M/s CHENNAI POWER GENERATION PRIVATE LIMITED...

FEASIBILITY REPORT

eGateway India Private Limited

M/s CHENNAI POWER GENERATION PRIVATE LIMITED CHENNAI

1050 MW (2 x 525 MW) MW COMBINED CYCLE POWER PROJECT AT DISTRICT THIRUVALLUR, TAMIL NADU STATE

Feasibility Report for 1050 MW ( 2 x 525 MW) Combined Cycle Power Project of M/S. Chennai Power

Generation Limited at Kattupalli and Kalanji villages at Ponneri Taluk, Thiruvallur district, Tamil Nadu

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CONTENTS

CHAPTE

R NO. PARTICULARS PAGE NO

FEASIBILITY REPORT

I EXECUTIVE SUMMARY 3

II INTRODUCTION OF THE PROJECT / BACKGROUND

INFORMATION 5

III PROJECT DESCRIPTION 9

IV SITE ANALYSIS 31

V PLANNING BRIEF 34

VI PROPOSED INFRASTRUCTURE 35

VII REHABILITATION & RESETTLEMENT (R&R) PLAN 36

VIII PROJECT SCHEDULE & COST ESTIMATES 37

IX ANALYSIS OF PROPOSAL (FINAL RECOMMENDATIONS) 38

LIST OF FIGURES

FIGURE

NO. PARTICULARS PAGE NO

3.1 LOCATION PLAN 10

3.2 SATELLITE IMAGE SHOWING PROJECT BOUNDARY

WITH CO-ORDINATES 11

3.3 PLOT PLAN 18

3.4 WATER BALANE DIAGRAM 28

3.5 INDEX PLAN 30



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LIST OF ANNEXURES

ANNEXURES

NO. PARTICULARS PAGE NO

1 PREVIOUS TERMS OF REFERENCE APPROVED BY

MOEF FOR IMPORTED COAL BASED POWER PLANT 39

2 HEADS OF AGREEMENT BETWEEN IOC AND

CHENNAI POWER GENERATION 47

3 MOU BETWEEN IOC AND CHENNAI POWER

GENERATION 56

4 LAND SURVEY NUMBERS DETAILS FOR PROJECT

SITE 60



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CHAPTER – I

EXECUTIVE SUMMARY

Sl.No

1 Title of The Project

1050 MW ( 2 x 525 MW) Combined Cycle Power Project of M /S. Chennai Power Generation Limited at Kattupalli and Kalanji villages at Ponneri Taluk, Thiruvallur district, Tamil Nadu .

2 Name & Address of The Project Proponent

M/s Chennai Power Generation Limited 10, First Street, Gopalapuram Chennai 600 086 [email protected] Phone Nos. 28117004, 28117005

3 Site Where Proposed Plant Will Be Located

Tamil Nadu / Thiruvallur District. /Ponneri Taluk/ Kattupalli & Kalanji Villages

4 Survey of India Topo sheet No

66 C/7

5 Latitude & Longitude 13⁰19’8.55” to 13⁰20’06.48”North 80⁰19’36.30”- 80⁰20’04.33” East

6 Project Area Out of 175.08 acres of land 153.08 acres is proposed for the Main Plant and 22 acres of (Part of 22 acres falls in CRZ area Zone III) is proposed for Pipe Corridor Area.

7 Approach Road, Railway

The Proposed Site is well connected by road approach. Road connecting Kalanji village with North Chennai Thermal Power Station Road is passing East of the project area which is connected to Minjur. Rail: Existing broad-gauge railway line connecting Athipattu Railway Station to North Chennai Thermal Power Station of TNEB is about 8 km from site.

8 Distance from Nearest Town/City

Minjur, 10 kms (By Road) from Plant site.

9 Notified Archaeologically important places, Monuments

Nil within 10km radius

10 Local Places of Historical and Tourism Interest


11 Environmental sensitive areas, Protected areas as per Wildlife Protection Act, 1972 (Tiger reserve, Elephant reserve, Biospheres, National parks, Wildlife sanctuaries, community reserves and conservation reserves)

Nil within 10km radius. Pulicat Sanctuary – 12 km - North

12 Reserved / Protected Forests

Nil within 10km radius.

13 Capacity of the Project Under Consideration

1050 MW (Nominal)

14 Power Plant Size Two modules of CCPP (Combined Cycle Power Plant) each comprising 1 GTG of 359 MW capacity (Gas Turbine Generator) +1 HRSG (Heat Recovery Steam Generator) + 1 STG of 166 MW capacity (Steam



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Turbine Generator) totaling 2 x 525 MW = 1050 MW shall be installed.

15 Source of Fuel

The Gas for proposed 1050 MW Gas Fired CCPP shall be supplied by Indian Oil Corporation Limited (IOCL) to site from their proposed Regassified Liquefied Natural Gas (RLNG) terminal at Ennore Port (6 Kms). CPGL has signed Heads of Agreement with IOCL for supply of Regassified Liquefied Natural Gas (RLNG)

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Water:

Source of Water

Sea water from Bay of Bengal will be brought to the Plant through intake well construction of offshore booster pump house and intake pipeline.

Average Daily Quantity of Water Required

Approx. 48 MCM water per annum required (1,30,800 mm3/ day.)

Type of Cooling System Quantity and Expected Characteristic of Waste Water Discharged

Induced Draft Cooling Towers As per MoEF Guideline

16 Distance from Water Source The Sea water from Bay of Bengal will be brought to the Plant through construction of onshore sea water intake pump house and pipe line for a distance of 1.5 Km.

17 Air Emissions Main Stack. Bypass Stack

18 Transmission Corridors and Power Evacuation System

Power generated from the proposed Plant units will be evacuated through 400 KV outdoor switchyard which will be connected by 400 KV double circuit transmission line to the proposed pooling station of National Grid Substation of Power Grid Corporation Limited (PGCIL) located at Sriperumbudur).

19 Green Belt Proposals Trees for formation of green belt around 50-meter-wide around the plant site will be suitably chosen. Special landscaping shall be made around the technical buildings, main entrance of Power House and Administrative building. Plantation of green belt shall commence at appropriate time, so that green belt is sufficiently developed during the time of commissioning of the project.

20 Rehabilitation and Resettlement plan (R&R plan)

No Home oustees. However Private Land Acquisition is involved.

21 Project Schedule for Commissioning

Commissioning of 1st Module: 24 Months Commissioning of complete plant in combined cycle mode (Both Modules): 30 Months

22 Project schedule and Cost Estimates

The Project Cost is estimated at US $ 825.16 million (Rs. 53635.4 Million @ Rs 65 Per $ ),



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CHAPTER – II

INTRODUCTION OF THE PROJECT / BACKGROUND INFORMATION

2.0 GENERAL:

M/s General Mediterranean Holding through its subsidiary M/s Chennai Power

Generation Limited (CPGL), is proposing to setup a 1050 MW Gas Based combined cycle

power plant in Kattupalli and Kalanji villages at Ponneri Taluk, Thiruvallur district, Tamil

Nadu state. The complete project will be executed on EPC basis.

2.1 BACK GROUND OF THE PROJECT:

The location was selected by TNEB and the Project conceived by TNEB as a 1050

MW Gas based project was allotted through the MOU route and was signed with TNEB by

the Company in year 1998. The PPA was also negotiated with RLNG as Fuel and initialed

by TNEB.

Land is reserved vide GO No 47 dated 5-2-1998 for setting up of this power plant.

Availability of sufficient vacant land in the area, location selected by TNEB.

Environmental Clearance from MOEF&CC was obtained vide letter No. J

13011/11/96-1A11 (T) dated 19.3.97 using naphtha as fuel.

