maharashtra state power generation co ltd feasibility ... state power generation co ltd feasibility...

Maharashtra State Power Generation

Co Ltd

FEASIBILITY REPORT

1 x 800 MW Ultra Super Critical Thermal Power Project

Pit Head coal TPP at Umred Coal Mine area village – Heoti , Tahsil – Umrer , District - Nagpur, Maharashtra

March 2018

FE

AS

IBIL

ITY

RE

PO

RT

Maharashtra State Power Generation Co Ltd

Feasibility Report

1

1.0

INDEX Executive Summary ....................................................................................................

1-6

1.1 Introduction 1-6

1.2 Site Location and area 1-7

1.3 Access to Site 1-7

1.4 Meteorological Data 1-7

1.5 Coal Source 1-7

1.6 Water 1-9

1.7 Technology Selection 1-9

1.8 Unit size and Plant Configuration 1-10

1.9 Power Evacuation 1-10

1.10 Environment 1-10

1.11 Project Completion Schedule 1-12

1.12 TechnIcal Evaluation 1-13

1.13 Conclusion .......................................................................................................... 1-13

2.0 Basis of Report ............................................................................................................ 2-17

2.1 Unit Size and Plant Configuration .................................................................... 2-17

2.2 Site (Land) ........................................................................................................ 2-17

2.3 Water ................................................................................................................ 2-17

2.4 Fuel ................................................................................................................. 2-17

2.5 Inputs ............................................................................................................... 2-17

3.0 Need for the Project .................................................................................................... 3-20

3.1 Introduction ...................................................................................................... 3-20

3.2 Present Power Sector Position in India ............................................................ 3-20

3.3 Power Supply and Demand Position in Maharashtra ....................................... 3-22

3.4 Replacement Plan In Maharashtra ................................................................... 3-24

3.5 Justification for the Project ............................................................................... 3-25

4.0 Technology Selection ................................................................................................. 4-29

4.1 Power Plant Technology .................................................................................. 4-29

4.2 Conclusion on Technology Selection ............................................................... 4-36

5.0 Project Site, Land, Water, Fuel Requirements and Power Evacuation .................. 5-39

5.1 Project site ....................................................................................................... 5-39

5.2 Land ................................................................................................................. 5-40


Feasibility Report

2

5.3 Overall Layout Planning and Plant Location .................................................... 5-43

5.4 Water ............................................................................................. 5-44

5.5 Fuel ............................................................................................... 5-46

5.6 Power Evacuation ......................................................................... 5-47

6.0 Socio Economic and Environmental Aspects ........................................ 6-51

6.1 Socio Economic Profile and Development .................................... 6-51

6.2 Environmental Protection .............................................................. 6-51

6.3 Ash Generation, Utilisation and Disposal ..................................... 6-60

6.4 Green Belt ..................................................................................... 6-61

6.5 Conclusion .................................................................................... 6-61

7.0 Project Execution ...................................................................................... 7-64

7.1 Method of Executing the Project ................................................... 7-64

7.2 Project Completion Schedule ........................................................ 7-64

7.3 Logistics of Heavy Equipments ..................................................... 7-64

64 7.4 Project Development Requirements.............................................. 7-64

