Annexure-PFR - Environment Clearance

Transcription

Tamil Nadu Generation and Distribution
Corporation Ltd.
(A Subsidiary of TNEB Limited)
Establishment of 4 x 660 MW Super Critical Thermal Power Plants
in Stage-II & Stage-III
near
2 X 660 MW (Stage-I) Udangudi Super Critical Thermal Power Project
Tuticorin District, Tamil Nadu
Pre-Feasibility Report
[ Doc. No.: FCE-1115125-ME-DOC-PFR-3000-001, Rev R0 ]
July 2015
FICHTNER Consulting Engineers (India) Pvt. Ltd.
Chennai, India
4 X 660 MW Udangudi Supercritical Thermal Power Project (Stage – II & III)
Pre-feasibility Report
Table of Contents
1.0
Introduction ............................................................................................................................. 4
2.0
Project Background ................................................................................................................ 4
3.0
Project Status: Stage-I ............................................................................................................ 5
4.0
5.0
3.1
Land ............................................................................................................................... 5
3.2
Public hearing ................................................................................................................ 5
3.3
EIA Studies .................................................................................................................... 5
3.4
Coal linkage ................................................................................................................... 5
3.5
MoEF Clearance for the Thermal Power Plant .............................................................. 6
3.6
Cooling Water ................................................................................................................ 6
3.7
Coal jetty ........................................................................................................................ 6
3.8
Main Plant package ....................................................................................................... 6
3.9
Project Description ......................................................................................................... 6
3.10
Technical Details of the Power Plant (Stage-I: 2 X 660 MW) ........................................ 7
3.11
Site specific and Environment studies conducted ......................................................... 9
3.12
Government Orders, Approvals and Clearances obtained ............................................ 9
Project status: stage-II & III ................................................................................................ 10
4.1
Land ............................................................................................................................... 10
4.2
Construction power ........................................................................................................ 12
4.3
Construction water ......................................................................................................... 12
4.4
Source and Type of Fuel ................................................................................................ 13
Coal Jetty ............................................................................................................................... 14
5.1
Site Location .................................................................................................................. 14
5.2
Environmental and Ecological aspects .......................................................................... 15
5.3
Traffic ............................................................................................................................. 15
5.4
Vessel Size..................................................................................................................... 15
5.5
Facility Requirements ..................................................................................................... 16
5.6
Capital cost estimate ...................................................................................................... 18
6.0
Water ...................................................................................................................................... 19
7.0
Power Evacuation.................................................................................................................. 19
8.0
Canal Diversion ..................................................................................................................... 20
9.0
Salient Technical Features ................................................................................................... 20
9.1
Technology Selection ..................................................................................................... 20
9.2
Power Cycle ................................................................................................................... 21
Doc. No. FCE-1115125-ME-DOC-PFR-3000-001
PFR_4+x+660+MW+TPP_Rev+R0.docx
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9.3
Cooling Water System: .................................................................................................. 22
9.4
Coal Handling System:................................................................................................... 23
9.5
Ash Handling System: .................................................................................................... 23
9.6
Fuel oil system ............................................................................................................... 24
9.7
Compressed Air System ................................................................................................ 25
9.8
Fire Fighting System ...................................................................................................... 25
9.9
Other Plant auxiliaries .................................................................................................... 25
10.0 Environmental and Pollution Aspects ................................................................................. 25
10.1 Air Pollution .................................................................................................................... 25
10.2 Water Pollution ............................................................................................................... 27
10.3 Thermal Pollution ........................................................................................................... 28
10.4 Noise Pollution ............................................................................................................... 29
10.5 Pollution Monitoring and Surveillance Systems ............................................................. 29
10.6 Green Belt ...................................................................................................................... 29
11.0 Project Execution & Operational Set-up ............................................................................ 29
11.1 Project Schedule ............................................................................................................ 29
11.2 Method of Executing the Project .................................................................................... 30
11.3 O&M Staff ....................................................................................................................... 30
12.0 Project Cost Estimates and Cost of Generation ................................................................. 30
12.1 Project Cost Estimate .................................................................................................... 30
12.2 Cost of Generation ......................................................................................................... 31
13.0 Conclusion.............................................................................................................................. 32
List of Appendices
Appendix - 1
Location and Climatic Conditions
Appendix - 2
Typical Coal Analysis
Appendix - 3
Typical Fuel Oil Analysis
Appendix - 4
Typical Sea Water analysis
Appendix - 5
Demand and availability Analysis
List of Drawings
Comprehensive Plot plan for Stage I, II & III
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1.0
INTRODUCTION
Tamil Nadu Generation & Distribution corporation limited (TANGEDCO), a Company
incorporated in India under the Companies Act 1956, having its registered office at NPKRR
Maaligai, 144, Anna Salai, Chennai – 600 002 is a statutory body of erstwhile Tamil Nadu
Electricity Board (TNEB) formed under the Electricity Supply Act as a successor to the
erstwhile Electricity Department of the Government of Madras. Starting with the modest
installed capacity of 156 MW and annual gross generation plus purchase of 630 Million units
at the dawn of independence, TANGEDCO has grown by leaps and bounds with total
installed generation capacity of 13,373 MW as on March 2015. The Board’s gross generation
during the year 2014-15 was 84,454 Million units.
The Tamil Nadu state continues to be in the forefront in the field of rural electrification in the
country. The role of TANGEDCO in improving the economy of the states of Tamil Nadu by
extensive electrification of the villages, large scale energisation of agricultural pump sets and