Various other clearances like NOC from Tamil Nadu Pollution Control Board, District

Forest Officer, Clearance from Airport Authority of India NAAI New Delhi, Clearance from

Ministry of Defence, Clearance from Fisheries department, NOC from Madras Metro-water

and Sewerage Board, In Principle Mega Power Project Status from Ministry of Power, etc.,

were obtained.

TIDCO dropped the proposal to establish the RLNG Terminal. Then the Company

had approached MOEF&CC to give amendment for change of fuel from Naphtha to

Imported coal. (Ltr no 27/12/2008).

MOEF&CC asked for revised EIA/EMP report vide letter no J-13011/11/96-IA-II (7)

dated 18/1/2008 for the proposed coal based thermal power-plant using imported coal.

Subsequent to submission of fresh application to get Environmental Clearance to

MOEF & CC for the project during January 2009, based on the EAC Meeting held during

12th and 13th March 2009 and again on 15th and 16th April 2009, TOR was issued for the

project in letter No. J-1301/11/96 IA II (T) dated 03.06.2009.

During the presentation by the CPGL to the Expert Committee, it was informed that

there is overlapping of lands between our project site and the North Chennai Power



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Company Project site and CPGL requested the Committee to impress upon North Chennai

power company to spare 70 acres of land for the proposed project so that both the projects

can come up in the same area.

M/s North Chennai Power Company refused to spare the land and MOEF&CC gave

Environmental Clearance to North Chennai Power Company ignoring CPGL objections

and also imposed two special conditions in the Terms of Reference namely Clear

ownership of the lands belonging to the company free of all encumbrances and there

should not be any overlapping of the lands belonging to any other company and CPGL

have to get a certificate from Revenue Authorities for the above two conditions.

Even though CPGL had completed studies as per TOR, but could not proceed

further as Pollution Control Board, Tamil Nadu refused to conduct Public Hearing stating

that overlap of land issue was not resolved.

As the project could not proceed further and in order to get remedy CPGL

approached Hon’ble High Court, Madras in W/.P. No. 25545 of 2010 and 25080 of 2010

for cancellation of environmental clearance issued to M/s North Chennai Power Company.

In the counter filed by MOEF&CC., they had stated that they had no objection for the

two Power projects co-existing in the areas in question with maintenance of environmental

integrity of power project to come up vis-à-vis that of the base line environment. Further,

during the arguments in the Court M/s North Chennai Power Company submitted that they

have no objection for CPGL to acquire lands in the overlapping area and proceed with their

project.

Based on the assurance given by MOEF&CC in the Counter that both projects can

co-exist, the case pending in the High Court of Madras was disposed on 29.11.2011.

During the litigation in the Court, the validity of TOR given to the project on 3.06.2009 had

expired and CPGL gave a representation to MOEF&CC on 13.05 2015 for extension of

validity.

MOEF&CC in their letter NO. F.No. J/13011/11/1996/IAII(T) dated 18.06.2015 had

directed CPGL to apply for fresh TOR. Based on the above direction of MOEF&CC, CPGL

submitted the application for issue of fresh TOR.

During the 43rd Meeting of the Expert Appraisal Committee held on 18th September

2015, the project was taken up for discussion and the Committee suggested that Project

Proponents may amicably resolve with North Chennai Power Company regarding land

overlapping issue and approach for further consideration of TOR.

However, North Chennai Power Company had refused to spare any land and hence

CPGL had prepared alternative proposal avoiding North Chennai Power Company’s land.

Now as per the CEA guidelines CPGL had decided to install the power plant based



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on Supercritical parameters. As the nearest supercritical unit size, available in India is 600

MW, Company decided to change the unit size from 2 x 515 MW to 2 x 660 MW

Supercritical plant based on imported coal. TOR was obtained for imported coal based

power plant for 2 X 660 MW Super critical power plant in letter number J-13012/16/2015-

1A-I(T) dated 10.06.2016 (Annexure 1).

However the company could not proceed further in the project as it could not tie up

for import of coal and tariff was also high

Hence, company has decided to change the fuel from coal based 2 x 660 MW

Supercritical plant to 1050MW gas based combined cycle plant due to availability of RLNG

from IOCL terminal coming up at Ennore which is about 6 km from selected plant site.

CPGL has signed heads of agreement with IOC for supply of RLNG. (Annexure 2).

Further GCGL also signed Gas transportation Agreement with IOCL for transport of RLNG

supply at the plant site.( Annexure – 3)

This Feasibility Report is prepared for the 1050 MW gas based combined cycle

power plant. It is proposed to adopt the latest technology on generation of power at most

economic parameters and competitive rates, meeting the statutory environmental norms

laid out by the Central /State Pollution Control authorities.

Now the company has submitted a fresh proposal for issue of fresh TOR for 1050

MW (2X525MW) RLNG based Combined cycle power plant.

2.2 NEED FOR THE PROJECT:

The utility electricity sector in India had an installed capacity of 314.64 GW as of 31st

January 2017. Renewable Power plants (including Hydro) constituted 29.94% of total

installed capacity and Non-Renewable Power Plants constituted the remaining 70.06%.

India became the world's third largest producer of electricity in the year 2013 with 4.8%

global share in electricity generation surpassing Japan and Russia. Of the 1.4 billion people

in the world who have no access to electricity, India accounts for over 300 million.

The International Energy Agency estimates India will add between 600 GW to 1,200

GW of additional new power generation capacity before 2050. This added new capacity is

equivalent to the 740 GW of total power generation capacity of European Union (EU-27) in

2005.Besides the existing installed capacity of 314.64 GW, GoI has encouraged private

sector participation in power generation. The total power generation in Southern Region is

82,008 MW consisting the states of Tamil Nadu, Andhra Pradesh, Telangana, Karnataka,

Kerala and union territory of Puducherry.

As per Planning Commission, the capacity addition of 88,537 MW has been planned

from conventional sources for the 12th Five Year Plan on an All India basis.



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The long term projected demand for energy is only expected to grow, as per the 18th EPS

of CEA:

From the above table it may be noted that the southern region is having a Surplus of

3.3 % in respect of energy and there is a short fall of 10 % as on 2016-17 as projected by

CEA. In respect of all India bases, the energy is surplus and peak surplus of 2.6 %. Even

though All India Basis there is Surplus both in Energy and Peak demand, the surplus will be

wiped out. If the industrial development in India expand exponentially and India will become

an energy deficient Country. The projects in the pipeline both in All India basis and

Southern region may not meet the respected demand in the future. The non-conventional

energy sources such as wind energy and solar energy may not meet the energy and

demand projection.

Considering the above scenario of power requirement in Tamil Nadu and also on All

India basis and the persisting power shortage in Southern and Western region, the

proposed 1050 MW Thermal Power Project at Thiruvallur District in Tamil Nadu State is well

justified.

2.3 EMPLOYMENT GENERATION (DIRECT AND INDIRECT) DUE TO THE

PROJECT:

The requirement of skilled/unskilled persons will be met from nearby villages during

construction phase in addition to some regular employment during the operation of the plant.

The Project will also help in generation of significant indirect employment. This will have

positive socio-economic development in the region. There will be in general upliftment of

standard of living of the people in the region/ neighborhood.



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CHAPTER – III

PROJECT DESCRIPTION

3.1 TYPE OF PROJECT INCLUDING INTERLINKED AND INTERDEPENDENT

PROJECTS, IF ANY:

This project pertains to 1050 MW Power plant using RLNG as Fuel. The Gas for

proposed 1050 MW Gas fired CCPP shall be supplied by Indian Oil Corporation Limited

(IOCL) to the site from their proposed RLNG terminal at Ennore port (6 km). The RLNG

shall be brought from the proposed RLNG terminal of IOCL at Ennore Port up to the

proposed power plant through pipelines to be constructed by IOCL.

