(A Subsidiary of TNEB Limited)

Transcription

1 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 ME-DOC-PFR , Rev R0 ] July 2015 FICHTNER Consulting Engineers (India) Pvt. Ltd. Chennai, India

2 Table of Contents 1.0 Introduction Project Background Project Status: Stage-I Land Public hearing EIA Studies Coal linkage MoEF Clearance for the Thermal Power Plant Cooling Water Coal jetty Main Plant package Project Description Technical Details of the Power Plant (Stage-I: 2 X 660 MW) Site specific and Environment studies conducted Government Orders, Approvals and Clearances obtained Project status: stage-ii & III Land Construction power Construction water Source and Type of Fuel Coal Jetty Site Location Environmental and Ecological aspects Traffic Vessel Size Facility Requirements Capital cost estimate Water Power Evacuation Canal Diversion Salient Technical Features Technology Selection Power Cycle Doc. No. FCE ME-DOC-PFR FICHTNER INDIA Page : 2 of 32

3 9.3 Cooling Water System: Coal Handling System: Ash Handling System: Fuel oil system Compressed Air System Fire Fighting System Other Plant auxiliaries Environmental and Pollution Aspects Air Pollution Water Pollution Thermal Pollution Noise Pollution Pollution Monitoring and Surveillance Systems Green Belt Project Execution & Operational Set-up Project Schedule Method of Executing the Project O&M Staff Project Cost Estimates and Cost of Generation Project Cost Estimate Cost of Generation Conclusion List of Appendices Appendix - 1 Appendix - 2 Appendix - 3 Appendix - 4 Appendix - 5 Location and Climatic Conditions Typical Coal Analysis Typical Fuel Oil Analysis Typical Sea Water analysis Demand and availability Analysis List of Drawings Comprehensive Plot plan for Stage I, II & III Doc. No. FCE ME-DOC-PFR FICHTNER INDIA Page : 3 of 32

4 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 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 The Board s gross generation during the year 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 TANGEDCO retained Fichtner Consulting Engineers (India) Pvt. Ltd. (FI), Chennai as their Consultant / Engineer for the preparation of 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 is 1316MW. Keeping in view of huge power generation capacity requirement to be added during 12 th Plan ( ), a rapid capacity addition through large scale thermal power development program is planned. Doc. No. FCE ME-DOC-PFR FICHTNER INDIA Page : 4 of 32

5 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 4 th Units) as Stage-II and 2 X 660 MW (5 th Unit and 6 th 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 hectares for industry and hectares for cooling water corridor totaling Hectares. 3.2 Public hearing Public hearing for the Power plant including coal jetty and CRZ facilities has already been completed on 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 12 th 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. Doc. No. FCE ME-DOC-PFR FICHTNER INDIA Page : 5 of 32

6 3.5 MoEF Clearance for the Thermal Power Plant MoEF has accorded Environmental Clearance for the 2 X 800 MW Udangudi project on 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 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 District & State Nature of the area Latitude Longitude Altitude of the site Udangudi Village Tuticorin District, Tamil Nadu State Fallow land N to N E to E FGL: RL (+) 3.30 M above MSL Connectivity Doc. No. FCE ME-DOC-PFR FICHTNER INDIA Page : 6 of 32

7 Road Rail Highway Airport Port SH (0.5 km away). 12 Km from Tiruchendur. ECR SH near project site Vagaikulam 60 km from site. Tuticorin 45 Km from site. Historical/Important Places Archaeological/Historically Important Site Sanctuaries / National Parks / Elephant / Tiger Reserve / Migratory routes Sensitive Areas Sea Nil Nil Gulf of Mannar (Approx. 45 km NE) 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, Kalangudi 9, Sirktachi Nainarpathu J.J.Nagar Maravanvilai Thaikavoor Ammanpuram 747 Note: All villages are within 2 km from the boundary of project site Technical Details of the Power Plant (Stage-I: 2 X 660 MW) Parameter Fuel Source of fuel Fuel Transportation Fuel requirement Calorific Value Coal Imported Coal from Indonesia 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. - Imported Coal: 3.87 million TPA from Indonesia through FSA with MMTC - HSD : 6500 m 3 /year - HFO (Heavy Fuel m 3 /year) 5700 Kcal/kg Doc. No. FCE ME-DOC-PFR FICHTNER INDIA Page : 7 of 32