8.0 Project Cost and Cost of Generation ...................................................... 8-68

8.1 General ......................................................................................... 8-68

8.2 Basis for Project Cost .................................................................... 8-68

8.3 Basis of Fixed Charge ................................................................... 8-68

8.4 Basis of Variable Charge............................................................... 8-69

8.5 Project Cost Estimate (CAPEX) .................................................... 8-69

8.6 Fixed Charge, Variable Charge and Cost of Generation............... 8-70

9.0 Analysis and Conclusion ......................................................................... 9-73

9.1 Comparative Analysis ................................................................... 9-73

9.2 Analysis and Observations ........................................................... 9-73

9.3 Analysis of Project Cost and Cost of Generation .......................... 9-74

9.4 Conclusion .................................................................................... 9-75


Feasibility Report

3

List of Appendices

Appendix - 1 Key Features of the Project Site

Appendix - 2 Landed Fuel Cost at site for Indian Coal

Appendix - 3 Coal Analysis

Appendix - 4 Coal Generation in WCL Umred Coal Mine

Appendix - 5 Coal Balance Scenario

List of Exhibit

Exhibit - 1 Key Plan

Exhibit - 2 Typical HMBD for 1 x 800 MW with Supercritical Parameters

Exhibit - 3 Site grade in Plot area


Feasibility Report

4

1 Executive Summary


Feasibility Report

5

Table of Contents

1.0 Executive Summary .......................................................................................

1.1 Introduction ............................................................................................. 1-6

1.2 Site Location and area ............................................................................ 1-7

1.3 Access to Site .................................................................................... 1-7

1.4 Meteorological Data ............................................................................ 1-7

1.5 Coal Source........................................................................................ 1-7

1.6 Water ............................................................................................. 1-9

1.7 Technology Selection ......................................................................... 1-9

1.8 Unit size and Plant Configuration ........................................................... 1-10

1.9 Power Evacuation .............................................................................. 1-10

1.10 Environment ....................................................................................... 1-10

1.11 Project Completion Schedule ................................................................. 1-12

1.12 TechnIcal Evaluation .......................................................................... 1-13

1.13 Conclusion ......................................................................................... 1-13


Feasibility Report

6

1.0 EXECUTIVE SUMMARY

1.1 INTRODUCTION

Maharashtra State Power Generation Co Ltd. (hereinafter referred to as “The Company”)

has been incorporated under Indian Companies Act 1956 pursuant to decision of Govt. of

Maharashtra to reorganize Erstwhile Maharashtra State Electricity Board (herein after

referred to as “MSEB”). The said reorganization of the MSEB has been done by Govt. of

Maharashtra pursuant to Part XIII read with section 131 of The Electricity Act 2003.

MAHAGENCO has been incorporated on 31.05.2005 with The Registrar of Companies,

Maharashtra, Mumbai and has obtained Certificate of Commencement of Business on

15.09.2005. MAHAGENCO is engaged in the business of generation and supply of Electricity

and has been vested with generation assets, interest in property, rights and liabilities of MSEB

as per Gazette Notification dated 4th June 2005 issued by Industry, Energy and Labour Dept.

of Govt of Maharashtra pursuant to section 131 of Electricity Act 2003.

MAHAGENCO having generation capacity of 11657 MW comprising 8220 MW thermal, 2585

MW hydel, 672 MW gas turbine and 180 MW solar; was established by Government of

Maharashtra under the Electricity Act-2003 with the principal objective of engaging in the

business of generation of electricity.

Government of India is planning to replace old underperforming units with modernised high

efficiency thermal plants. MAHAGENCO is operating Thermal Power Plant with capacities

ranging from 210 MW to 660 MW in Maharashtra. The plants uses Indian Coal sourced from

various mines in Mahanadi Coal Field, Western Coal Field and South Eastern Coal fields.

MAHAGECO has an installed capacity of 1260 MW of thermal plants which are older than 35

years. MAHAGENCO are considering to replace some of the older plants with high efficiency

and higher capacity plants.

Maharashtra State Generation Company Limited (MAHAGENCO) is planning to set up

1 x 800 MW pit head coal based thermal power project at Umred WCL coal mine area,

near Nagpur in Maharashtra. Fichtner Consulting Engineers (India) Private Limited (FI)

have been appointed by MAHAGENCO as their Consultant to conduct Feasibility Study to

establish a plant of a configuration of 1 x 800 MW project and preparation of DPR for the

final selected plant configuration. This report provides the finding of the feasibility study.


Feasibility Report

7

The objective of this Feasibility Study is to assess the available land, its suitability for the

proposed configuration options and suggest the most suitable configuration for the proposed

Power Plant considering the fuel availability, water availability and power evacuation facilities.

Based on the site visits, discussion held with MAHGENCO and the inputs collected, a

comparative study of the different configurations for the proposed thermal power plant in

respect of techno-commercial aspects was carried out.

The salient aspects of the study are summarized as below:

1.2 SITE LOCATION AND AREA

The proposed site is located in Umed coal mine of WCL, in village Heoti in Umrer Tahsil,

Nagpur Dist, Maharashtra. The proposed site is mined area which was back filled over a

period 30 years. There is no village/habitations located inside the proposed site area. The

land terrain with variations of upto 30 meters is seen in the proposed area. The available

areas measures approximately 475 acres and the exact availability of area and the contour

shall be ascertained by topographic survey. The identified site will be taken on long lease

from WCL and no land acquisition is required for the main power plant facilities including ash

pond. The township will also be located adjacent to the existing WCL township area.