3.2 SITE DESCRIPTION

3.2.1 LOCATION & COMMUNICATION:

The 1050 MW Power plant is proposed to be located in Kattupalli and Kalanji village

at Ponneri Taluk, Thiruvallur district, Tamil Nadu state. This site is a part of Survey of India

Topo sheet No 66 C/7, lying at Latitude 13o19’8.55” to 13 o20’06.48”North and Longitude

80 o19’36.30”- 80 o20’04.33” East. Out of 175.08 acres of land 153.08 acres is proposed for

the Main Plant and 22 acres (Part of land falls in CRZ Zone III area) is proposed for Pipe

Corridor Area. The site is located 6 km north of Ennore Port, which is 22km north of

Chennai. Chennai Airport is about 40 Km from the site. Athipattu is the nearest railhead.

The area is approachable from the North Chennai Power Plant (NCTP) – Ennore Port road,

which branches off the Chennai – Manali – Minjur road near Vallur village.

The location plan is given in Figure No 3.1 and Map Showing Project Boundary with

Co-ordinates is shown in Figure 3.2



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Figure No 3.1



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Figure No 3.2

SATELLITE IMAGE SHOWING PROJECT BOUNDARY WITH CO ORDINATES



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3.2.2 TOPOGRAPHY & DRAINAGE:

The project area is a typically plain coastal area with sandy soil and sparse

vegetation. The general slope of the area is from Northwest to Southeast. The site elevation

is up to 10m above mean sea level (AMSL). The Bay of Bengal is located at 1.5km – East

of the plant area and Buckingham canal is located at 100m in the West of the plant area.

Proposed site represents a typical sea shore based environment.

3.3 DETAILS OF ALTERNATIVE SITE CONSIDERED AND THE BASIS OF SELECTING

THE PROPOSED SITE, PARTICULARLY THE ENVIRONMENTAL

CONSIDERATIONS:

This location is selected by Tamil Nadu Electricity board for setting up the Power plant

and allotted to CPGL through MOU route. This land is also reserved vide GO No 47 dated

5-2-1998 for setting up of this power plant.

The proposed site has the following advantages:

Proximity to the well developed Ennore Port and L & T Kattupalli Port for

logistical advantages.

Availability of sufficient vacant land in the area.

Proximity to sea and availability of sea water as source of water without putting

constraints on the existing water system of the locality.

Proximity to load centre (i.e Chennai city)

Absence of any ecologically sensitive features in the 10km region.

The location has the advantages of good accessibility for reaching the site,

transport of heavy machinery, Easy availability of sea water by pipelines,

Evacuation of power is by 400 kV Transmission lines. The transmission lines will

be linked to PGCIL 400kV substation at Sriperumpudur.

Availability of RLNG from proposed IOCL terminal coming up at Ennore which is

about 6 km from selected plant site.

3.4 SIZE OR MAGNITUDE OF OPERATION

The proposed 1050 MW Power Plant will be established in the identified 175.08

acres of land which is selected excluding M/S ABAN LLOYD Power Plant site. Out of

175.08 acres of land 153.08 acres is proposed for the Main Plant and 22 acres is proposed

for Pipe Corridor Area (Part of land falls in CRZ Zone III). The area is divided into two

parts comprising main plant area and pipe line corridor area. The sea water pipe line from

the sea will pass through this proposed pipe line corridor and will be connected to the main

plant through buried pipe line in the intervening road side Government land after obtaining

necessary permission. The entire land is private lands.



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3.5 PROJECT DESCRIPTION WITH PROCESS DETAILS

3.5.1 PLANT SIZE AND ASSOCIATED ACTIVITIES:

The layout is based on the following assumptions:

• Two modules of CCPP (Combined Cycle Power Plant) each comprising 1 GTG of 359

MW capacity (Gas Turbine Generator) +1 HRSG (Heat Recovery Steam Generator) + 1

STG of 166 MW capacity (Steam Turbine Generator) totaling 2 x 525 MW = 1050 MW

shall be installed.

• The plant will be operated on RLNG (Regassified Liquified Natural Gas) only.

• Closed recirculation cooling water with cooling tower shall be adopted for STG

Condensers

• Horizontal type HRSG unit shall be installed.

• The layout has been developed on concept in which power block equipment will be

located in one block, housing the combined cycle module consisting of 2 nos Gas

Turbine and 2 nos Steam Turbine and associated auxiliaries. The block will be located in a

Single Turbine Building. The block will have one switchgear and central Control Room

building as annexe to the turbine building for operational advantage.

The Plot Plan has been developed based on 2 nos combined cycle modules. However,

depending upon the final selection of single shaft or combined cycle modules based on the

manufactures proven design, the plot plan shall be optimized.

• Tentative land requirement for the plant will be around 175.08 acres of land in that 153.08

acres is proposed for the Main Plant and 22 acres of (part of this area is in CRZ Zone III) is

proposed for Pipe Corridor Area

3.5.2 TECHNICAL PROFILES:

It is proposed to install 1050 MW Combined Cycle Power unit for this project. This

will also facilitate execution of these projects in a lesser time frame which will go a long way

in mitigating prevailing the power shortages in the country.

The per day requirement of 1050 MW combined Cycle plant shall be 4.8 Million

Metric Standard Cubic Meter Per Day (MMSCMD) considering Gross Calorific Value of gas

as 8000 kcal/SCM and plant heat rate of 1600 kcal/kwh. The daily gas consumption at 85%

PLF is estimated around 4.0 MMSCMD.

3.5.3 MAIN PLANT EQUIPMENT AND SYSTEMS

The Combined Cycle Power Plant (CCPP) will consist of two modules. Each Module

will have one (1) Gas Turbine Generator, one (1) HRSG and one (1) Steam Turbine

Generator.



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3.5.4 Gas Turbine Generator (GTG):

The GTG set shall be heavy-duty industrial type, capable for fuel firing with

Re-gassified Liquefied Natural Gas (RLNG). GTG would have an ISO output of around 359

MW - in open cycle and plant output of around 1050MW (ISO) under combined cycle mode

of operation. The synchronous generator would be hydrogen cooled, 3000 rpm, 50 Hz set.

The GTG set would be self-contained as far as practicable requiring minimum interface with

other plant facilities.

The GTG would be suitable for indoor installation, and capable of continuous

operation at all loads under site conditions in simple cycle mode and combined cycle mode

at base load. The GTG would be provided with individual bypass stack and transition piece

section and a straight / tee piece upstream of the HRSG to enable operation in simple

cycle mode when HRSG is taken out for maintenance. GTG would be skid mounted to the

extent possible along with enclosure and all associated auxiliaries for ease of

transportation, handling and installation.

3.5.5 Gas Turbine Module

The gas turbine Module would consist of the turbine and compressor with

annular combustor installed in between. The main components of the unit will be –

• Rotor with turbine blades and compressor blades supported and guided in two/more

journal bearings and one thrust bearing.

• Compressor casing and turbine casing.

• Variable compressor inlet guide vanes.

• Compressor vanes installed in the compressor casing and the compressor vane carrier.

• Compressor diffuser.

• Turbine vane carrier and turbine vanes.

• Exhaust casing

• Compressor Bleed-off system

• Supports at the turbine end and the compressor end.

3.5.6 Heat Recovery Steam Generator (HRSG) and Auxiliaries

HRSG would be connected to GT exhaust gas duct with supports, transition piece

section, straight / Tee piece and expansion joints.

The HRSG would be of natural circulation type with dual/triple pressure stages with

steam parameters as per the optimum heat cycle design. The HRSG would be of unfired

heat recovery type designed to accept the maximum gas flow and exhaust gas temperature

from the gas turbine when operated under extreme site conditions.