extension of electricity services to poor/backward and downtrodden sections of the society, in
addition to extension of supply to large number of industries has been well recognized.
Already TANGEDCO is setting up a 1,320 MW (2x660 MW) coal based thermal power project
at Udangudi in Stage-I in Tuticorin District of Tamil Nadu and this project is established under
State Sector.
While the tender for Stage-I of 2 x 660 MW Coal based thermal Power Project is under
finalization, it is explored to study various options for increasing the generation capacity of the
State. As there are sufficient land to establish future units near 2 X 660 MW of Stage-I, it is
proposed to install four more units of 660 MW and the feasibility of installing these additional
units is studied. The GOTN has accorded in principle approval for establishing Stage-II & III
(each of 2X660 MW) vide G.O (4D) No.1, dated 03.02.2015.
TANGEDCO retained Fichtner Consulting Engineers (India) Pvt. Ltd. (FI), Chennai as their
Consultant / Engineer for the preparation of Pre-feasibility Report of the Project.
2.0
PROJECT BACKGROUND
Electricity consumption in India is increasing at a rate faster than over all energy supply.
From the Demand analysis and availability statement (enclosed as Appendix-5), the deficit
during the year 2015-16 is 1316MW. Keeping in view of huge power generation capacity
requirement to be added during 12th Plan (2012-17), a rapid capacity addition through large
scale thermal power development program is planned.
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In order to meet the growing demand of the state, Government of Tamil Nadu had decided to
develop coal based power projects. In this process, TANGEDCO initiated to establish
2 X 800 MW Supercritical Thermal Power Project near Udangudi Village Tuticorin District,
Tamil Nadu as a Joint Venture Project with BHEL, through a Joint Venture Company viz.
Udangudi Power Corporation Limited (UPCL). Subsequently TANGEDCO decided to proceed
with the project under State Sector and purchased all BHEL shares in Udangudi Power
Corporation Limited. Now TANGEDCO is preceding the project with the standardized unit
capacity to 2 x 660 MW. The project activities are under way.
TANGEDCO is studying the feasibility of developing additional 2 X 660 MW (3 rd Unit and
4th Units) as Stage-II and 2 X 660 MW (5th Unit and 6th Units) as Stage-III of the Udangudi
Project.
3.0
PROJECT STATUS: STAGE-I
3.1
Land
TN Government has alienated to the project about 305.31.1 hectares for industry and 1.23.5
hectares for cooling water corridor totaling 306.54.5 Hectares.
3.2
Public hearing
Public hearing for the Power plant including coal jetty and CRZ facilities has already been
completed on 07.02.2009.
3.3
EIA Studies
The Environmental Impact Assessment study for the above project (2X800 MW) was studied
by M/s. Bhagavathy Ana Labs, Hyderabad to satisfy the ambient and air quality standards.
3.4
Coal linkage
The application for the coal linkage was filed during December 2007 to Ministry Of Coal. As
on date no allocation is made by the Standing Linkage Committee (Long Term) for any of the
12th Plan projects in the country, hence TANGEDCO considered Imported coal from
Indonesia as the primary fuel for the proposed plant. The annual consumption of imported
coal with GCV of 5700 kcal/kg for 2 x 660 MW power plants is estimated as 3.87 Million
tonnes per annum (MTPA) considering PLF of 85% and TANGEDCO has entered agreement
with MMTC for the supply of imported coal from Indonesia. As per MOEF requirement,
calorific value of Imported coal will be minimum 6000 kcal/kg. TANGEDCO to approach
MOEF for necessary modification in the MOEF clearance.
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3.5
MoEF Clearance for the Thermal Power Plant
MoEF has accorded Environmental Clearance for the 2 X 800 MW Udangudi project on
14.10.2013. As the unit capacity has been subsequently standardized as 660 MW, MOEF is
being approached for the modification of EC suitably to the revised capacity of 2 X 660 MW.
3.6
Cooling Water
As the project is located 1.2 km away from the HTL of Bay of Bengal, it has been proposed to
utilize sea water as the source for the cooling water for condenser and auxiliary cooling water
requirement.
3.7
Coal jetty
This is an integrated power project with coal jetty component for coal logistics required for the
power plant. For bringing the coal to the power plant it is proposed to establish Captive coal
jetty at about 7.5 km offshore and the coal to be conveyed through the two streams of pipe
conveyor built on trestles at an elevation of + 6 to 8 meters from MSL. The MoEF has
accorded CRZ approval for the Coal Jetty, Pipe Conveyor System and Cooling Water intake
and outfall structures in MoEF communication letter dated 06.06.2011.
Tender has been floated for the Establishment of captive coal jetty with unloading facilities
and pipe conveyor.
3.8
Main Plant package
Necessary tendering for the project is under process. Since this project is State Sector
Project entire power will be taken by TANGEDCO / GOTN.
3.9
Project Description
The salient features of the 2 X 660 Stage-I project are furnished in the following table:
Site details
Location
Udangudi Village
District & State
Tuticorin District, Tamil Nadu State
Nature of the area
Fallow land
Latitude
08˚25’20.50” N to 08˚26’49.26” N
Longitude
78˚03’05.85” E to 78˚04’13.07”E
Altitude of the site
FGL: RL (+) 3.30 M above MSL
Connectivity
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Road
SH - 176 (0.5 km away).
Rail
12 Km from Tiruchendur.
Highway
ECR SH - 176 near project site
Airport
Vagaikulam 60 km from site.
Port
Tuticorin 45 Km from site.
Historical/Important Places
Archaeological/Historically Important Site
Nil
Sanctuaries / National Parks / Elephant /
Tiger Reserve / Migratory routes
Nil
Sensitive Areas
Gulf of Mannar (Approx. 45 km NE)
Sea
Bay of Bengal (1.2 km East)
Population details in the nearby Villages of Udangudi Project
Sl. No.
Village name
Population (In Nos.)
1.
Udangudi
19,738
2.
Kalangudi
9,680
3.
Sirktachi
499
4.
Nainarpathu
331
5.
J.J.Nagar
431
6.
Maravanvilai
235
7.
Thaikavoor
325
8.
Ammanpuram
747
Note: All villages are within 2 km from the boundary of project site.
3.10
Technical Details of the Power Plant (Stage-I: 2 X 660 MW)
Parameter
Fuel
Coal
Source of fuel
Imported Coal from Indonesia
Fuel Transportation
Through captive Jetty and from Jetty to plant
by pipe conveyors. Double stream with each
stream capacity of 3000 TPH Pipe conveyor
from the coal jetty.
Fuel requirement
Calorific Value
-
Imported Coal: 3.87 million TPA from
Indonesia through FSA with MMTC
HSD : 6500 m3 /year
HFO (Heavy Fuel – 35000 m3/year)
5700 Kcal/kg
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Average ash content in coal (% ARB)
6.62 % in Imported coal
Max Sulphur content in coal (%)
0.53 % in Imported coal
Major Project Requirements
Land Requirement
a) 754 Acres of Government Barren Land
(poramboke)
was
alienated
and
boundary marked
b) Acquisition of private lands:
Based on the Administrative approval
accorded by GOTN under TN Industrial
Purposes Act 10/99 and the awards
passed. The District Collector issued
notices to the Land owners under Clause
3(2) and 3(1) of the Act and finalized the
area of land to be acquired in
proceedings dated 29.09.2010. Gazette
notification has been issued and the
Collector has issued enter upon
permission on 07.08.2013 As per the
District
Collector’s
Letter
dated
27.12.2013, compensation amount for
the private lands has been deposited in
Collector & DRO’s Joint account No SB
33627772198,State Bank of India,
Udangudi. Issue of Award is under
process.
The
estimated
consumptive
water
requirement is 13500 m3/ hr (Including loss &
recovery)
Water Requirement
Source
Sea
Intake - Though Gravity pipe line at 2.05 km
from shore
Outfall-At 1.06 Km from shore through piping
system
Water transportation
In plant storage
24 hours storage
Raw water treatment
Sea water will be treated in clarifiers filters
and in desalination plant
Cooling water system
Re-circulating type cooling water system with
wet type Natural Draft Cooling Towers
PROJECT COST
Total Project Cost Including coal Jetty
Rs. 10423 Crores
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3.11
Site specific and Environment studies conducted
Marine EIA Report of plant, Coal Jetty,
Coal Conveyor and Cooling water
intake and outfall
Flood Protection and Area Drainage
study
1.
2.
3.12
Institution of Ocean Management, Anna
University, Chennai
Anna University, Chennai
3.
CRZ Demarcation map
Institute of Remote sensing, Anna
University, Chennai
4.
Modeling study for Intake and Outfall of
Cooling Water system
NIO, Goa
5.
Marine Environmental Survey
Annamalai University
6.
Modeling study for location of Coal
Jetty
NIO, Goa
7.
Detailed Project Report
Fichtner consulting engineers (India) private
limited.
8.
Sub-bottom profiling & Bathymetry
Report
Geo star Surveys, Navi Mumbai
9.
Marine Geo Technical Investigation
Infotech Surveys, Chennai
10.
EIA & EMP study for the plant
Bhagavathy Ana Labs, Hyderabad
11.
DPR for coal jetty
L&T Ramboll, Chennai
Government Orders, Approvals and Clearances obtained
a) Airport Authority of India NOC for Chimney ht. of 275 meters in letter dated 25.08.2008