8 Average ash content in coal (% ARB) Max Sulphur content in coal (%) Major Project Requirements Land Requirement Water Requirement Source Water transportation In plant storage Raw water treatment Cooling water system 6.62 % in Imported coal 0.53 % in Imported coal 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 Gazette notification has been issued and the Collector has issued enter upon permission on As per the District Collector s Letter dated , compensation amount for the private lands has been deposited in Collector & DRO s Joint account No SB ,State Bank of India, Udangudi. Issue of Award is under process. The estimated consumptive water requirement is m 3 / hr (Including loss & recovery) Sea Intake - Though Gravity pipe line at 2.05 km from shore Outfall-At 1.06 Km from shore through piping system 24 hours storage Sea water will be treated in clarifiers filters and in desalination plant Re-circulating type cooling water system with wet type Natural Draft Cooling Towers PROJECT COST Total Project Cost Including coal Jetty Rs Crores Doc. No. FCE ME-DOC-PFR FICHTNER INDIA Page : 8 of 32

9 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 3. CRZ Demarcation map 4. Modeling study for Intake and Outfall of Cooling Water system Institution of Ocean Management, Anna University, Chennai Anna University, Chennai Institute of Remote sensing, Anna University, Chennai NIO, Goa 5. Marine Environmental Survey Annamalai University 6. Modeling study for location of Coal Jetty 7. Detailed Project Report 8. Sub-bottom profiling & Bathymetry Report NIO, Goa Fichtner consulting engineers (India) private limited. 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 3.12 Government Orders, Approvals and Clearances obtained a) Airport Authority of India NOC for Chimney ht. of 275 meters in letter dated b) SCZMA recommendation to NCZMA dated for power project. c) SCZMA recommendation to NCZMA dated for infrastructure facilities in CRZ d) In-principle approval of Tamil Nadu Maritime Board dated for setting Udangudi Coal jetty e) Declaration of Udangudi Minor Port by GoTN on and declaration of Port Limits. f) Hectares alienated vide G.O No.81/dated , for industrial area and hectares for cooling water corridor, vide G.O No.20/dated g) G.O for Land (Private land) 281 Acres ( Hectares) (G.O No.31/dated ) h) MoEF approval of Environment Clearance for captive Udangudi Coal Jetty in MoEF letter dated i) The Environmental Clearance for 2x800 MW Units for 100% imported coal has been awarded by MOEF on j) TANGEDCO has entered agreement dated 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 Doc. No. FCE ME-DOC-PFR FICHTNER INDIA Page : 9 of 32

10 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 Hectares for stage-i, 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 , 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 Doc. No. FCE ME-DOC-PFR FICHTNER INDIA Page : 10 of 32

11 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: Sl. No. 1. Description Main Plant, Transformer Yard, Switch yard and FGD 2 x 660 MW Stage-I (Acres) 4 x 660 MW Stage-II & III (Acres) Coal Yard 65* 33* Remarks * Stockpiles is common for three Stages 3. Cooling water system Fuel Oil system Water system including Chlorination system Ash Dyke Administration building and other Non-plant buildings Miscellaneous such as Corridor for CW piping, Ash piping, Intake & outfall, Silo & its utility building, Workshop, Stores, Roads etc., Green Belt Township 130 Shared with 2 x 660 MW (Stage I) Shared with 2 x 660 MW (Stage I ) Area earmarked for stage-ii & III in stage I boundary will be considered as greenbelt for stage-i. 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.: 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. Doc. No. FCE ME-DOC-PFR FICHTNER INDIA Page : 11 of 32

12 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 Doc. No. FCE ME-DOC-PFR FICHTNER INDIA Page : 12 of 32

13 (WR2) department dated ; 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 Stage-II and III Coal required for 3 Stages 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: Doc. No. FCE ME-DOC-PFR FICHTNER INDIA Page : 13 of 32