The exhaust gas temperature at the HRSG exhaust would be designed to leave at a



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temperature well above the acid dew point to prevent back end corrosion. The HRSG would

be designed to operate in sliding pressure mode with variation of HP steam pressure with

load being within the acceptable limits of steam turbine.

The HRSG is suitable for outdoor installation. The entire HRSG would be

constructed to form a gas-tight envelope to prevent gas leakage. Any penetration of the

enclosure required for piping, etc. would be designed to retain the pressure-tight integrity of

the enclosure. The HRSG would be designed to meet all the requirements of Indian Boiler

Regulations (IBR), ASME Section-VIII and ANSI B 31.1.

The steam drums would be of fusion welded construction, fabricated from carbon

steel plate and equipped with two (2) manholes, one at each end of the drums. Connections

are provided on the steam drums for steam outlet, feed inlet, riser and down comers,

venting, safety columns, chemical feed, sampling and nitrogen blanketing. The spray-tube

desuperheater would have all necessary internals, control and shut-off valves. The inlet

ductwork would be fabricated as shop assembled panels consisting of carbon steel outer

casing, insulation and internal liner. The ductwork from the HRSG to the stack would be

carbon steel provided with wire mesh stand-offs for personnel protection. The ductwork

would be properly stiffened, reinforced and complete with necessary doors and expansion

joints. The casing would include all necessary backstays, access doors, inspection ports,

etc., and would be designed to withstand a pressure equal to maximum turbine exhaust

static pressure.

3.5.7 Steam Turbine Generator and Auxiliaries

The steam turbine generator unit would be located in the turbine building and would

operate with steam from HRSG in a module. The turbine-generator unit would be a 3000

rpm, double casing, condensing type with a maximum continuous rating (TMCR) to suit the

guarantee Module Output.

Steam Turbine Casing

Separate casing for different sections of turbine or alternatively combine HP/ IP and LP

casing are acceptable provided they meet the proveness of major equipment as specified.

The casings shall be designed to withstand the maximum pressure and temperature to

which they are likely to be subjected. The casings shall be symmetrical in design to

minimise the effects of thermal stresses. The casings shall be keyed to permit free radial

and longitudinal expansion while maintaining the eccentricity of shaft and the casing. LP

casing shall be provided with pressure relief bursting diaphragms for protection against

increased pressure and a self-contained exhaust hood. Spray system to protect against

excessive temperature under different conditions of operation.



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The HP outer casing consists of an upper and a lower half fabricated from cast steel. The

pre-tensioned bolts in the horizontal flange hold the casing halves together, so that no

gaskets would be required to prevent the steam leakage.

The blade carriers would be made of cast steel having material properties suitable for the

steam temperature and pressure conditions. These are split into two halves at the

horizontal joint and bolted together with hydraulic pre-stressed elongation bolts. The gland

seal casings are also fitted within the pressure casings. All condensate collection points

would be connected to the drainage branches to remove the drains.

Low Pressure (LP) Casing

Exhaust steam from HP casing will enter a single flow LP turbine having axial

exhaust. The main components of the low-pressure turbine casing consist of outer casing,

the LP casing, rotor and the shaft sealing.

Steam would be led from the vertical steam admission line via the steam inlet into

the inner casing. The inner casing inlet section together with the radially arranged

stationary blade row would ensure proper flow of steam to the blading’s.

Gland Seals

The shaft seals prevent air ingress into the turbine and steam leakage into the

ambient atmosphere. The design of the sealing segments would be non-contacting type

during normal operation. The shaft seals consist of a lower and an upper part bolted

together. Steam from this system together with air leaking from the outside is led to the

gland steam condenser.

3.5.8 Environmental and Efficiency Considerations

The Power Plant shall be designed for optimum efficiency, availability and reliability

using advanced class Gas turbine of state-of-art technology. Gas Turbine with high open

and combined cycle efficiencies and having proven performance record shall be installed.

Gas Turbine shall be provided with low NOx fuel burners to make the power station

environmentally compliant to local norms.

Triple pressure Heat Recovery Steam Generator with optimum steam parameters

shall be selected to maximise the waste heat utilisation from gas turbine exhaust flue gas.

Steam Turbine Generator from reputed manufacturers will be installed to optimise

the combined cycle efficiency of the module. Separate HP/LP by-pass system for HRSG

capable to by-pass MCR flow of steam from HRSG is envisaged for quick and independent

start-up of HRSG while the steam turbine is in partial load.

Closed cycle circulating cooling water with cooling towers for STG condensers will

be adopted to improve the condenser vacuum and thereby maximise the LP turbine output.



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3.5.9 PLANT LAYOUT:

The layout of the main plant along with all the auxiliary systems for 1050 MW

units is shown in Plant layout Figure No 3.3.

The conceptual plant layout has been developed considering the proposed location of

the plant. The layout is based on the following assumptions:

Two nos modules of CCPP each comprising 1 GTG +1 HRSG + 1 STG shall be

installed.

The plant will be operated on RLNG only.

Closed recirculation cooling water with cooling tower shall be adopted for STG

Condensers

Horizontal type HRSG unit shall be installed.

The layout has been developed on concept in which power block equipment will be

located in one block, housing the combined cycle module consisting of 2 nos Gas

Turbine and 2 nos Steam Turbine and associated auxiliaries. The block will be located

in a Single Turbine Building. The block will have one switchgear and central Control

Room building as annexe to the turbine building for operational advantage.

Steam Turbine will be located near the centre of the block keeping adequate

maintenance space around. Condensers will be located on Turbine Hall floor with

C.W. pipe entry and inlet at one side and tube cleaning and removal provision on

other. Condenser hot well will be located in basement.

GTG Inlet air filter is proposed to be located on top of the electric generator in order to

reduce inlet air flow path to GTG. GT Generator will be located in the electrical bay.

Heat cycle equipment for the module comprising de-aerator, BFP’s (Boiler Feed

Pumps) will be located near the HRSG. Balance of Plant facilities (other than heat

cycle equipment) will be located as reflected in the plot plan.

All the outdoor and yard piping shall be taken on pipe racks, except for the fire hydrant

system, which shall be buried. Small local stretches of pipes may be taken in trenches

or just above ground, should the layout warrant at the time of execution. Interplant

cabling shall also be taken on the pipe rack wherever possible.

The Plot Plan has been developed based on 2 nos multi-shift combined cycle

modules. However, depending upon the final selection of single shaft or multi-shift

combined cycle modules based on the manufactures proven design, the plot plan

shall be optimized.

Tentative land requirement for the plant will be around 175.08 acres including green

belt and pipeline corridor.

Feasibility Report for 1050 MW ( 2 x 525 MW) Combined Cycle Power Project of M/S. Chennai Power Generation Limited at Kattupalli and Kalanji villages at Ponneri Taluk,

Thiruvallur district, Tamil Nadu

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PLOT PLAN Figure No 3.3



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3.5.10 PLANT WATER SYSTEM

The total water requirement for the power plant is 5450 m³/hr (1,30,800

m³/day) for 1050MW plant. The total annual water requirement will be approximately 48

MCM. The entire water requirement will be met from Sea water.

Sea water after screening is proposed to be used for cooling of steam

turbine condensers, services other than condenser cooling requiring de-mineralised

water will be met by processing sea water. Sea water intake pump house with pipelines

is proposed to deliver total cooling and consumptive water requirement of the power

plant to the pretreatment plant and makeup to the cooling tower basins located in the

plant area. The fire water pumps will be located in a pump house adjacent to the clarified

water reservoir.

The water treatment system comprises of Water Pre-treatment Plant, RO

Plant (Desalination Plant), DM Plant, Electro-chlorination Plant, Condensate Polishing

Plant, CW Treatment Plant.