b) SCZMA recommendation to NCZMA dated 12.10.2009 for power project.
c) SCZMA recommendation to NCZMA dated 26.11.2009 for infrastructure facilities in CRZ
d) In-principle approval of Tamil Nadu Maritime Board dated 06.07.2009 for setting
Udangudi Coal jetty
e) Declaration of Udangudi Minor Port by GoTN on 16.09.2010 and declaration of Port
Limits.
f)
305.31.1 Hectares alienated vide G.O No.81/dated 23.02.2010, for industrial area and
1.23.5 hectares for cooling water corridor, vide G.O No.20/dated 13.01.2011.
g) G.O for Land (Private land) – 281 Acres (114.75.5 Hectares) (G.O No.31/dated
22.3.2010)
h) MoEF approval of Environment Clearance for captive Udangudi Coal Jetty in MoEF letter
dated 06.06.2011.
i)
The Environmental Clearance for 2x800 MW Units for 100% imported coal has been
awarded by MOEF on 14.10.2013
j)
TANGEDCO has entered agreement dated 19.11.2012 with MMTC for supply of
4.5 Million Tonnes per annum imported coal from Indonesia
k) Tamilnadu pollution Control Board has accorded consent for the establishment of the
projects under section 25 of the Water Act in orders dated 10.03.2014.
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4.0
PROJECT STATUS: STAGE-II & III
The establishment of additional 2 x 660 MW Unit each in Stage-II and stage III is favoured on
the following factors.
i.
Suitable land availability for the main plant
ii.
Access to the site
iii. Construction power availability
iv. Construction water availability
v.
Coal Linkage & Transportation
vi. Sharing the Cooling water drawal and outfall system. Provision of separate Cooling
Water tower
vii. Chimney location and AAI approval
viii. Power evacuation
ix. Sharing Coal Handling system
x.
Sharing Ash Handling system
xi. Fuel oil system
xii. Compressed Air system
xiii. Firefighting system
xiv. Other plant auxiliaries
xv. Sufficient Green Belt provisions
Separate EIA & EMP study will be conducted for the Stage-II & III additional units.
4.1
Land
TANGEDCO has alienated Poromboke lands of 306.54.5 Hectares for stage-I, 114.54.5
hectares Patta land acquisition for cooling water, township and other plant facilities. As per
proceedings of DRO / Tuticorin, awards passed and releasing compensation to pattadarar is
under progress for Stage-I. Based on G.O (4D) energy (B1) department dated 03.02.2015,
land plan schedule was taken-up for Stage-II&III in the identified lands of 1546 acres on the
western side of stage-I in Udangudi, Kalankudiiruppu and Manadu Thandapath Villages.
However, as per the directions of RDO/Thiruchendur during field inspection, the western
peripheral boundary has been revised and the area as per the revised profile works out to
1369 acres for stage-II&III. The acquisition process of the land identified has been initiated.
Hence sufficient lands are available for Stage-II & III.
The additional two stages of each 2 x 660 MW (i.e.) Stage-II & Stage-III are earmarked on the
western side of the proposed Stage-I. Separate space will be considered for power block,
switch yard, chimney, cooling tower, cooling water inlet pipes from CWPH upto the plant, ash
dyke, ash water pipes, etc. In respect of the coal yard (stockpiles), sea water intake and
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outfall, power evacuation arrangements will be shared with the proposed system for
2 x 660 MW units of Stage-I.
Thus the land requirement is categorized as follows:
Description
2 x 660 MW
Stage-I
(Acres)
4 x 660 MW
Stage-II & III
(Acres)
1.
Main
Plant,
Transformer
Yard, Switch yard and FGD
65
111.8
2.
Coal Yard
65*
33*
3.
Cooling water system
43
54
4.
Fuel Oil system
4.2
4.2
5.
Water
system
including
Chlorination system
19.23
35.14
6.
Ash Dyke
120
240
7.
Administration building and
other Non-plant buildings
11.66
0.86
Shared with
2 x 660 MW
(Stage I)
8.
Miscellaneous
such
as
Corridor for CW piping, Ash
piping, Intake & outfall, Silo &
its utility building, Workshop,
Stores, Roads etc.,
198.1
343.0
Shared with
2 x 660 MW
(Stage I )
Sl.
No.
Remarks
* Stockpiles is
common for
three Stages
Area earmarked
for stage-II & III
in stage –I
boundary will be
considered as
greenbelt for
stage-I.
9.
Green Belt
927.8
10.
Township
130
TOTAL
2406
Note:
1. Necessary model studies will be carried out to ensure the location of intake and
outfall for the Stage-II and Stage–III and to finalize the corridor requirement.
2. Based on the boundary profile prepared from the Village maps, the comprehensive
Plot plan for stage I, II & III (Drg No.: 00-1115125-G-001) has been generated and
may not match with the break-up of land provided above.
Contour and
Topographical Survey is to be carried out to finalize the actual boundary.
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Access to the site:
The site is located on the Western side of Bay of Bengal. Distance between sea front to site is
about 1.2 km and site is close to the existing State Highways from Rameswaram to
Kanyakumari (SH-176). The nearest railway station is at Thiruchendur which is about 12 km
from the site. The nearest airport is at Vaagaikulam, which is about 60 km from Udangudi
site. The nearest sea port is Tuticorin port, which is about 45 km from the site.
4.2
Construction power
The construction power for the proposed project will be derived from 33 kV distribution lines
of TANGEDCO, envisaged at project site near plant boundary. Suitable 33 kV distribution
substation and HT ring main will be made at project site to feed various construction sites
through 415 V distribution substations.
4.3
Construction water
TWAD has already carried investigation works and finalized the scheme of supplying 15 lakhs
per day of water from its 20 MGD scheme. At later stage the proposal was dropped. However
the District Collector can accord permission for drawal of water less than 1 MGD in
consultation with PWD, W.R.O subject to clearance from Pollution Control Board and
availability of water. For industrial use necessary Government order has to be obtained
through the Regional Chief engineer concerned. As per G.O Ms No. 701, Public Works
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(WR2) department dated 18.10.1996; construction water can be purchased from private
agency.
4.4
Source and Type of Fuel
Coal Linkage
Coal linkage is yet to be finalized for stage-II and stage-III.
Imported Coal
Coal from International market could be procured from countries like Indonesia, South Africa,
Australia, China and other possible sources. With the dedicated jetty being envisaged at port
to unload coal for stage-I, imported coal will be considered as one of main fuel for operation
of the power project. Coal jetty constructed for stage-I will be used for the stage-II and III.
Calorific value of Imported coal will be about 5700 kcal/kg inline with stage-I. The requirement
of coal for various stages is as follows:
Imported coal requirement
Description
TPH
MTPA
Stage-I
520
3.87
Stage-II and III
1040
7.75
Coal required for 3 Stages
1560
11.62
Note: PLF considered as 85%.
In case of imported coal, coal handling, ash handling and operating cost will be less due to
less ash content and high calorific value of the fuel. However, the problems that could be
encountered are possibility of default on part of the fuel supplier, disruption in transportation
facilities, high transportation cost due to fluctuating petroleum prices and fluctuation of Rupee
Vs Dollar rate.
Blended Coal
Blending option will also be envisaged for Stage-II and III. Imported coal will be blended with
Indian coal in the ratio as indicated below. The calorific value of Imported coal is considered
as 5700 kcal/kg and for Indian coal as 3000 kcal/kg. TANGEDCO will approach MOEF for
necessary clearance to utilize Blended coal for power plant. The coal requirement for various
Blending coal options are as follows:
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Description
70% Imported Coal:30%
Indian Coal
50% Imported Coal:50%
Indian Coal
TPH
MTPA
TPH
MTPA
Stage-I
606
4.51
682
5.08
Stage-II and III
1212
9.02
1364
10.16
Coal required for 3 Stages
1818
13.53
2046
15.24
Coal linkage is yet to be finalized for stage-II and stage-III.
Coal Transportation
The coal will land at site from coal jetty direct by pipe conveyors.
5.0
COAL JETTY
Due to availability of sea front close to the project site, construction of a new coal jetty for
receiving coal for the proposed units (2 x 660 MW) at Udangudi and for the future expansion
Stage-II (2 X 660 MW) & Stage-III (2 x 660 MW) of the project will be proposed. GoTN has
approved the establishment of separate captive Coal Jetty near the project site for handling
coal for the project in G.O.Ms No.282 Dt.16.09.2010. The Tamil Nadu Maritime Board has
allocated 1.92 Hectares of coastal land for the establishment of Udangudi Coal Jetty on lease
basis.
MoEF has accorded Environmental Clearance for the establishment Coal Jetty in
notification dated 06.06.2011.
The salient features of the proposed Coal Jetty are as below:-
5.1
Site Location
The Udangudi Port has been declared as a Minor Port for the captive use of M/s. Udangudi
Power Corporation Limited, vide GOMs No.: 282 (Highways & Minor Ports (HF2) Department)
dated 16/09/2010. Further the following co-ordinates have been declared as the Port limits for
the Udangudi minor port:
PORT LIMITS – UDANGUDI MINOR PORT