14 Description 70% Imported Coal:30% Indian Coal 50% Imported Coal:50% Indian Coal TPH MTPA TPH MTPA Stage-I Stage-II and III Coal required for 3 Stages 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 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 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 N and Longitude E Latitude N and Longitude E Latitude N and Longitude E Latitude N and Longitude E Doc. No. FCE ME-DOC-PFR FICHTNER INDIA Page : 14 of 32

15 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 Description 100 % Imp. Coal Cargo Traffic (MTPA) 70% Imp. Coal + 30% Ind. Coal 50% Imp. Coal + 50% Ind. Coal Traffic for 1320 power plant (Stage-I) Traffic considering future expansion of 2640 MW Units (Stage-II & III) Vessel Size The design Vessel considered for the design of various port facilities are as shown in Table Doc. No. FCE ME-DOC-PFR FICHTNER INDIA Page : 15 of 32

16 Recommended Size of Dry bulk carrier for Udangudi Jetty Vessel Type Design Vessel Size (DWT) LOA (m) Beam (m) Draft (m) Dry bulk Carrier (Coal) 80, 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. Doc. No. FCE ME-DOC-PFR FICHTNER INDIA Page : 16 of 32

17 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 Stage- I, 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 co- ordinate: N : E. Deck level: As per the recommendations of IS: 4651 (Part V): 1980 deck elevation of + 7 M (CD) is provided. Doc. No. FCE ME-DOC-PFR FICHTNER INDIA Page : 17 of 32

18 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 Cargo Coal Equipment Type Continuous Grab type Unloader 2000 TPH rate capacity Conveyor with 3000 TPH rated capacity each Number of Equipment Phase I Addl. for Phase II stream 1 stream 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 Equipment Type Stage-I (6.20 MTPA) Rs. (in Crores) Stage-II &III (10 MTPA) Capital Cost Annual O&M Cost (per year) Doc. No. FCE ME-DOC-PFR FICHTNER INDIA Page : 18 of 32

19 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 37 th meeting & 38 th 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. Doc. No. FCE ME-DOC-PFR FICHTNER INDIA Page : 19 of 32

20 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 Technology. Doc. No. FCE ME-DOC-PFR FICHTNER INDIA Page : 20 of 32

21 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 % 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 Doc. No. FCE ME-DOC-PFR FICHTNER INDIA Page : 21 of 32

22 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 m 3 /hr Intake point 13,790 Outfall point 8,890 Location N E N E Distance from shore Depth 2.05 km (-) 5.4 m 1.06 km (-) 5.0 m Doc. No. FCE ME-DOC-PFR FICHTNER INDIA Page : 22 of 32

23 The quantity of Intake / discharge for the proposed 3 rd, 4 th, 5 th and 6 th units are given below. Intake quantity Discharge / Outfall Quantity Stage-II (2x660 MW Units) 13,790 m 3 /h 8,890 m 3 /h Stage-III (2x660MW Units) 13,790 m 3 /h 8,890 m 3 /h In the proposed stage-i, intake and outfall system are designed for m 3 /h and 22500m 3 /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. Doc. No. FCE ME-DOC-PFR FICHTNER INDIA Page : 23 of 32

24 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 Total Ash generation for four units Annual ash generated for four units Annual Bottom ash generated for four units Annual Fly ash generated for four units Ash Generation TPH million TPA million TPA million TPA 70:30 blended coal with ash content of 18.13% at 85% PLF is indicated below. Description Total Ash generation for four units Annual ash generated for four units Annual Bottom ash generated for four units Annual Fly ash generated for four units Ash Generation TPH million TPA million TPA million TPA 50:50 blended coal with ash content of 26% at 85% PLF is indicated below. Description Total Ash generation for four units Annual ash generated for four units Annual Bottom ash generated for four units Annual Fly ash generated for four units Ash Generation TPH million TPA million TPA million TPA 9.6 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 Doc. No. FCE ME-DOC-PFR FICHTNER INDIA Page : 24 of 32