Consumptive water will primarily consist of de-mineralised (DM) water for

HRSG feed water make-up and NOx control in the GTG (if required), make-up water to

the air-conditioning and ventilation systems, potable water and miscellaneous services

such as plant washing, etc. DM water is envisaged to meet feed cycle make up and make

up requirement of auxiliaries.

Adequate storage of potable water as well as DM water will be provided

inside the CCPP premises. The individual storage capacities will be based on the buffer

requirement at the relevant stages of the process to ensure uninterrupted operation of the

plant. Firewater storage tank sizing will meet the TAC/ NFPA Regulations which will be

met from the clarified water reservoir.

3.5.11 Cooling Water Systems

Sea Water Intake System

Water required for the power station is drawn from the sea which is about

1.5 KM away from the Main plant. Three (3) vertical turbine pumps (2 working + 1

standby) each of suitable capacity with required head will be installed in the raw water

intake pump house for pumping raw water from sea to plant water treatment system and

cooling tower make-up. Suitable gate, trash rack & travelling water screen will be

provided for the intake pump chamber.

Condenser Cooling water system

Closed cycle circulating water system for the condenser is adopted with

Induced draft cooling tower. The makeup cooling water will be drawn from the clarified

water storage tank. The CW system will consist of basin, circulating water (CW) pumps,

pump discharge and condenser inlet/ outlet piping, butterfly valves, expansion joints,



20

debris filters, online tube cleaning system of the Condenser etc. To supply the cooling

water requirement of the condenser, 3x50% (2W + 1S) capacity vertical mixed flow

pumps of about 29,120m3/hr capacity each are proposed. The pumps will be located

indoor in the CW Pump House. Pumps shall be self-lubricated type. One EOT crane will

be installed for erection / maintenance of the C. W. pump sets.

The pump discharge lines and condenser inlet / outlet pipes will be of

carbon steel with internal cement mortar lining and external gunniting/other protective

coating. For the purposes of isolation and control, motor-operated / hydraulically

operated/ butterfly valves are proposed on the CW pump discharge lines, and condenser

inlet and outlet pipes. Expansion joints will be provided on the CW pump discharge lines

and condenser inlet and outlet lines to take care of misalignment and thermal expansion

of these pipelines and condenser as well as to facilitate dismantling of the butterfly

valves. Hot water from the condenser will be discharged in concrete conduits which will

lead the water into a hot water distribution header of the cooling tower.

Auxiliary Cooling water system

GTG, STG and HRSG auxiliaries / coolers associated with HP / LP feed

pumps, condensate pumps, station and instrument air compressors, sample coolers etc.

will be provided with a closed cooling system using passivated DM water. The DM water,

in turn, will be cooled in 2x100% plate type heat exchangers using auxiliary cooling water

drawn through three (3) x 50% capacity ACW pumps from CW inlet piping to the

condenser. Two (2 x 100%) closed cooling water (CCW) pumps will circulate the DM

water through the various auxiliaries and the heat exchangers. Hot water from these heat

exchangers will lead to the hot water conduit of the main CW system and will return to

the cooling tower.

3.5.12 Cooling Tower

The cooling tower will be designed for continuous operation. The hot water

distribution system will be designed to ensure equal distribution of heat load and flow all

over the fill area. Wood/timber will not be used as material of construction in any part of

the cooling tower.

It is proposed to install two (2) Induced draft cooling towers, one for each

unit, of capacity 32,000 m3/hr. The cooling water will be collected in a RCC basin. The

cooling tower will be designed for an approach of 5˚C. The design wet bulb temperature

is considered as 27˚C. The design hot and cold-water temperatures of the cooling towers

will be 39˚C and 32˚C respectively. Tower construction will be of RCC with PVC splash

type fill. The total CW flow from three cooling tower basins is proposed to be conveyed

by gravity to the common CW fore bay and CW pump chambers through RC rectangular

open channels. The channels will be designed to accommodate maximum level



21

fluctuations expected under transient flow conditions.

The fore bay will be designed to ensure equal distribution of flow to the

CW pumps as well as to limit the entrance velocity at the CW pump chambers. The top

level of the fore bay walls will be fixed on the basis of maximum upsurge expected in the

fore bay, when all the CW pumps trip under normal water level condition. The sump level

of the pumps will be fixed so as to ensure adequate submergence to the CW pumps.

3.5.13 Water Treatment System

The water treatment system comprises of Water Pre-treatment Plant, RO

Plant (Desalination Plant), DM Plant, Electro-chlorination Plant, Condensate Polishing

Plant, CW Treatment Plant as described below.

3.5.14 Pre Treatment Plant

Raw water shall be pumped from sea water intake pump house to aerator

(one number). From aerator, water shall flow to stilling chamber (one number) and from

stilling chamber to inlet chamber. Flow-measuring instrument (Parshall flume) shall be

installed for measuring the flow between stilling chamber and inlet channel.

Simultaneously raw sea water through a branch off pipeline will be supplied to the CW

makeup system. Bypass channel shall be provided for bypassing the clarifier of

respective system. Chemical dosing shall be done in the clarifier. Chlorine shall be dosed

in stilling chamber.

From clarifier System, water shall flow to clarified water storage tank. This

water shall be used as influent to Gravity filters. Two (2) numbers of air blowers shall be

provided for air scouring of gravity filters. Sludge from the clarifier shall be discharged

into a sludge sump, from where it shall be pumped by means of 2 x 100% capacity

sludge disposal pumps to sludge thickeners for disposal of sludge cakes by trucks.

Gravity filters shall be backwashed by filtered water. Filtered water shall be

stored in an overhead tank to be used as potable water through pumps. The filtered

water will be fed to Reverse Osmosis (RO) Plant comprising RO stage – 1 and RO stage

– 2. The desalinated water of RO stage -1 will be used for fire protection system and

service water system and potable water after hypo chlorination treatment. 2nd stage

desalination water will be used for potable water after hypochlorisation and as influent for

the DM plant.

3.5.15 Demineralization (DM) Plant

The DM plant will be designed for a total productive output of about 60 m3/

hr of DM water based on 3% makeup for HRSG plus steam injection for NOx control in

the GTG if applicable. The DM plant will have three stream each of 30 𝑚𝑚3/ hr capacity

(2W+1S) streams with two working and one standby each consisting of three (3) Nos



22

activated carbon filters, three (3) Nos cation units (SAC + WAC (depending upon water

quality)), Three (3) Nos anion units (SBA + WBA (depending upon water quality)), and

Three (3) Nos mixed bed units. Three (3) Nos Degassers comprising 3 nos Degasser

Towers and degassed Water storage tank with all accessories. The use of ultrafiltration

process will be considered if necessary depending upon the Sea water analysis to

achieve desired quality of DM water. The DM water from DM plant will be stored in two

numbers of DM water tanks capable to meet 7 days’ plant requirement at full load. The

operation of the plant will be automatic based on programmable logic control (PLC) and

data-link with the plant DCS.

3.5.16 Electro Chlorination Plant

Electro chlorination plant is envisaged to avoid growth of algae and bacteria in

the sea water intake at the seashore and CW system. This is accomplished by sodium

hypo chlorination dosing in sea water intake and CW fore bay. This will also be used in

pre-treatment area for potable water. The chlorination system shall comprise 2x100%

(1W+1S). Hypochlorite generator with 2x100% booster pumps associated transformer

rectifiers etc. for generation of sodium hypochlorite 2x100% dosing pumps shall

employed for each dosing point.

3.5.17 Service & Potable Water System

The service water system supplies water required for the miscellaneous water

requirements such as for plant washing, toilets, gardening etc. The service water

requirement of the plant will be met by two (1 working + 1standby) service water pumps

each of suitable capacity which will be intermittently operated to pump the water to 2 nos

overhead tanks located at a point 30 m elevation. Water will be distributed through

various small overhead tanks located on top of plant buildings.