However right of way needs to established for conveying the treated waste water from NMC

and river water from Goshikurd dam to proposed power plant.

1.3 ACCESS TO SITE

The Major State Highway (MSH-9) is 5 km away on the eastern side of the proposed site.

The existing railway station at Umred is 6 km from the proposed site. The nearest airport is

Nagpur which is located at 42 km away from the proposed site. The nearest harbor is

Mumbai which is located at 850 km from away from the proposed site on western side.

1.4 METEOROLOGICAL DATA

The Project Information and Meteorological Data are given in Appendix-1.

1.5 COAL SOURCE

The proposed project is a pit head power project located in Umred coal mines. WCL have

confirmed for supply of coal for the proposed project. Coal from the Umred coal mines of

WCL will be the source for the proposed power plant. The grade of coal to be considered for

the project is in the range of 3000 – 3400 Kcal/kg, typical coal analysis is given in Appendix

3. The annual coal requirement considering the GCV of 3400 Kcal/kg for 1 x 800 MW at

85% PLF are as follows :


Feasibility Report

8

Table 1.1: Annual Coal Consumption considering GCV of 3400 kcal/kg

Sl.

No. Description Unit

Plant Configuration

1x800MW

1 Turbine cycle heat rate kcal/kWh 1746.6

2 Boiler efficiency % 87

3 Station Heat Rate (Design)

kcal/kWh 2008

4

Station Heat Rate (Weighted Average, considering the factor as per CERC)

kcal/kWh 2098

5 Coal consumption TPH 494

TPD 11847

6 Annual Coal

consumption

Million

TPA 3.68

The annual coal requirement considering the worst coal GCV of 3000 Kcal/kg for

1 x 800 MW is 4.17 Million tonnes per annum at 85% PLF

The yearly target production of coal in WCL Umred area is tabulated here

under: Table 1.2: Yearly Production of Coal in WCL Umred area

Name of

Mine

Total

reserve of coal

in MMT

Nominal Capacity

in MT

Mine

Operation

starting date Life up

to Year

Tentative Target in MTY

2017-18 2018-19 2019-20

Dinesh 87.36 4.0 Oct 2016 2040 2.6 3.5 3.75

Umrer 20.58 2.0 April 2016 2021 3.15 3.1 3.2

MKD-I 34.68 2.0 Dec 2014 2032 1.65 1.7 2

Gokul 15.30 1.5 May 2015 2025 1.65 1.8 1.8

Total 157.92 9.5 9.05 10.10 10.75

Dinesh coal mine is planned to be allocated for the proposed power plant, Dinesh mine has

started its coal mining from October 2016 onwards and the total reserve of this coal mine is

around 87.36 MT. Based on the above projected production targets for Umred coal mines

table, it can be observed that around 3.5 - 4.0 million tones per annum can be considered for

the proposed power plant. It is also seen from the coal balance scenario of WCL presented

as Appendix 5 of this report, the coal available in excess to the already committed supplies is

in the range of about 2.5 million tonnes per annum from the year 2021 – 22 onwards.


Feasibility Report

9

For 1 x 800 MW coal is available considering 4.0 million tones as annual generation .

Mahagenco shall take a confirmation from WCL for supply of coal for a period of 25 years

with necessary allocation from WCL Umred mines by readjusting the coal supply to other

consumers of WCL Umred mines

1 .6 W ATER

Based on the MOEF draft Notification released on October 2017, all the new plants to be

installed after 1st January 2017 shall have to meet specific water consumption upto maximum

3 m3/MWh. Based on this consideration, the proposed power project would require water of

around 17.87 Million cubic meter.

The available sources of water for the plant are viz Treated waste water from Nagpur

Municipal Corporation (NMC) and River water from Goshikhurd dam. The treated waste water

from NMC will have to sourced from Nagpur which is located at a distance of around 45 km.

The Goshikhurd dam is located at a distance of around 56 km from the proposed site.

Water conservation point of view treated waste water from NMC would be a better option

instead of utilising the natural resources, hence treated waste water would be considered as

the primary source.

