholders. Comments received from the
stakeholders are presented in tabulated format below.
Sl
No
Stake Holder Name Nature of relationship with
APML
Comments
1 Employees of
APML
Employed at APML The employees of APML have
appreciated this initiative of APML.
2 Local Stakeholders Local stakeholders affected by
the proposed project activity
The local stakeholders have lauded
the initiative taken by APML which
will help in employment generation
and electrification of parts of
Maharashtra.
3 Consultants Provided engineering consulting
service to APML for the
proposed project activity
The consultants have encouraged
APML to implement such an
advanced technology which will
result in GHG reduction and
mitigation of global warming.
4 Equipment Suppliers Supplied equipments to APML
for the proposed project activity
The equipment suppliers have
appreciated the initiative of APML
to implement this less GHG
intensive technology.
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 49 E.3. Report on how due account was taken of any comments received:
APML has so far received only positive feedbacks on the project activity from all the stakeholders.
However stakeholder consultation is an on-going process and the project proponent will continue the
process. All the comments received, so far, have been considered and given due consideration while
preparing the CDM Project Design Document.
Furthermore, as per the requirement of UNFCCC, the CDM Project Design Document has been web-
hosted on the DOE’s (Designated Operational Entity) website for a period of one month for global
stakeholder consultation. The comments received by the Validator during the period of global
stakeholder consultation will be properly addressed as a part of CDM process.
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 50
Annex 1
CONTACT INFORMATION ON PARTICIPANTS IN THE PROJECT ACTIVITY
Organization: Adani Power Maharashtra Limited Street/P.O.Box: 7th Floor, Sambhav House, Judges Bungalow Road, Bodakdev, Building: Sambhav Press Building City: Ahmedabad State/Region: Gujarat Postfix/ZIP: 380 015 Country: India Telephone: +91- 79-2555 6927 FAX: +91- 79-2555 7176 E-Mail: [email protected] URL: www.adanigroup.com Represented by: Title: Salutation: Mr. Last Name: Jain Middle Name: First Name: Vineet Department: Sr. Vice President Mobile: +91-9925230124 Direct FAX: +91- 79-2555 7176 Direct tel: +91- 79-2555 6927 Personal E-Mail: [email protected]
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 51
Annex 2
INFORMATION REGARDING PUBLIC FUNDING
No public funding available for this project.
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 52
Annex 3
BASELINE INFORMATION
Table A1: Average station heat rate in Indian power plant as published by Central Electricity Authority, Government of India
Year No. of stations analyzed Capacity (MW) Weighted Average Operating
SHR (kCal/kWh) 2005-06 57 35480 2747 2006-07 56 38611 2861 2007-08 53 37830 2703.9
Source: http://www.cea.nic.in/god/opm/Thermal_Performance_Review/0708/highlights.pdf http://www.cea.nic.in/god/opm/Thermal_Performance_Review/0607/SECTION-13.pdf
Table A2: Baseline Emissions
Baseline Emissions Option 1 Option 2
Year PLF EGPJ,y EFFF,BL,CO2,y EFFF,PJ,CO2,y ηBL EFBL,CO2,y EFBL,CO2,y BEy %
Auxiliary Consumption MWh tCO2/GJ tCO2/GJ tCO2/MWh tCO2/MWh tCO2
%
IPCC value -sub-
bituminous coal
IPCC value- coal used in
project Aug 2011-Jul 2012 85 7.50% 7197490 0.0961 0.0961 0.351 0.986 0.941 6772838
Aug 2012-Jul 2013 85 7.50% 9091566 0.0961 0.0961 0.351 0.986 0.941 8555164
Aug 2013-Jul 2014 85 7.50% 9091566 0.0961 0.0961 0.351 0.986 0.941 8555164
Aug 2014-Jul 2015 85 7.50% 9091566 0.0961 0.0961 0.351 0.986 0.941 8555164
Aug 2015-Jul 2016 85 7.50% 9091566 0.0961 0.0961 0.351 0.986 0.941 8555164
Aug 2016-Jul 2017 85 7.50% 9091566 0.0961 0.0961 0.351 0.986 0.941 8555164
Aug 2017-Jul 2018 85 7.50% 9091566 0.0961 0.0961 0.351 0.986 0.941 8555164
Aug 2018-Jul 2019 85 7.50% 9091566 0.0961 0.0961 0.351 0.986 0.941 8555164
Aug 2019-Jul 2020 85 7.50% 9091566 0.0961 0.0961 0.351 0.986 0.941 8555164
Aug 2020-Jul 2021 85 7.50% 9091566 0.0961 0.0961 0.351 0.986 0.941 8555164
Total 83769310
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 53
Annex 4 MONITORING INFORMATION
The operational and management structure that will monitor the project activity is described below.
Roles and responsibility:
1. General Manager (GM) of the APML Power Plant will have the following responsibilities
§ Ensuring implementation of monitoring procedure
§ Internal audit and project conformance reviews
2. Manager (Operations) will have the following responsibilities
§ Organizing and conduct training programs on CDM
§ Implementing all monitoring control procedures
§ Associating with the Manager (Technical Services) towards maintenance and calibration of
equipments
§ Has the overall responsibility for record handling and maintenance.
§ Reviewing of records and dealing with monitored data
§ Organizing internal audit for checking the data recorded
§ Has the overall responsibility for closing project non-conformances and implementing
corrective actions before the verification
Plant General Manager
Manager (Operations)
Plant Shift Charge Engineers
Shift Engineers
Operators
PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03 CDM – Executive Board page 54 3. Plant Shift Charge Engineer will have the following responsibilities:
§ Supervising and training the operators and maintaining training records.
§ Has the overall responsibility of monitoring measurements and reporting
§ Will assist the Manager (Operations) in record handling, records checks and review and
during internal audit and check the data recorded by the Operators in the individual sections as
described in Section B7.1.
4. The Operator would collect and record appropriate data of the project activity represented in the
monitoring tables of Section B 7.1 based on the monitoring frequency and as per the instructions of his
seniors.
The Monitoring and Verification (M&V) procedures:
§ define a project-specific standard (baseline of historical emissions) against which the project’s
performance (i.e. GHG reductions) and conformance with all relevant criteria will be
monitored and verified.
§ It includes developing suitable data collection methods and data interpretation techniques for
monitoring and verification of GHG emissions.
§ It also allows scope for review, scrutinize and benchmark all this information against reports
pertaining to M & V protocols.
The M&V protocol provides a range of data measurement, estimation and collection
options/techniques in each case indicating preferred options consistent with good practices to allow
project managers and operational staff, auditors, and verifiers to apply the most practical and cost-
effective measurement approaches to the project. The aim is to enable this project have a clear,
credible, and accurate set of monitoring, evaluation and verification procedures. The purpose of these
procedures would be to direct and support continuous monitoring of project performance/key project
indicators to determine project outcomes, greenhouse gas (GHG) emission reductions.
The instrumentation system installed for the project is equipped with shift-wise recording and feedback
facility with desired level of accuracy. The accuracy of measurement can be ensured by the timely
calibration.
- - - - -