This system caters to the drinking water requirements of the plant personnel,

water to the wash basins in toilets and canteen. The potable water requirement of the

plant will be met by two nos (1 working + 1standby) potable water pumps. Plant potable

water pumps take suction from the RO-stage 1 permeate storage tank filtration unit of

DM plant and supply to 2 nos overhead tanks located at 30m elevation for further

distribution through individual overhead tanks to various consumer points by gravity.

3.5.18 OTHER SYSTEMS:

In addition to above facilities, other systems such as compressed air, air

conditioning ventilation, communication, control and instrumentation, etc. will be provided

commensurate with statutory requirements, with latest modern technological features



23

3.5.19 FIRE PROTECTION SYSTEM:

Fire protection system is envisaged as common facility for both Modules of

the CCPP. The design of the system shall be as per TAC/ NFPA and other applicable

standards for equipment design.

The following systems are proposed to protect the plant:

Hydrant system for exterior as well as internal protection of various buildings /

areas of the plant

High velocity water spray (HVWS) system for the protection of generator

transformers, turbine oil tanks, lube oil system equipment, unit auxiliary

transformers

Medium velocity water spray system for cable galleries etc.

Trolley mounted CO2 cylinders for control room protection or flooding system

using Halon – substitutes

Portable extinguishers and hand appliances for extinguishing small fires in

different areas of the plant.

Carbon dioxide flooding system for GTG.

Two independent motor-driven pumps each of 410 m3/hr capacities at 88 m head

have been envisaged for the proposed hydrant system. One motor-driven pump of

similar rating will be provided for the spray water systems. Two standby pumps of

410 m3/hr capacity driven by diesel engine will be provided. In addition, two

motors driven jockey pumps each of 30 m3/hr capacities will be provided to keep

the fire water mains at the desired pressure.

The fire water pumps will be located in the fire water pump house and take suction

from the RO stage-1 permeate storage tank. Starting of the pumps is automatic

and stopping of the pumps is manual except the jockey pumps which stop

automatically when the mains pressure is restored.

Hydrant System

Adequate number of fire hydrants will be provided at various locations in and

around the buildings and other plant areas. The hydrants will be provided on a

network of hydrant mains drawing water from the hydrant pump, which will start

automatically due to drop in pressure in the event of opening of the hydrant

valves.

Transformers and Turbine Lube Oil Tank Protection

Automatic high velocity water spray (HVWS) system is proposed for the

generator, transformer, station and unit auxiliary transformer. The system will

consist of a number of high velocity projectors mounted on a pipe network around



24

the transformers. Water supply from main to this pipe network will be through

deluge valves. Quartzoid bulb detectors mounted around the transformers will get

fused in the event of a fire at the rated (high) temperature which will cause the

deluge valve to open and the resulting pressure drop in the water mains will be

sensed by a pressure switch through which the spray water pump will be started

automatically and the spray of water will take place. Provision will also be made

for remote manual operation. Remote manual HVWS system will be provided for

turbine lube oil tanks.

Cable Vaults Protection

Medium velocity water spray (MVWS) protection is proposed for the cable

galleries.

The system is automatic with facilities for remote manual operation. To limit the

demand of water and reduce water damage, the cable galleries are divided into a

number of zones and with the help of a suitable alarm and detection system and

control logic, only the zone on fire and two adjacent zones on either side would be

sprayed with water.

Gas Turbine Protection

Gas turbine Generator is provided with automatic carbon dioxide (CO2) flooding

type of protection and this system is supplied along with the GTG package.

Control room protection is by means of large capacity (22.5 kg/45 kg) trolley

mounted CO2 extinguishers. Flooding with a suitable Halon substitute can also be

employed in lieu of CO2 extinguishers.

Portable Extinguishers

Adequate number and suitable type of hand appliances and trolley mounted fire

extinguishers will be provided in the various plant buildings for quenching small

fires in their incipient stage.

3.5.20 COMPRESSED AIR SYSTEM

Compressed air requirement is envisaged mainly for the following services:

For various control systems and power actuators – instrument quality, dry

compressed air at 7-8 kg/cm2 pressure.

For pulse cleaning of gas turbine inlet air filters – instrument quality, dry

compressed air at 7-8 kg/cm2 pressure.

For miscellaneous plant services – ordinary plant quality air at 7-8 kg/cm2

pressure.

For the complete plant, an integrated service and instrument air system is

proposed with a priority valve, which will cut the plant service air supply in case of



25

instrument air shortage thus giving the priority to the instrument air. The compressed air

requirement shall be met by 2x100% Instrument Air Compressor and 2x100% Service Air

Compressor for the complete plant compressor shall be oil free tube of suitable capacity

provided along with air receivers and other accessories and Two (2) x 100% capacity

heatless purge type air dryers for supply of instrument quality of air to control and

instrumentation (C&I) system. Normally, pulse cleaning air, if required for inlet filter will be

provided from GT compressor. Alternatively, it can be supplied from air supply system.

Capacity of the air compressors shall be guided by the air requirement of the EPC

contractor based on equipment selection.

3.5.21 AIR CONDITIONING SYSTEM

Properly designed ventilation and air-conditioning systems will be provided to

cater various areas of the plant. The system will be designed in line with the guidelines

and recommendations of ASHRAE and will follow acceptable industry practices.

Wherever practicable, relevant Indian Standards or other international standards will be

adhered to.

3.5.22 VENTILATION SYSTEM

All ventilation areas will be designed such that the difference between indoor and

outdoor temperatures will be within permissible limits. Pressurized ventilation system will

be provided for the turbine building and switchgear & MCC rooms of various plant

buildings CW pump house, etc. The system for each of the areas will be provided with

fresh filtered air supply arrangement consisting of bird screen louvers, filters and supply

air fan complete with ducts. Location and sizing of duct outlets will be done in accordance

with the guidelines of ASHRAE for effective air distribution.

The system will be designed such that positive pressure is maintained inside the

room to avoid ingress of dust, etc. Ventilated air will be exhausted through roof

extractors/back draft dampers.

3.5.23 ENVIRONMENTAL PROTECTION FEATURES OF THE PROPOSED PLANT:

The following environmental management measures are inbuilt in the plant design

itself: which will help in reducing emissions and effluents:

The Power Plant will be designed for optimum efficiency, availability and reliability

using advanced class Gas turbine of state-of-art technology. Gas Turbine with

high open and combined cycle efficiencies and having proven performance record

shall be installed. Gas Turbine shall be provided with low NOx fuel burners to

make the power station environmentally compliant to local norms.



26

Triple pressure Heat Recovery Steam Generator with optimum steam parameters

shall be selected to maximize the waste heat utilization from gas turbine exhaust

flue gas.

Steam Turbine Generator from reputed manufacturers will be installed to optimise

the combined cycle efficiency of the module. Separate HP/LP by-pass system for

HRSG capable to by-pass MCR flow of steam from HRSG is envisaged for quick

and independent start-up of HRSG while the steam turbine is in partial load.

Closed cycle circulating cooling water with cooling towers for STG condensers will

be adopted to improve the condenser vacuum and thereby maximize the LP

turbine output.

3.6 FUEL REQUIREMENT:

Regassified Liquefied Natural Gas (RLNG) will be used as fuel. The Gas for

proposed 1050 MW Gas fired CCPP shall be supplied by Indian Oil Corporation Limited

(IOCL) to the site from their proposed RLNG terminal at Ennore port (6 km). The RLNG

shall be brought from the proposed RLNG terminal of IOCL at Ennore Port up to the

proposed power plant through pipelines to be constructed by IOCL.

The per day requirement of 1050 MW combined Cycle plant shall be 4.8 Million

Metric Standard Cubic Meter Per Day (MMSCMD) considering Gross Calorific Value of

gas as 8000 kcal/SCM and plant heat rate of 1600 kcal/kw hr. The daily gas

consumption at 85% PLF is estimated around 4.0 MMSCMD.