25 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 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 Air Pollution The Air pollutants from the proposed units are: Sulphur dioxide in flue gas Doc. No. FCE ME-DOC-PFR FICHTNER INDIA Page : 25 of 32

26 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 SO x Emissions Presently there is no legislation or norms for limiting the SO2 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 Less than 200 MW H=14(Q) 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 NO x 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 Doc. No. FCE ME-DOC-PFR FICHTNER INDIA Page : 26 of 32

27 will use coal burners of proven, advanced design to reduce NOX production, and the boiler furnace will be provided with over-fire air ports to further reduce NOX production 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 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/nm 3 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) 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 Water Pollution The wastewater treatment systems will be designed to collect and treat the various effluents from the site, which are as follows: Doc. No. FCE ME-DOC-PFR FICHTNER INDIA Page : 27 of 32

28 Effluents Sources Method of treatment Disposal / Reuse Oily wastes Chemical contaminated waste Cooling blow down water Run-off from coal stock piles. Ash pond water Sewage Storm water drainage Transformer yard, TG hall floor wash Fuel oil handling area. DM Regeneration waste Desalination Plant reject water (Brine) 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. Condenser and Cold side blow down auxiliary Cooling hence temperature water reduction is not required. From coal stock Settling pond and clear Treated water is reused piles formed due to water treated in for horticulture or rainfall. effluent treatment plant stockpile dust clarifier suppression. Bottom ash and fly Recovered water from Clear water reused in ash slurry disposal the ash pond will be ash handling disposal system treated using system or taken to sea clariflocculator. water outfall tank during heavy rainfall. Canteen Aerobic treatment. Treated sewage is Toilets reused for horticulture. Rain Water No treatment required. 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 5 o C 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. Doc. No. FCE ME-DOC-PFR FICHTNER INDIA Page : 28 of 32

29 The exact location of intake and outfall will be finalized after conducting seawater oceanographic and recirculation study for stage-ii and III 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 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 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 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. Doc. No. FCE ME-DOC-PFR FICHTNER INDIA Page : 29 of 32

30 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 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 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 PROJECT COST ESTIMATES AND COST OF GENERATION 12.1 Project Cost Estimate The expected cost of the project for MW is as follows. Description Amount (Rs. In Crores) Land Cost and Site Development Plant Cost including Taxes and Duties* Preliminary & Pre-Operative Expenses Interest During Construction (IDC) Financial Charges Total * 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. Doc. No. FCE ME-DOC-PFR FICHTNER INDIA Page : 30 of 32

31 Approximate estimate for basic civil construction materials for each Stage (2x660 MW) is as follows. Description Quantity Sand 2,50,000 m 3 Cement Reinforcement Steel 1,80,000 MT 45,000 MT 12.2 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 per MT Indian Coal Cost : Rs per MT Port handling charges : Rs per MT Escalation in fuel cost : 1.7 % p.a. Quantity of secondary fuel : 0.5 ml / kwh Doc. No. FCE ME-DOC-PFR FICHTNER INDIA Page : 31 of 32

32 Cost of secondary fuel : Rs 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 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 / kwh in the first year of operation and levelized tariff works out to Rs / kwh 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. Doc. No. FCE ME-DOC-PFR FICHTNER INDIA Page : 32 of 32

33 Appendix - 1 Location and Climatic Conditions

34 Appendix 1.0 Location and Climatic Conditions 1.0 Project Site : Udangudi Village, Thoothukudi District, Tamil Nadu State, India 1.1 Latitude : 08 o Longitude : 78 o 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 6.2 Rainfall Annual rainfall (Maximum) : mm Annual rainfall (Minimum) : mm Twenty four (24) hour-max : mm Doc. No. FCE ME-DOC-PFR FICHTNER INDIA Page : 1 of 2 PFR_4 x 660 MW TPP_Rev R0 Appendix 1