Presently Nagpur municipality corporation (NMC) is supplying 130 MLD of treated waste

water to MAHAGENCO STP at Bhadaewadi, which is used for CW cooling, ash handling coal

washeries etc., for Power generation at Koradi Thermal power station. NMC is augmenting

the existing 100 MLD STP at Bhandewadi to 200 MLD capacity, the augmentation work is

likely to completed by Dec 2018.

Availability of 28 MCM per annum is confirmed by NMC through a consent letter. As an

alternative, Mahagenco has taken a consent for about 28 million cubic meter from Chief

engineer Irrigation Goshikhurd project for use of river water for the proposed plant.

1.7 TECHNOLOGY SELECTION

Supercritical and Ultra supercritical Technology and steam parameters are now being

considered in India due to higher thermal efficiency and resulting reduction in power plant

emissions. Efficiency gains, worldwide references and the suppliers have been considered in

evaluating both these technologies and USC technology is recommended for the proposed

project.


Feasibility Report

10

1.8 UNIT SIZE AND PLANT CONFIGURATION

The report consider plant configuration 1 x 800 MW for the proposed power project.

The various requirements for the above configurations in terms of land requirement, coal

consumption and water consumption and power evacuation have been studied for arriving at

an optimized configuration.

1.9 POWER EVACUATION

In the vicinity of proposed power plant, at a distance of 20 km (near Bhivad), a 400 kV single

circuit transmission line connecting Khaperkeda and Chandrapur is available which is

operated by MSETCL. This line has twin moose ACSR conductor, which has Surge

Impedance Load (SIL) loading capacity of 517 MW. By making Line In Line Out (LILO)

arrangement of this line at Bhivad and further laying 20 kM 400 kV double circuit transmission

line up to Umred power plant site, Power evacuation network can be established. Through

this arrangement about 1034 MW power can be evacuated and is subject to validation

through Load flow study of the transmission network by MSETCL.

For evacuation of power beyond 1034 MW, additional transmission lines need to be planned

to evacuate the power.

Further, In the State Transmission Utility(STU) 5 year transmission plan (2016-17 to 2021-

22), MSETCL have envisaged new transmission lines and substations including

augmentation in the Nagpur region. As the proposed power plant will be ready only by end of

2021-22, MSETCL can be requested to consider suitable evacuation plan from Umred Power

plant to MSETCL grid substations or through Central Transmission Utility (CTU) network in

coordination with PGCIL.

1.10 ENVIRONMENT

Ministry of Environment, Forest and Climate Change, Government of India issued Gazette

notification on 7th December 2015 amending Environment (Protection) Rules, 1986. Amended

rules will be called Environment (Protection) Amendment Rule, 2015 and subsequently MOEF

issued draft Environment (Protection) Amendment Rules, 2017.

Emission standards for Thermal Power Plants as per Ministry of Environment, Forest and

Climate Change are given below:


Feasibility Report

11

Table 1.3 : Emission Standards as per MOEF

Sr.No. Industry Parameter Standards

1 2 3 4

“5A.

Thermal

Power plant

(Water

consumption

limit)

Water consumption

1. All Plants with Once Through Cooling

(OTC) shall install Cooling Tower (CT)

and achieve specific water

consumption upto maximum of 3.5

m3/MWh with in a period of two years

from the date of publication of this

notification.

2. All existing CT -based plants reduce specific water consumption upto maximum of 3.5 m3/MWh MW with in a period of two years from the date of publication of this notification.

3. New plants to be installed after 1st

January, 2017 shall have to meet

specific water consumption upto

maximum of 3 m3/MWh and achieve

zero water discharged.

“25. Thermal

Power Plants TPPs (units) installed before 31st December, 2003*

Particulate Matter 100 mg/Nm3

Sulphur Dioxide(SO2)

600 mg/Nm3 (Units Smaller than 500MW

capacity units)

200 mg/Nm3 (for units having capacity

of 500 MW and above)

Oxides of Nitrogen(NOx) 600 mg/Nm

3

Mercury(Hg)

0.03 mg/Nm3 (for units having capacity


TPPs (units) installed after 1st

January,2003, upto 31st

December, 2016*


Sulphur

Dioxide(SO2)

600 mg/Nm3 (Units Smaller than 500

MW capacity units)

200 mg/Nm3 (for units having capacity


Oxides of Nitrogen

(NOx) 300 mg/Nm3

Mercury(Hg) 0.03 mg/Nm3


Feasibility Report

12


1 2 3 4

TPPs(units) to be installed from 1stJanuary, 2017**


Sulphur

Dioxide(SO2) 100 mg/Nm

3

Oxides of

Nitrogen(NOx) 100 mg/Nm

3


The above notification is effective from 7th December 2015. As per the new rules all thermal

power plant units, which are to be installed from 1st January 2017 shall meet the following

emission standards. The proposed power plant will be designed to meet the new

environmental norms by MOEF.