3.7 RESOURCE OPTIMIZATION/RECYCLING:

Optimization/Recycling and Reuse is planned in the proposed plant.

3.8 OTHER SOURCES LIKE WATER, POWER/ENERGY REQUIREMENT:

3.8.1 WATER REQUIREMENT:

Water will be required for condenser cooling, cycle make-up and other

consumptive water requirements after doing appropriate treatment. The total estimated

make up sea water requirement for the cooling water system and other consumptive

requirement is 5,450 m³/hr (1, 30, 800 m³/day) for 1050MW plant. The total annual water

requirement will be approximately 48 MCM. The Sea water from Bay of Bengal will be

brought to the Plant through construction of onshore intake pump house and pipe line.

The discharge water pipeline shall be returned to Sea. The water balance diagram is

shown in Figure No 3.4. Water requirement during the construction period will be meet

from Ground Water or other sources



27

3.8.2 POWER REQUIREMENT:

The power required for operating the power plant will be met from the Power

generated in the plant itself. The auxiliary power consumption will be within the range of 3

to 3.5% of the Power plant capacity. During the construction period, temporary supply of

power from TNEB at 11 KV and 33 KV power lines to meet power requirement.

3.9. QUANTITY OF WASTE GENERATED (LIQUID & SOLID) AND SCHEME OF

THEIR MANAGEMENT/DISPOSAL:

This being the gas based power plant there will not be any ash disposal. Liquid

Waste will be mainly from the effluents generated from the combined cycle power plant

would be from Cooling tower blow down,DM plant Regeneration plant , Heat recovery

steam generator drum blow down, Sanitary waste, Water from Oil water Separator.

About 4127 m3 / hr of waste is expected to be generated from this plant of which

4045 m3/hr will be from Cooling tower blow down, RO reject and 82 m3/hr is expected to

be from other sources.

Its break up is as follows:

Cooling Tower Blow Down discharge back to sea = 3380 m3/ hr.

RO-1 & RO-2 (DM Plant) process waste discharge back to sea = 665 m3/ hr.

SubTotal = 4045 m3/ hr.

Others:

Heat Recovery Steam Generator Drum Blow Down to CMB = 20 m3/ hr.

Sanitary/ Industrial Waste to CMB = 55 m3/ hr.

Oil/ Water Separator to CMB = 2 m3/ hr.

Neutralization Pit in DM Plant = 5 m3/ hr.

SubTotal = 82 m3/ hr.

The cooling tower blow down and RO rejects (totaling) 4045 m3/hr will be

discharged back in to the sea based on Stimulation Modelling study and in compliance

with regulatory norms in order to keep temperature differential between blow down and

receiving sea water within permissible limits and will be disposed deep in to the sea

through diffuser ports to achieve optimum mixing to attain requisite temperature and

salinity

Other waste Water Collected ( 82m3/hr) will be collected in the Central Monitoring

Basin (CMB) and after treatment shall be utilized for Plantation or other industrial use..

Feasibility Report for 1050 MW ( 2 x 525 MW) Combined Cycle Power Project of M/S. Chennai Power Generation Limited at Kattupalli and Kalanji villages at Ponneri Taluk,

Thiruvallur district, Tamil Nadu

28

Water Balance Diagram Figure No 3.4.



29

3.10 SCHEMATIC REPRESENTATION OF THE FEASIBILITY DRAWING WHICH GIVE INFORMATION OF EIA PURPOSE:

The basic process involved in the EIA projects for grant of Environmental

Clearance is given below:

Submission of PFR, Form I, Summary and ToR in

MoEF & CC, New Delhi

Presentation MoEF & CC for grant of ToR

Submission of Draft EIA/EMP Report to TNPCB

Conducting Public Hearing

Preparation of Final EIA/EMP Report Public Hearing

Details

Presentation to MoEF & CC Committees for grant of

EC



30

INDEX PLAN Figure No – 3.5



31

CHAPTER – IV

SITE ANALYSIS

4.1 CONNECTIVITY:

The Proposed Site is well connected by road approach. Road connecting Kalanji

village with North Chennai Thermal Power Station Road is passing East of the project

area which is connected to Minjur.

4.2 LAND FORM, LAND USE AND LAND OWNERSHIP:

Land is reserved vide GO No. 47 dated 5.2.98 by Government of Tamil Nadu for setting

up the power plant. Land is mostly sea side waste lands only. No agricultural land is

involved. However, lots of industrial activities are happening in the area and there is good

demand for the land. 56 Acres of land have already been acquired by CPGL, out of the

total land requirement of 175.08 Acres of land. The balance land will be acquired from

private land owners.

4.3 TOPOGRAPHY (ALONG WITH MAP):

The project area is a typically plain coastal area with general slope of the area is

from Northwest to Southeast. The site elevation is up to 10m above mean sea level

(AMSL).. The ground level will be maintained above high flood level of the area.

4.4 EXISTING LAND USE PATTERN (AGRICULTURE, NON-AGRICULTURE, FOREST,

WATER BODIES (INCLUDING AREA UNDER CRZ), SHORTEST DISTANCES FROM

THE PERIPHERY OF THE PROJECT TO PERIPHERY OF THE FORESTS, NATIONAL

PARK, WILD LIFE SANCTUARY, ECO SENSITIVE AREAS, WATER BODIES

(DISTANCE FROM THE HFL OF THE RIVER), CRZ. IN CASE OF NOTIFIED

INDUSTRIAL AREA, A COPY OF THE GAZETTE NOTIFICATION SHOULD BE GIVEN:

There are no declared biospheres, wild life sanctuaries, or tiger sanctuary or migrating

corridor or Coastal zone in the core zone and 10 km buffer zone. Pulicat Sanctuary – 12

km, North.



32

In the 10km buffer zone, the following features are observed:

S.No Particulars Details

1 Nearest villages Kattupalli, Kalanji, etc

2 Nearest Major water bodies Buckingham canal – 100 m West

Bay of Bengal - 1.5 Km East from the Main

Power Plant

3 Notified Archaeologically important

places, Monuments


4 Local Places of Historical and

Tourism Interest


5 Environmental sensitive areas,

Protected areas as per Wildlife

Protection Act, 1972 (Tiger reserve,

Elephant reserve, Biospheres,

National parks, Wildlife sanctuaries,

community reserves and conservation

reserves)

Pulicat Sanctuary – 12km - North

6 Reserved / Protected Forests Nil within 10km radius

7 Defence Installations Nil within 10km radius

8 Seismic Zone Zone – II (Least Active)

9 Other Industries in the area North Chennai TPS, Vallur TPS, Ennore port,

L & T ship yard, L & T Port, Chettinad Coal

Terminal, Chennai Metro Desalination plant,

etc

Index plan showing the features within 10km radius is given as Figure No – 3.5

4.5 EXISTING INFRASTRUCTURE:

Better Infrastructure are avalable in the area. All necessarry infrastructures for this

plant will be created.

4.6 SOIL CLASSIFICATION:

The project area is a typically plain coastal area with sandy soil and sparse

vegetation.



33

4.7 CLIMATIC DATA FROM SECONDARY SOURCES:

Based on the meteorological data, the design ambient dry bulb temperature has

been considered as 28 ºC, RH of 79%, and cooling water temperature of 34 ºC. Climate

of the region can be considered as subtropical without any extreme variation in

temperature profile. Average annual rainfall is 1330 mm, out of which the maximum

precipitation is during the North-East monsoon period of October to December, when

nearly 70% of the annual rainfall occurs. Maximum rainfall invariably is in the month of

November and minimum in the month of March. The hottest months of the year are May

to July, when the monthly average temperature ranges from 35ºC to 37ºC. Individual day

maximum temperature during the summer months may go up to 40ºC.