Latitude 8° 26’ 21”N and Longitude 78° 04’ 45”E



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Power plant
JETTY Location
LAND
FALL POINT
POWER PLANT
LOCATION
Figure: Google Image of the proposed site for Udangudi Power Plant
5.2
Environmental and Ecological aspects
No significant environmental and ecological hotspots are reported around the proposed port
site. The port site falls under coastal regulation zone (CRZ) and since ports need water front,
constructing port is a permissible activity under CRZ.
5.3
Traffic
Based on the detailed coal requirement for the power plant, expected traffic to be handled at
the jetty is presented below.
Traffic at Udangudi Coal Jetty
Cargo Traffic (MTPA)
Description
100 % Imp. Coal
5.4
70% Imp. Coal + 50% Imp. Coal +
30% Ind. Coal
50% Ind. Coal
Traffic for 1320 power plant (Stage-I)
3.87
4.51
5.08
Traffic considering future expansion of
2640 MW Units (Stage-II & III)
7.74
9.02
10.16
Vessel Size
The design Vessel considered for the design of various port facilities are as shown in Table
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Recommended Size of Dry bulk carrier for Udangudi Jetty
Vessel Type
Design Vessel Size (DWT)
LOA (m)
Beam (m)
Draft (m)
80,000
240
37
14
Dry bulk Carrier (Coal)
5.5
Facility Requirements
The various facilities envisaged in the proposed jetty at Udangudi for unloading coal are
briefed below:
Navigational Channel Dimensions
Channel width
:
185 M
Channel depth
:
16.8 M
Manoeuvring area dimensions
:
480 M diameter and 16.8m depth
Berthing area
:
555 M X 25 m
Berthing Facilities
:
2 berths
Breakwaters
The Coal Jetty has been designed based on the Mathematical model studies done by NIO,
Goa.
Breakwaters are provided to give the berths maximum protection against the predominant
wave attack. Breakwater is provided in the North east direction so that the berths are safe
from the waves approaching from the SSW to E directions. The proposed breakwater is
located at (-) 18 m contour. The initial 178 m length of the breakwater is aligned in East west
directions which then takes a turn in NE direction, aligned parallel to the berth for a length of
555 m and finally turned towards North direction for a length of 182 m. Breakwater is
proposed to be constructed with concrete caisson with rock and concrete armour protection
on sea side. Top of the caisson will be used as the berthing area. Thus the proposed
breakwater at Udangudi measures about 915 m.
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Approach channel:
As the draft is available naturally at the location no dredging for the approach channel,
turning circle and manoeuvring area is not required.
Berths:
For the coal traffic of 10 MTPA, it has been arrived that 2 Nos. of berths with a total quay
length of 555 m is envisaged to handle the traffic (in 80,000 DWT vessel) within the
allowable berth-occupancy levels. As the expected Traffic is more than 10 MTPA for StageI, II & III, facility required at Berth needs to be studied and suitable facilities to meet the
Stage-I, II & III requirements to be provided. The required depth for safe berthing of the
vessel is available at about 7910 M from HTL. The location for the berth is marked by at the
0
0
co- ordinate: 8 23’ 50.38” N : 78 82’ 2.41”E.
Deck level:
As per the recommendations of IS: 4651 (Part V): 1980 deck elevation of + 7 M (CD) is
provided.
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Approach Trestles:
Carriage way (single lane)
:
4.25 m
Conveyor Trestle
:
5.10 m
Outfall pipe line corridor
:
5.00 m
Dredging:
No dredging is required as the draft is naturally available.
Cargo handling equipment:
The various coal handling equipment required at Udangudi to keep the berth occupancy
levels within allowable limits are summarized below:
Summary of Cargo Handling Equipment
Number of Equipment
Cargo
Equipment Type
Phase I
Addl. for Phase II
2
2
1 stream
1 stream
Continuous Grab type Unloader – 2000
TPH rate capacity
Coal
Conveyor with
capacity each
3000
TPH
rated
Cargo handling equipment needs to be studied with respect to expected traffic for Stage-I, II
& III.
Navigational Aids:
The proposed development involves creating channel breakwater. The turning and berthing
area is located in the natural water depth.
5.6
Capital cost estimate
The Capital Cost and the O&M Cost for the project for the two phases of development viz.,
Phase-I (6.20 MTPA) and Phase-II (10MTPA) are summarized as below
Capital and O&M costs for Udangudi project
Rs. (in Crores)
Equipment Type
Stage-I
(6.20 MTPA)
Stage-II &III
(10 MTPA)
Capital Cost
1264
112
Annual O&M Cost (per year)
62.33
84.12
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As the annual coal requirement is more than installed capacity of Jetty, the proposed coal
jetty to be designed based on coal demand for Stage-I, II & III.
6.0
WATER
The power station will have to depend upon seawater to meet the plant water requirement
due to non-availability of sweet water either from surface water sources or underground
sources on a sustained basis.
The quantity of water necessary for meeting requirement of DM plant, auxiliary cooling
circuit make-up, chilling plant make-up, ventilation system, service water, drinking water
requirements of plant etc., are proposed to be met by the Desalination plant.
It has been proposed to draw water from the sea, through seawater intake system. Sweet
water requirement for 2 x 660 MW power project for stage –I will be about 16 MLD
accounting limestone based FGD requirement. Sweet water requirement for Stages II & III
will be about 14.5 MLD each accounting limestone based FGD requirement.
The proposed water will be stored in desalinated water cum fire water storage tank located
inside the plant boundary. From the desalinated water cum fire water storage, water will be
pumped to meet the plant water requirements.
7.0
POWER EVACUATION
The total power generated from the generators will be 2640 MW (4X660 MW). Discounting
auxiliary power consumption of about 5.5 %, the power available for evacuation will be about
2494 MW.
Vide 37th meeting & 38th meeting of the standing committee on Power System Planning of
Southern Region, 765kV is proposed for evacuation of power from the proposed power
plant. 765 kV Tuticorin pooling substation is being executed by PGCIL in the vicinity of project
site. Hence, power generated in the power plant will be stepped up to 765 kV and evacuated
to PGCIL pooling substation. 2 numbers 765 kV line feeders are envisaged for the same.
Considering saline atmosphere prevailing at plant site, Gas Insulated Switchgear (GIS),
indoor type, is envisaged with one and half breaker or double bus scheme for the 765 kV
system. 765 kV GIS switchyard will be interconnected with 400 kV GIS Switchyard of Stage-I,
through 765/400 kV interconnecting transformers. This will facilitate power flow between
400 kV & 765 kV, for startup and part evacuation.
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During plant start-up, power required for station auxiliaries and unit auxiliaries will be drawn
from 765kV GIS switchyard. The power flow will be through Generator Transformer (GT) and
Unit Transformer (UT) and the Generator Circuit Breaker (GCB) scheme is envisaged.
For each unit, two numbers UTs are envisaged. UT will provide power to station auxiliaries
also. A standby transformer is envisaged common to 4 units, to provide backup, during
outage of any UT. Standby transformer will be energized from 400 kV GIS switchyard of
Stage-I power plant.
Auxiliary power supply is envisaged at three levels viz., 11 kV, 6.6 kV & 415 V, to provide
power for all the drives and equipment in the power plant. 11 kV Auxiliary supply for unit
auxiliaries will be derived from UT by tapping from the main run of the isolated phase busduct
and stepped down to 11 kV level to feed unit switchboards. 6.6 kV Auxiliary supply for plant
auxiliaries will be derived from 11/6.9 kV auxiliary transformers. 415 V supply will be derived
from 11 kV and 6.6 kV boards through service transformers.
To provide Emergency AC supply for safe shut down of the unit, in the event of total black
out, one DG set for each unit is envisaged with a common DG set as backup.
8.0
CANAL DIVERSION
The existing Elappanaikan canal will be diverted to the western boundary of Stage-I area. The
canal will be accommodated within land available for stage-I. The patrol road and compound
wall for stage-1 will be located adjacent to canal within land available for stage-I.
Upon finalization of the acquired land contour of stage-II&III, the Elappanaikan canal will be
diverted to western boundary of Stage-II & III. The canal will be accommodated within land
available for stage-II & III. The patrol road and compound wall for stage-II&III will be located
adjacent to canal within land available for stage-II & III.
9.0
SALIENT TECHNICAL FEATURES
The power station under progress is conceived to be comprising of two units of 660 MW
capacity each, with a total capacity of 1320 MW. The project will be established on the
basis of unitized system. Similarly for Stage-II & III Units, the same arrangement is
proposed. However, common systems will also be considered based on functional
requirements.
9.1
Technology Selection
The technology to be adopted in proposed 2 x 660 MW units is Super Critical Technology.
The additional four units of 2x660 MW are also designed in Super Critical Techn ology.
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9.2
Power Cycle
The basic configuration of the plant comprises two units of Steam Generator and Steam
Turbine with a gross power output at the generator terminals of 660 MW each at 100%
Turbine Maximum Continuous Rating (TMCR).
The Steam Generator will be of Single pass (Tower type) or two pass type using either