35 6.3 Wind velocity Mean wind velocity : 20.6 km/h Wind direction : North, North east, North west, East 6.4 Relative humidity Mean Maximum humidity (Summer) Mean Minimum humidity (Summer) : 84% : 62% Maximum humidity (Monsoon) : 97% Minimum humidity (Monsoon) : 45% 7.0 Availability of Water : Tidal levels Height in meters above datum Mean high water-spring : CD m Mean high Water-Neap CD m Mean low Water-Neap : CD m Mean low water-spring : CD m Mean sea level : CD m Doc. No. FCE ME-DOC-PFR FICHTNER INDIA Page : 2 of 2 PFR_4 x 660 MW TPP_Rev R0 Appendix 1

36 Appendix - 2 Typical Coal Analysis

37 Appendix 2.0 Typical Coal Analysis 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 Imported Coal 1. Higher Heating Value -As Fired basis given Kcal/kg 3000 (GCV as received basis) 5700 (as received basis) 2. Total Moisture % During rainy season 20% (inherent + surface) 16.5% 3. HGI Abrasiveness expected YGP Shale and sand stone content Feed coal size 45 to 55 Average to 70 mg/kg 20% max. up to 50 mm. 51 INDIAN COAL PARTICULARS: Particulars Units Parameters A. Proximate Analysis 1. Moisture % Volatile Matter % Ash % Fixed carbon % Total % 100 B. Ultimate Analysis, % ( As received) 1. Carbon % Hydrogen % Nitrogen % Oxygen % Sulphur % Ash % Doc. No. FCE ME-DOC-PFR FICHTNER INDIA Page : 1 of 3 PFR_4 x 660 MW TPP_Rev R0 Appendix 2

38 Particulars Units Parameters 7. Moisture % Carbonates % Phosphorous % Others % - Total % C. Ash fusion temperature (deg C) 1. Initial deformation, IT deg C Spherical, ST deg C Hemispherical, HT deg C Fluid, FT deg C - D. Ash Analysis (%) 1. SiO2 % Al2 O3 % Fe2O3 % CaO % Na2O % K2O % - 7. TiO2 % SO3 % P2O5 % MgO % Others % 0.60 Total E Resistivity of fly ash Ohm - cm 1.73x 10^12 IMPORTED COAL Particulars Units Parameters A. Proximate Analysis (As received) 1. Moisture % Volatile Matter % Ash % Fixed carbon % Total % B. Ultimate Analysis, (%) (As received) 1. Carbon % Hydrogen % 4.38 Doc. No. FCE ME-DOC-PFR FICHTNER INDIA Page : 2 of 3 PFR_4 x 660 MW TPP_Rev R0 Appendix 2

39 Particulars Units Parameters 3. Nitrogen % Oxygen % Sulphur % Ash % Moisture % Carbonates % - 9. Phosphorous % Others % - Total % C. Ash fusion temperature (deg C) 1. Initial deformation, IT deg C Spherical, ST deg C Hemispherical, HT deg C Fluid, FT deg C - D. Ash Analysis (%) 1. SiO2 % Al2 O3 % Fe2O3 % CaO % Na2O % K2O % TiO2 % SO3 % P2O5 % MgO % Others % Total % Doc. No. FCE ME-DOC-PFR FICHTNER INDIA Page : 3 of 3 PFR_4 x 660 MW TPP_Rev R0 Appendix 2

40 Appendix 3 Typical Fuel Oil Analysis

41 Appendix 3.0 Typical Fuel Oil Analysis Specification of Heavy Fuel Oil (HFO) Flash point ( C) min. 66 K. Viscosity in 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 Specification of HSD Oil: Specific 15 C Gross calorific value, Kcal/kg Pour point ( C) max. 12 Flash point ( C) min. 66 Sulphur % (T) max. 0.5 K Viscosity in 50 C max. 7.5 Ash by wt. % 0.01 Water & sediment Vol. Max. % 0.25 Doc. No. FCE ME-DOC-PFR FICHTNER INDIA Page : 1 of 1 PFR_4 x 660 MW TPP_Rev R0 Appendix 3

42 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+04,088f TOP LAYER 09/ /09/ Ii as Page 1 of 20

43 I iii NOTE: BOL: Below Detection Limit. DL : Detection Limit Page 2 of 20