Table 1.4 : Emission Standards

Parameters Unit Standard

Particulate matter mg/Nm3 30

Sulphur Dioxide (SO2) mg/Nm3 100

Oxides of Nitrogen (NOX) mg/Nm3 100

Mercury (Hg) mg/Nm3 0.03

Also as per the new draft rules the proposed power plant will be designed to meet the specific

water consumption of 3 m3/MWh and achieve zero water discharge.

1.11 PROJECT COMPLETION SCHEDULE

The project completion schedule will depend on unit configuration and number of units. The

project schedule for configuration is as below :

1x 800 MW

Forty two (42) months for COD of the unit from the date of letter of Award (LOA) for EPC

contract.


Feasibility Report

13

1.12 TECHNICAL EVALUATION

In order to decide the best suited configuration from among the three proposed

configurations, a technical evaluation was carried out.

The following factors were considered as the basis for the technical evaluation:

- Extent of Land

- Availability of coal for the full life of plant

- Availability of water

- Power evacuation constraints

The technical comparison is presented below :

Description Unit 1 x 800 MW

1

2

3

4

Land

Water consumption per annum

Coal consumption per annum

Power evacuation

Acers

M Cubic Meter

Million tonnes

499

17.87

3.68

20 kM of 400 kV Double

circuit up to LILO to be considered

1.13 CONCLUSION

Feasibility study was carried out to establish the configuration considering Land, Water, Fuel

and Power evacuation for 1 x 800 MW inside the Umred coal mine.

From the techno economic evaluation, it can be seen that land availability, coal and Water

requirement are met for 1 x 800 MW TPP. The Power evacuation is also not a constraint for

1x 800 MW TPP.

Considering the limitation imposed by coal availability it is suggested that a plant configuration

of 1 x 800 MW can be adopted for the proposed project. Mahagenco shall take a confirmation

from WCL for supply of 4.17 tonnes per annum considering the Worst Coal GCV of


Feasibility Report

14

3000 Kcal/kg for a period of 25 years with necessary allocation of coal from WCL Umred

mines by readjusting the coal to other consumers of WCL Umred Mines.

Proposed power project is being planned as a pit head station within the existing WCL mine

area. No additional land is required to be acquired for this proposed project. Necessary

infrastructure facilities are already available. Considering the projected future power supply

and demand scenario installing a Power Plant of 1 x 800 MW capacity at Umred mine area

with assured water supply, all existing infrastructure is considered to be techno economically

viable.

Project cost and Cost of generation is highlighted hereunder for the selected configuration of

1 x 800 MW :

Description Unit 1 x 800 MW

Project Cost Rs.Crs/MW 7.52

Cost of generation

- Fixed cost Rs./kWh 1.98

- Energy cost Rs./kWh 1.17

- Cost of Generation (First Year) Rs./kWh 3.15

- Levelised Tariff for 25 Years Rs./kWh 3.05

- Levelised Tariff for 30 Years Rs./kWh 3.08

- Payback Years 17


Feasibility Report

15

2 Basis of Report


Feasibility Report

16

Table of Contents

2.0 Basis of Report ..................................................................................................... 2-17

2.1 Unit Size and Plant Configuration ........................................................... 2-17

2.2 Site (Land) ................................................................................................ 2-17

2.3 Water ........................................................................................................ 2-17

2.4 Fuel .......................................................................................................... 2-17

2.5 Inputs ........................................................................................................ 2-17


Feasibility Report

17

2.0 BASIS OF REPORT

2.1 UNIT SIZE AND PLANT CONFIGURATION

MAHAGENCO proposed Unit size and plant configurations 1 x 800 MW for the feasibility

of the proposed power project.

2.2 SITE (LAND)

For the feasibility study, MAHAGENCO have proposed the land area inside the Umred coal

mine, which is located in the village Heoti in Umrer Tahsil, Nagpur Dist, Maharashtra.