spiral wall (inclined) or vertical plain / rifled type water wall tubing. The steam generator
will be direct Pulverized coal fired, top supported, single reheat, radiant, dry bottom with
balanced draft and suitable for outdoor installations. The water wall of Steam Generator
will be suitable for variable pressure operation from Sub critical to Super critical pressure
range. The SG will be of once through type with supercritical steam parameters.
Steam parameter at the superheater outlet of Steam Generator will be about 250 ata,
565°C and at the reheater outlet, temperature will be about 595 °C at rated load. The
Steam Generators would be capable of maintaining main steam and hot reheat steam
temperatures of designed value between 60-100% MCR load. The Steam Generator would
be capable of operation with “the HP heaters out of service” condition and deliver steam to
meet Turbo-generator requirement at 100% MCR.
The capacity of Steam Generating units would ensure 4 to 5% margin over the steam
requirement of the Turbine at Valve Wide Open condition (VWO is 5% above TMCR) to
cater to the auxiliary steam requirement for soot blowing operation, fuel oil heating system
and normal de-rating of the Steam Generating unit after prolonged use.
The Steam Generators are coal fired with Heavy Fuel Oil firing(HFO) provision up to 30%
Boiler Maximum Continuous Rating (BMCR) for low load operation & flame stabilization
and High Speed Diesel (HSD) firing provision to a minimum of 7.5% BMCR as secondary
fuel and start-up fuel respectively.
The bowl mills are considered with adequate redundancies. While firing Worst coal at
100 % BMCR, N Nos. working with 1 No. standby Mills is envisaged and for design coal,
N Nos. working with 2 Nos. standby is provided. Minimum 2 Nos. of PA Fans each with
60% of BMCR capacity will be provided.
Draft system of each unit comprises of two (2) sets of ID fans and two (2) sets of FD fans
with each set rated for 60% of BMCR capacity. Each unit comprises of Two (2) nos. of
regenerative air pre heaters each with electric motor drive and manual cranking facility for
emergency. Each Air preheater will be designed for 60% of BMCR load. Each steam
generator unit will be provided with high efficiency Electro Static Precipitators (ESP).
Each coal fired unit consists of a supercritical boiler, a steam turbine with one HP, one IP
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and two/three LP stages, horizontally split casing and a feed water heating train with eight
feed water pre-heaters with drain coolers.
The Steam Turbine would be standard multi-stage, 3000 rpm, tandem compound, single
reheat, regenerative, condensing, multi-cylinder unit with eight (8) uncontrolled extractions
for regenerative feed water heating. At Turbine valve wide open (VWO) condition the
Turbo- generator set will be able to operate continuously at throttle steam flow of about
105% of turbine MCR condition.
The feed water heating plant includes four low pressure heaters, de-aerator and three high
pressure heaters. With this configuration a final feed water temperature of about 290 deg
C is maintained.
One or two low pressure feed water heaters will be located in the
condenser neck.
The condenser will be of single / two shell configuration, Single / Double pass surface
condenser capable of maintaining the required vacuum while condensing maximum steam
flow through LP turbine will be provided. The divided water box arrangement will be such
that it is possible to isolate one half of the condenser from cooling water inlet and outlet
sides.
2 x 50 % boiler feed pumps and booster pumps driven by drive turbine and 1 x 50% motor
driven boiler feed pump and booster pump are proposed. Condensate extraction pumps
will be of 3 x 50 % capacity motor driven units.
9.3
Cooling Water System:
Detailed Oceanographic studies have been carried out for stage-I by NIO, Goa and
location of intake / outfall for sea water system.
The exact location of intake and outfall has been finalized after conducting seawater
thermal recirculation study by NIO, Goa for the drawal of 21,000 m 3/hr of sea water and
disposal of warm sea water upto 13,500 m 3/hr after the circulation process.
As per MOEF, the following Intake / Discharge quantity are permitted for stage -I:
Intake / Discharge quantity m3/hr
Location
Distance from
shore
Depth
Intake point
13,790
8°25.548’ N
78°5.511’ E
2.05 km
(-) 5.4 m
Outfall point
8,890
8°25.95’ N
78°5.157’ E
1.06 km
(-) 5.0 m
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The quantity of Intake / discharge for the proposed 3rd, 4th, 5th and 6th units are given below.
Intake quantity
Discharge / Outfall
Quantity
Stage-II (2x660 MW Units)
13,790 m3/h
8,890 m3/h
Stage-III (2x660MW Units)
13,790 m3/h
8,890 m3/h
In the proposed stage-I, intake and outfall system are designed for 30000 m3/h and
22500m3/h respectively.
Intake system design includes piping from intake point and desilting basin. This
requirement will able to cater for 4x660MW i.e. Stage-I and Stage-II. 2 nos. of OD 2000mm
pipe are considered to cater the design requirement. For Stage-III, additional one no. of
OD 2000 pipe intake pipe will be laid along with the proposed piping. The same is to be
executed in Stage-I for ease of installation. Separate desilting basin along with pump
house will be envisaged for Stage-III.
Outfall system design includes pumping and piping requirement will able to cater for
4x660MW i.e. Stage-I and Stage-II. 1 no. of OD 2000mm pipe is considered to cater the
design requirement. Additional outfall pipe of one No. pipe of OD 1400 mm is envisaged to
cater Stage-III requirement. This pipe will be laid in Coal conveyor approach trestle. Total
width of the sea water outfall pipe corridor in approach trestle will be minimum 5m.
Necessary model studies will be carried out to ensure the location of intake and outfall for
the Stage-II and Stage–III.
9.4
Coal Handling System:
Additional two stock piles are envisaged adjacent to the stockpiles considered for Stage – I
units. Combined coal stockpile storage capacity will be 20 days for all 3 stages considering
imported coal with calorific value of 5700kcal/kg.
9.5
Ash Handling System:
Independent bottom ash and fly ash handling system will be provided for each Stages.
Common ash dyke will be proposed for disposal of the wet slurry generated from the
Stage-II & III. The fly ash will be disposed into ash dyke under emergency condition only.
As the fly ash is a precious commodity in the cement and brick products 100% ash
utilization could be easily achieved. The lands for the ash dyke have been identified and
acquisition is initiated.
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9.5.1
Ash Disposal
Slurry form of ash will be collected in slurry sump and will be disposed to ash dyke through
slurry pumps and pipes. Necessary land for ash dyke will be available for ash slurry
disposal.
Appropriate land will be kept reserved for ash dyke for the storage of ash. This plot will
accommodate ash in wet disposal of bottom ash for the period of about 25 years from the
commercial operation. For fly ash, efforts would be made for achieving 100% fly ash
utilization as per MOEF requirement. Ash pond will be sized considered worst coal
(50% : 50% blended coal).
The average annual ash generation from the proposed power plant (4x660), considering Best
coal - 100% Imported coal with ash content of 6.62% at 85% PLF is indicated below.
Description
Ash Generation
Total Ash generation for four units
69.09 TPH
Annual ash generated for four units
0.513 million TPA
Annual Bottom ash generated for four units
0.102 million TPA
Annual Fly ash generated for four units
0.411 million TPA
70:30 blended coal with ash content of 18.13% at 85% PLF is indicated below.
Description
Ash Generation
220.03 TPH
1.638 million TPA
0.327 million TPA
1.310 million TPA
50:50 blended coal with ash content of 26% at 85% PLF is indicated below.
Description
9.6
Ash Generation
354.71 TPH
2.641 million TPA
0.528 million TPA
2.113 million TPA
Fuel oil system
Separate fuel oil system is provided for Stage-II & III Units. The Fuel oil system provides
the facility for unloading, storage, supply and forwarding of Heavy Fuel Oil and High Speed
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Diesel Oil. HFO and HSD will be transported through Road tankers.
9.7
Compressed Air System
Compressed air system will be unitized for each stages. Compressed air will be required
for instrumentation applications and service utilities. Quality air would be required for
instrumentation and control of the power plant equipment including operation of various
pneumatically operated valves, actuators etc. Service air would be required for boiler
utilities like HEA purging, APH auxiliary air motor, atomizing air for HSD firing, etc as well
as general service air for cleaning purposes.
9.8
Fire Fighting System
Fire fighting system will be designed to provide system for each stage in conformity with
the recommendations of the Tariff Advisory Committee of Insurance Association of India.
Codes and Standards of National Fire Protection Association (NFPA), USA will be
followed, as applicable.
9.9
Other Plant auxiliaries
The other plant auxiliaries such as Ventilation & Air condition system, Mill reject system,
Effluent treatment systems, Cranes & Hoists, Elevators, Chemical laboratory etc., will be
designed to meet the plant requirement.
10.0
ENVIRONMENTAL AND POLLUTION ASPECTS
The environmental impact of the proposed power station covering the following aspects
and the measures for controlling the pollution within the values specified by Central / State
Pollution Control Board is briefly discussed below:

Air pollution

Water pollution

Thermal pollution

Noise pollution

Pollution monitoring and surveillance systems
Separate EIA & EMP study will be conducted for the Stage-II & III additional units.
10.1
Air Pollution
The Air pollutants from the proposed units are:

Sulphur dioxide in flue gas
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
Nitrogen oxides in flue gas

Carbon monoxide in flue gas.

Suspended Particulate Matter (SPM) in flue gas

Coal dust particles during storage/handling
Mitigation measures to limit the above air pollutions are to be investigated in detail through an
Environmental Impact Assessment Study to satisfy ambient air quality standards. Pollution
from mercury emission from imported coal and the impact on the environment are to be
studied.
10.1.1 SOx Emissions
Presently there is no legislation or norms for limiting the SO 2 emissions from coal based
thermal power plants. Changes as required by MOEF/GOI
notification shall be adhered
Currently sulphur dioxide levels are controlled by dispersing the pollutant to atmosphere
through a tall stack.
The minimum stack height to be maintained to keep the sulphur dioxide level in the ambient
within the air quality standards, as furnished below:
Stack Height Requirement for Sulphur Dioxide Control
Generation Capacity
Stack Height
H=14(Q)0.3
Less than 200 MW
200 MW & more to less than 500 MW
220 m
500 MW and more
275 m
Where,
Q
=
Sulphur dioxide emission rate in kg/h
H
=
Stack height in metres
With this, the stack height for the 660 MW units under consideration will be 275 metres.
Currently there is no requirement for installing any Flue Gas De-sulphuring (FGD) equipment.
However a provision is made in the plant layout for installing a FGD plant in future if required.
This also includes the water requirement for limestone based FGD.
10.1.2 NOx Emissions
Presently there are no limitations for NOx emissions from the coal fired power plants.
Changes as required by MOEF/GOI notification shall be adhered. However the power plant
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will use coal burners of proven, advanced design to reduce NO X production, and the boiler
furnace will be provided with over-fire air ports to further reduce NOX production.
10.1.3 CO Emissions
Carbon monoxide (CO) another kind of pollutant hardly exists in the modern power stations
as design of combustion control equipment and the furnace eliminates, almost completely the
possibility of incomplete combustion. The ground level concentration is expected to be within
the limit prescribed by Ministry of Environment and Forest.
10.1.4 Suspended Particulate Matter (SPM)
For thermal power stations, depending upon the requirement of local situation, such as
protected area, the State Pollution Control Boards and other implementing agencies under
the Environment (Protection) Act, 1986, may prescribe a limit of 50 mg/Nm3 for particulate
matter, irrespective of generation capacity of the plant.
The efficiency of the ESP will be more than 99.7%, which remove most of the fly ash from
the flue gas thereby limiting the quantity of fly ash emitted to atmosphere and the height
of the stack which disperses the pollutants has been fixed at 275m to meet the norms of
Central Pollution Control Board (CPCB).
10.1.5 Coal Dust Particles during Storage/Handling of coal
Dust generated in the Coal handling area would be minimized by providing suitable dust
suppression/extraction systems. For the coal stockyard, dust suppression system would be
provided. Boiler bunkers would be provided with ventilation system with bag filters to trap the
dust in the bunkers.
Using supercritical technology will result in reduced coal consumption and have an inherent
environmental benefit also. Reduced coal combustion for power generation will result in
lesser flue gas emissions to atmosphere. Apart from reduced GHG (CO2) emissions, the
project results in reduced SPM, SOx and NOx load on the environment.
10.2
Water Pollution
The wastewater treatment systems will be designed to collect and treat the various effluents
from the site, which are as follows:
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Effluents
Sources
Method of treatment
Disposal / Reuse
Oily wastes
Transformer yard,
TG hall floor wash
Fuel oil handling
area.
Chemical
contaminated
waste
DM Regeneration
waste
Tilted Plate interceptor,
oil skimmer to bring
down the treated water
oil level to less than
10 ppm.
Neutralization in a
neutralizing pit to bring
the pH to acceptable
levels.
No
treatment
is
necessary as the pH of
brine is higher than 7.
Treated effluents are
reused for horticulture
and removed oil is
taken
offsite
for
disposal.
Neutralized effluent is
taken to the CMB and
further
utilized
for
Horticulture etc.
Disposed to sea along
with CW return. The
TDS of water will be
diluted when mixed with
CW return which is
about 7 times more in
terms of flow rate.
Disposed to sea.
Desalination Plant
reject water (Brine)
Cooling
blow down
water
Condenser
and
auxiliary
Cooling
water
Run-off from coal
stock piles.
From coal stock
piles formed due to
rainfall.
Ash pond water
Bottom ash and fly
ash slurry disposal
system
Sewage
Canteen
Toilets
Rain Water
Storm water
drainage
10.3
Cold side blow down
hence
temperature
reduction
is
not
required.
Settling pond and clear
water
treated
in
effluent treatment plant
clarifier
Recovered water from
the ash pond will be
treated
using
clariflocculator.
Aerobic treatment.
No treatment required.
Treated water is reused
for
horticulture
or
stockpile
dust
suppression.
Clear water reused in
ash handling disposal
system or taken to sea
water outfall tank during
heavy rainfall.
Treated
sewage
is
reused for horticulture.
Reused
in
plant.
Excess water will be led
in channel outside the
plant boundary.
Thermal Pollution
According to the Central Pollution Control Board stipulation, the thermal power plants using
sea water should adopt suitable system to reduce water temperature at the final discharge
point so that the resultant rise in the temperature of receiving water does not exceed 5oC over
and above the ambient temperature of receiving water bodies.
For the proposed power plant, a closed cooling water system is adopted and in order to limit
the temperature of seawater discharged to sea, blow down from the plant is considered from
cold side of cooling water. Therefore the temperature of reject seawater at point of discharge
will be same as cold cooling water temperature.
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The exact location of intake and outfall will be finalized after conducting seawater
oceanographic and recirculation study for stage-II and III.
10.4
Noise Pollution
Several noise suppression and attenuation features will be designed into the plant for the
protection of personnel at all normally accessible locations within the plant boundary, both
inside and outside the different buildings, and for the protection of the inhabitants living in the
vicinity of the power plant.
10.5
Pollution Monitoring and Surveillance Systems
For thermal power stations, the Indian Emission Regulations stipulate the limits for particulate
matter emission and minimum stack heights to be maintained for keeping the sulphur dioxide
levels in the ambient within the air quality standards.
The characteristics of the effluent from the plant would be maintained so as to meet the
requirements of the State Pollution Control Board and the Minimum National Standards for
Thermal Power Plants stipulated by the Central Board for Prevention and Control of Water
Pollution.
10.6
Green Belt
The landscaping and ground cover system meant to enhance the appearance of selected
areas, enhance soil and slope stabilization of the land of the power plant, and assist in
reducing the noise level and fugitive dust generated by the plant.
As per the stipulations of MoEF, green belt will be provided all around the power plant
boundary by planting trees and the total green area including landscaping area will be 1/3rd
of the plant area.
11.0
PROJECT EXECUTION & OPERATIONAL SET-UP
11.1
Project Schedule
It proposed to take up the 1320 MW project in single stage, i.e. 2 x 660 MW in Stage -I.
The expansion to this project is taken now as second and third stage. As per international
practice, 2x660 MW unit is put into commercial operation in 42 months from the project
zero date.
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11.2
Method of Executing the Project
It is proposed to execute the Stage-I (2x660 MW units) under EPC contract and the
successful contractor will take overall responsibility for timely project execution, plant
performance and provide guarantees for the same. Concerning the Stage -II (2 x 660 MW)
units and Stage-III (2x 660 MW units), the projects will be executed through another EPC
contract. Since TANGEDCO is the proponent for executing Stage –II & III units, there will
not be any operational problem.
11.3
O&M Staff
The total personnel required for the O&M of the Stage-II & Stage-III will be about 500. Of
this, 250 will be unskilled workmen and quarters are not envisaged for them. This unskilled
workforce will be locally sourced. Housing colony for skilled O&M staff will be planned
separately.
As Separate Township has been proposed for the plant and GoTN has approved for the
acquisition of 81.91 acres for the township in Udangudi Village. There is possibility of
utilizing 50 acres adjacent to the stage I township from the identified lands for stage II &III
on north and east side. Hence the total land available for town ship will be 130 Acres.
12.0
PROJECT COST ESTIMATES AND COST OF GENERATION
12.1
Project Cost Estimate
The expected cost of the project for 4 × 660 MW is as follows.
Description
Amount (Rs. In Crores)
Land Cost and Site Development
204.155
Plant Cost including Taxes and Duties*
15043.632
Preliminary & Pre-Operative Expenses
675.542
Interest During Construction (IDC)
2758.249
Financial Charges
75.026
Total
18756.660
* Without considering Mega Power Status.
The above cost estimate is preliminary one, during DPR stage detail cost estimate will be
worked by obtaining budgetary offers from the Plant Equipment manufacturers.
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Approximate estimate for basic civil construction materials for each Stage (2x660 MW) is as
follows.
Description
Quantity
Sand
2,50,000 m3
Cement
1,80,000 MT
Reinforcement Steel
12.2
45,000 MT
Cost of Generation
The following fixed and variable costs are considered along with appropriate escalations.