4.8 SOCIAL INFRASTRUCTURE AVAILABLE:

Good social infrastructure facilities are available in nearby Minjur Town which is

located 8.2 KM from power plant site and Chennai city is located about 25 KM from the

Site



34

CHAPTER – V

PLANNING BRIEF

5.1 PLANNING CONCEPT (TYPE OF INDUSTRIES, FACILITIES, TRANSPORTATION ETC) TOWN AND COUNTRY PLANNING/ DEVELOPMENT AUTHORITY CLASSIFICATION:

The site has been chosen considering the availability of land, proximity of water,

evacuation of power through PGCIL, feasibility of gas linkage from upcoming RLNG

terminal of IOCL at Ennore Port and availability of other infrastructure facilities in the

vicinity of proposed plant.

5.2 POPULATION PROJECTIONS: The populations in nearby villages are given below: NAME DISTANCE AND DIRECTION POPULATION

(AS PER CENSUS OF INDIA 2011)

Kalanji 0.1 KM – N 260

Kattupalli 2.0 KM – SW 1911

Karungali 3.5 KM – N 203

Minjur Town 8.2 KM – SW 28337

5.3 LAND USE PLANNING (BREAKUP ALONG WITH GREENBELT ETC):

The details of land use planning for the project have been furnished in chapter -

III. Landscaping of the entire plant area shall be done. Trees for formation of green belt

around 50-meter-wide around the plant site will be suitably chosen. Special landscaping

shall be made around the technical buildings, main entrance of Power House and

Administrative building. Plantation of green belt shall commence at appropriate time, so

that green belt is sufficiently developed during the time of commissioning of the project.

5.4 ASSESSMENT OF INFRASTRUCTURE DEMAND (PHYSICAL & SOCIAL): Power evacuation from the plant will be through double circuit 400 KV lines for a distance

of 32 KM to link with power grid substation at Sriperumbudur.

RLNG pipe line from IOCL LNG terminal at Ennore port to the plant site for a distance of

6.0 Km will be laid by IOCL.



35

CHAPTER – VI

PROPOSED INFRASTRUCTURE

6.1 Industrial area: Lots of industrial activities are happening in the area and there is good demand

for the land.

6.2 Residential area (Non-Processing area):

No residential area is proposed within the Power Plant Area.

6.3 Green belt:

Landscaping of the entire plant area shall be done. Trees for formation of green

belt around 50-meter-wide around the plant site will be suitably chosen. Special and

scaping shall be made around the technical buildings, main entrance of Power House

and Administrative building. Plantation of green belt shall commence at appropriate time,

so that green belt is sufficiently developed during the time of commissioning of the project.

About 53 Acres of land is proposed for green belt in the power plant area.

6.4 Social Infrastructure:

The availability of land, proximity of water, evacuation of power through PGCIL,

feasibility of gas linkage from upcoming RLNG terminal of IOCL at Ennore Port and

availability of other infrastructure facilities in the vicinity of proposed plant.

6.6 Drinking water Management (Source & Supply of water):

Already given in Chapter 3, para number 3.5.17

6.7 Sewerage sytem: A permanent sewage treatment plant will be provided to cater to the sewage

discharge of the plant area. The treatment plant shall be so designed as to meet the

requirements of applicable local bye-laws / pollution standards and conditions as

stipulated by the State / Central agencies while according environmental clearance to the

project.

6.8 Industrial Waste Management:

Already given in Chapter 3, para number 3.9

6.9 Solid waste Management:

Already given in Chapter 3, para number 3.9

6.10 Power Requirement & Supply / Source: The power required for operating the power plant will be met from the Power

generated in the plant itself. The auxiliary power consumption will be within the range of 3

to 3.5% of the plant capacity.



36

CHAPTER – VII

REHABILITATION AND RESETTLEMENT PLAN (R&R PLAN)

7.1 POLICY TO BE ADOPTED (CENTRAL/STATE) IN RESPECT OF THE PROJECT OUSTEES, LAND OUSTEES AND LANDLESS LABORERS (A BRIEF OUTLINE TO BE GIVEN) The plant is proposed to be located in a total extent of 175.08 acres of land in that

153.08 acres is proposed for the Main Plant and 22 acres of (Part of land in CRZ area III)

is proposed for Pipe Corridor Area. Out of total plant area of 175.08 acres of land, in that

56 acres of land are owned by proponent.

The entire lease area is a non-forest private land without any habitation. As such

no home oustees are involved.

Land is mostly sea side waste lands only. No agricultural land is involved. However,

since lot of industrial activities are happening in the area, there is good demand & market

for the land.



37

CHAPTER – VIII

PROJECT SCHEDULE AND COST ESTIMATES

8.1 LIKELY DATE OF START OF CONSTRUCTION AND LIKELY DATE OF COMPLETION (TIME SCHEDULE FOR THE PROJECT TO BE GIVEN)

The Developer has conducted Plant Location studies, had initial discussions with

equipment manufacturers, suppliers, vendors, contractors, power purchasers and

industry professionals. The supply, erection, testing and commissioning will be contracted

out to the EPC Contractor.

The stages of implementation include:

Pre-construction phase

Construction Phase

Operation & Maintenance Phase

Project and Site Management

PROJECT SCHEDULE:

The construction period has been estimated as 30 months from the zero date

reckoned as the date of financial closure and Notice to Proceed (NTP):

Pre-construction and approvals – 10 months prior to NTP

Notice to Proceed – 0 month

Commissioning of 1st Module – 24 Months

Commissioning of complete plant in combined cycle mode (Both Modules) – 30

Months

8.2 ESTIMATED PROJECT COST ALONG WITH ANALYSIS IN TERMS OF ECONOMIC VIABILITY OF THE PROJECT:

The Project Cost is estimated at US $ 825.16 million (Rs. 53635.4 Million @ Rs 65

Per $),, indicating a per MW all-in cost of about US $0.83 million for a 1050 MW Plant.

The Project is proposed to be financed at a debt to equity ratio of 70:30, corresponding to

US $ 247.55 million in equity and US $ 577.61 million in debt



38

CHAPTER – IX

ANALYSIS OF PROPOSAL

(FINAL RECOMMENDATIONS)

9.1 FINANCIAL AND SOCIAL BENEFITS WITH SPECIAL EMPHASIS ON THE BENEFIT TO THE LOCAL PEOPLE INCLUDING TRIBAL POPULATION, IF ANY, IN THE AREA: Social and Financial benefits:

The requirement of skilled/unskilled persons will be met from nearby villages during

construction phase in addition to some regular employment during the operation of the

plant. The Project will also help in generation of significant indirect employment. This will

have positive socio-economic development in the region. There will be in general

upliftment of standard of living of the people in the region/ neighbourhood.

Conclusion:

The proposal for setting up a 1050 MW Combined Cycle power plant in Thiruvallur

by M/s Chennai Power Generation Limited is an effort to tide over the power shortage in

the Tamil Nadu State. Combined Cycle Power Plant (CCPP) Power Plants with short

gestation periods are significant contributors to bridge the demand – supply gap. Within

30 months, full-fledged operation in combined cycle mode shall be achieved. Hence, the

proposal to install a Combined Cycle Power Plant (CCPP) Power Plant having an output

1050 MW at Thiruvallur in Tamil Nadu is viable and well justified.

.* * * * * * * *



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Annexure 1

Previous Terms of Reference approved by MOEF for imported coal based

power plant



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Annexure 2

Heads of Agreement Between IOCL and Chennai Power Generation LTD



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Annexure 3

MOU signed Between IOCL and Chennai Power Generation LTD



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Annexure 4

Land Survey Number details for Project Site

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