The fixed costs include:
a) Interest on Loan
b) O&M expenses
c) Interest on Working Capital
d) Income tax
e) Depreciation

The variable cost covers the fuel cost (both primary and secondary).
The financial analysis covering the cost of generation, revenue from sale of power,
profitability and other parameters has been carried out with the above project cost and
CERC norms for cost of generation.
The salient parameters used in the analysis are;
Debt – Equity Ratio
:
80: 20
Interest on Loan & working Cap. :
13 % p.a. after COD
Repayment period
:
10 years
Loan grace period
:
2 years
Design useful life of the plant
:
25 years
Plant Load Factor
:
85% (As per CERC)
Auxiliary Power consumption
:
5.25% (As per CERC)
Plant Heat Rate
:
2248 kcal/kWh (As per CERC)
GCV of Imported Coal
:
5700 kcal/kg (As per Stage-I Tender)
GCV of Indian Coal
:
3000 kcal/kg (As per Stage-I Tender)
Imported Coal Cost
:
Rs. 6264.00 per MT
Indian Coal Cost
:
Rs. 2180.00 per MT
Port handling charges
:
Rs. 550.00 per MT
Escalation in fuel cost
:
1.7 % p.a.
Quantity of secondary fuel
:
0.5 ml / kWh
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Cost of secondary fuel
:
Rs. 47.40 per litre
Return on equity
:
16 % p.a. (As per CERC)
Depreciation
:
5.28 % p.a. for first 12 years (As per CERC)
2.05 % for above 12 years
Operation & Maintenance cost :
:
Rs. 19.54 lacs/ MW per year Escalation on O&M
6.32 % per year (As per CERC)
a) With imported coal, it is seen that the cost of generation works out to Rs. 5.10/ kWh in
the first year of operation and levelized tariff works out to Rs. 5.25/ kWh.
b) With blended coal, it is seen that the cost of generation works out to Rs. 5.07 / kWh in
the first year of operation and levelized tariff works out to Rs. 5.21 / kWh.
13.0
CONCLUSION
Considering the magnitude of the proposed power project capacity, availability of land,
selection of supercritical technology is an acceptable one for the proposed project.
Selection of environmental friendly supercritical technology will result in higher efficiency
leading to lower emission per kWh of power generated.
Also, Central Electricity Authority emphasize on the urgent need for introduction of large
scale thermal power plants in an environmentally friendly manner. In order to achieve the
twin objective of quick capacity addition and better efficiency, unit size of 660 MW
supercritical power plants is ideally suited for this purpose.
The
proposed
project
of providing additional four units of 660 MW is
considered
techno-economically viable and attractive from the investment point of view, provided
the following are established;

Environmental Clearance

Separate EIA & EMP study will be conducted for the Stage-II & III additional units

CRZ clearance.

Power Evacuation Plan.

Seawater intake and outfall comprehensively for Stage-I, Stage-II & III projects.

Coal Linkage

Jetty for Coal unloading at the port comprehensively for Stage-I, Stage-II & III
projects

Right of way for branching laying seawater intake, outfall piping and coal conveyors
from Stage-I project for Stage-II & III units.

Chimney Clearance from Airport Authority of India for Stage-II & III projects.
FICHTNER INDIA
Page : 32 of 32
Appendix - 1
Appendix – 1.0
1.0
Project Site
:
Udangudi Village, Thoothukudi District,
Tamil Nadu State, India
1.1
Latitude
:
08o 26’59.42”
1.2
Longitude
:
78o 04’12.106”
2.0
Approach to site
2.1
Nearest town
:
Thoothukudi
2.2
Nearest Railway Station
:
Thiruchendur (about 12 kms)
2.3
Nearest Sea Port
:
Thoothukudi (about 45kms)
2.4
Nearest Airport
:
Vaagaikulam (about 60 kms)
2.5
Access Roads
:
State Highway(176) Rameswaram to
Kanyakumari
3.0
Site Elevation
:
Finished Ground Level RL (+) 3.30m
above mean sea level.
4.0
Atmospheric Conditions
:
Hot, humid and corrosive - close to Sea
front
5.0
Seismic data
:
As per IS:1893-Latest
5.1
Zone
:
II
5.2
Intensity
:
As per IS:1893-Latest
6.0
Meteorological data
6.1
Ambient Air Temperature
Maximum dry bulb temperature
:
41°C
Minimum dry bulb temperature
:
17°C
Annual rainfall (Maximum)
:
718.2 mm
Annual rainfall (Minimum)
:
384.1 mm
Twenty four (24) hour-Max
:
138.2 mm
6.2
Rainfall
PFR_4 x 660 MW TPP_Rev R0
FICHTNER INDIA
Page : 1 of 2
Appendix 1
6.3
6.4
Wind velocity
Mean wind velocity
:
20.6 km/h
Wind direction
:
North, North east, North west, East
Relative humidity
Mean
Maximum
(Summer)
humidity
:
84%
Mean
Minimum
(Summer)
humidity
:
62%
Maximum humidity (Monsoon)
:
97%
Minimum humidity (Monsoon)
:
45%
7.0
Availability of Water
:
-
8.0
Tidal levels
Mean high water-Spring
Height in meters above datum
:
Mean high Water-Neap
CD + 0.99 m
CD + 0.71 m
Mean low Water-Neap
:
CD + 0.55 m
Mean low water-Spring
:
CD + 0.29m
Mean sea level
:
CD + 0.64 m
FICHTNER INDIA
Page : 2 of 2
Appendix 1
Appendix - 2
Appendix – 2.0
COAL PARAMETERS:
The steam generator will be designed for the following conditions:

Best Coal
:
100% Imported Coal

Design Coal
:
70% Imported & 30% Indian Coal on weighted average

Worst Coal
:
50% Imported & 50% Indian Coal on weighted average
The analysis of fuel is given below:
Coal Analysis
Coal Quality Parameters
Sl.No
Description
Indian Coal
1.
Higher Heating Value -As Fired
basis given Kcal/kg
3000 (GCV as received
basis)
2.
Total Moisture %
During rainy season 20%
(inherent + surface)
3.
HGI Abrasiveness expected YGP
Shale and sand stone content
Feed coal size
45 to 55 Average 52 50 to 70
mg/kg 20% max. up to 50
mm.
Imported Coal
5700 (as received
basis)
16.5%
51
INDIAN COAL PARTICULARS:
Particulars
Units
Parameters
A. Proximate Analysis
1.
Moisture
%
16.00
2.
Volatile Matter
%
19.00
3.
Ash
%
45.00
4.
Fixed carbon
%
20.00
%
100
Total
B. Ultimate Analysis, % ( As received)
1.
Carbon
%
27.70
2.
Hydrogen
%
2.60
3.
Nitrogen
%
0.52
4.
Oxygen
%
7.26
5.
Sulphur
%
0.50
6.
Ash
%
45.00
FICHTNER INDIA
Page : 1 of 3
Appendix 2
Particulars
Units
Parameters
7.
Moisture
%
16.00
8.
Carbonates
%
0.38
9.
Phosphorous
%
0.04
10.
Others
%
-
%
100.00
Total
C. Ash fusion temperature (deg C)
1.
Initial deformation, IT
deg C
1100
2.
Spherical, ST
deg C
1200
3.
Hemispherical, HT
deg C
1300
4.
Fluid, FT
deg C
-
D. Ash Analysis (%)
1.
SiO2
%
59.54
2.
Al2 O3
%
29.00
3.
Fe2O3
%
6.42
4.
CaO
%
1.50
5.
Na2O
%
0.08
6.
K2O
%
-
7.
TiO2
%
1.60
8.
SO3
%
0.25
9.
P2O5
%
0.51
10.
MgO
%
0.50
11.
Others
%
0.60
Total
100.00
E Resistivity of fly ash
Ohm - cm
1.73x 10^12
Units
Parameters
IMPORTED COAL
Particulars
A. Proximate Analysis (As received)
1.
Moisture
%
16.50
2.
Volatile Matter
%
36.45
3.
Ash
%
6.62
4.
Fixed carbon
%
40.43
5
Total
%
100.00
B. Ultimate Analysis, (%) (As received)
1.
Carbon
%
60.12
2.
Hydrogen
%
4.38
FICHTNER INDIA
Page : 2 of 3
Appendix 2
Particulars
Units
Parameters
3.
Nitrogen
%
1.48
4.
Oxygen
%
10.37
5.
Sulphur
%
0.53
6.
Ash
%
6.62
7.
Moisture
%
16.5
8.
Carbonates
%
-
9.
Phosphorous
%
-
10.
Others
%
-
%
100.00
Total
C. Ash fusion temperature (deg C)
1.
Initial deformation, IT
deg C
1230
2.
Spherical, ST
deg C
1270
3.
Hemispherical, HT
deg C
1320
4.
Fluid, FT
deg C
-
D. Ash Analysis (%)
1.
SiO2
%
36.00
2.
Al2 O3
%
13.90
3.
Fe2O3
%
14.80
4.
CaO
%
12.70
5.
Na2O
%
0.70
6.
K2O
%
1.70
7.
TiO2
%
0.80
8.
SO3
%
10.60
9
P2O5
%
0.20
10.
MgO
%
8.60
11.
Others
%
-
12.
Total
%
100.00
FICHTNER INDIA
Page : 3 of 3
Appendix 2
Appendix – 3
Appendix – 3.0
Specification of Heavy Fuel Oil (HFO)
Flash point (°C) min. 66 K.
Viscosity in Centistokes @ 50°C max. 370
Ash by wt. % 0.1
Water content by volume % max 1
Sediment by weight % max 0.25
Total Sulphur by weight % max 4.5
Gross calorific value, Kcal/kg 10800
Specification of HSD Oil:
Specific gravity @ 15° C 0.8348
Gross calorific value, Kcal/kg 10400
Pour point (°C) max. 12
Flash point (°C) min. 66
Sulphur % (T) max. 0.5 K
Viscosity in Centistokes @ 50°C max. 7.5
Ash by wt. % 0.01
Water & sediment Vol. Max. % 0.25
FICHTNER INDIA
Page : 1 of 1
Appendix 3
APPENDIX - 4
TYPICAL SEAWATER ANALYSIS
SAMPLE IDENTIFIED AS : SEA WATER
SAMPLING METHOD
SAMPLE DESC RIPTION
SAMPLE CTY.
SAMPLE CODE
MARK
COLLECTED ON
TEST START DATE
TEST END DATE
NA
SEAWAT ER
20L
N _08+24,00 1,E-78+04,088f09 .09 .06
TOP LAYER
09/0912006
13/09/2006
2710912006
Ii
as
Page 1 of 20
iii
I
NOTE: BOL: Below Detection Li mit.
DL : Detection Limit
Page 2 of 20
Appendix – 5
Demand Analysis and Availability
Appendix – 5.0
7
9(5+6+87)
8
2012-13
10364
450
299
10515
8085
382
254
0
8213
2013-14
10515
1594
225
11884
8213
1318
137
1500
10894
13501
2014-15
11884
2222
734
13373
10894
1848
623
-776
11342
14581
2015-16
13373
466
32
13807
11342
394
27
2723
14432
2016-17
13807
699
32
14474
14432
594
27
383
2017-18
14474
987
95
15367
15382
839
80
2018-19
15367
2967
0
18333
15641
2522
2019-20
18333
4540
1785
21088
18162
2020-21
21088
2620
0
23708
2021-22
23708
2640
0
26348
13
Energy Surplus/ Deficit
(MU)
12
Nett Annual Energy
Availability (MU)
11
NETT SHORTAGE
10
Correction for over
projection
Availability at the end of
the year (MW)
Case I Bidding (inclusive of
losses) (MW)
Reduction in availability
due to unit retirement/
PPA expiry (MW)
Availability during the year
(MW)
6
Annual energy Availability
from Firm Sources (MU)
5
Annual Energy
Requirement(MU)
4(1+2-3)
Availability at the
beginning of the year
(MW)
Installed capacity at the
end of the year (MW)
Reduction in capacity due
to unit retirement/ PPA
expiry (MW)
3
Deficit/ Surplus (MW)
2
Projected demand (MW)
1
Capacity addition during
the year (MW)
Year
Installed capacity at the
beginning of the year
(MW)
Demand Analysis and Availability
14
95247
81117
-3239
102867
84454
-18413
15748
-1316
111096
107461
-3635
15382
17007
-1625
119984
114536
-5448
-500
15641
18368
-2727
129582
116462
-13120
0
0
18162
19837
-1675
139949
135238
-4711
3434
1517
0
20079
21424
-1345
151145
149510
-1635
20079
2227
0
0
22306
23138
-832
163237
166092
2856
22306
544
0
0
22850
24989
-2139
176296
170143
-6153
FICHTNER INDIA
Page : 1 of 1
Appendix 5
TAMIL NADU GENERATION AND
DISTRIBUTION CORPORATION LTD

Annexure-PFR - Environment Clearance

Transcription

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