2 . 3 W A T E R

The required plant water for the proposed plant will be the treated waste water from Nagpur

city which is at distance of 45 km. As an alternate, the water from the Goshikhurd dam at a

distance of nearly 56 km is also considered. Water Source and Requirement is further

detailed in Section 5.0.

2.4 FUEL

The site is located inside the Umred coal mine of Western coal fields. Umred mine area

have four mines viz Dinesh, Umrer, Makaradhura 1 and Gokul Based on the discussion with

WCL and the data collected, 100% coal will be sourced from the Umred coal mines of WCL.

Coal source and coal analysis is further detailed in Section 5.0.

2.5 INPUTS

The basis of the study is carried out based on the following inputs collected during kick off

meeting and site visit.

1. Minutes of meeting between Mahagenco and FI is furnished in Annexure - 1

2. Mahagenco letter for Inputs - Land and Water is furnished in Annexure - 2

3. Mahagenco letter regarding Power evacuation is furnished in Annexure - 3

4. Letter for Water Availability is furnished in Annexure - 4

5. Letter from WCL is furnished in Annexure - 5

6. Letter from MAHAGENCO on Replacement plan of old units is furnished in Annexure – 6

7. Geotechnical report is furnished in Annexure - 7

8. STP outlet water analysis is furnished in Annexure -8

9. Coal analysis is furnished in Annexure - 9


Feasibility Report

18

3 Need for the Project


Feasibility Report

19

Table of Contents

3.0 Need for the Project ............................................................................................. 3-20

3.1 Introduction ............................................................................................... 3-20

3.2 Present Power Sector Position in India .................................................... 3-20

3.3 Power Supply and Demand Position in Maharashtra ............................... 3-22

3.4 Replacement Plan In Maharashtra ........................................................... 3-24

3.5 Justification for the Project ....................................................................... 3-25


Feasibility Report

20

3.0 NEED FOR THE PROJECT

3.1 INTRODUCTION

The power demand in our country is increasing rapidly due to rapid industrial and

infrastructure developments. Lack of availability of sufficient electric power has always been

one of the greatest deterrents to the growth of industry in the state. Government of India is

planning to build last mile connectivity to the rural landscape of the country which will

enhance the power demand.

To meet the increasing power demand and to Generate power at cost lower than the average

cost of power generation, Maharashtra State Power Generation Co Ltd (MAHAGENCO) is

planning to set up thermal power project In Umred Western Coal Mine area as a pit head

project, the plant capacity will be 1 x 800 MW .

3.2 PRESENT POWER SECTOR POSITION IN INDIA

Over the years, the Electricity Industry has made significant progress, Installed capacity

increased from 288664.97MW (Feb, 2016) to 330260 MW (May, 2017). Annual per capita

electrical energy consumption is increased to over 1075 kWh (2015-16).

Table 3.1 : Installed Capacity in India

Type Installed Capacity (MW)

Hydro 44594.42

Coal 195602.88

Gas 25185.38

Diesel 837.63

Nuclear 6780

Renewable 57260.23*

Total 330260.53

* - Renewable installed capacity as on 31-12-2016

Source: Central Electricity Authority-31-05 2017


Feasibility Report

21

All the three sectors namely Central, State and Private contribute to the availability of power

in the country. States sector owns a share of about 32% (104303.28 MW), central sector

owns a share of about 24% (81167.25 MW) of installed capacity and the rest by private

sector i.e. 44% (144790.01 MW). Major contribution of energy generation is from thermal

followed by hydel energy.

Peak power demand and peak power availability across India for the 11th and 12

th plan period

is presented below:


Feasibility Report

22

Table 3.2 : Actual Power and Energy Demand Vs Supply Position in India

Sl. No

Period

Peak Demand

(MW)

Peak Gen.

(MW)

Deficit (MW)

%

Deficit (-) /

Surplus(+)

Energy Requi- rement

(MU)

Energy Availa- bility (MU)

Energy Deficit

(MU)

% Deficit(-) /Surplus

(+)

1 2009-10 119166 104009 15157 -12.7 830594 746644 83950 -10.1

2 2010-11 122287 110256 12031 -9.8 861591 788355 73236 -8.5

3 2011-12 130006 116191 13815 -10.6 937199 857886 79313 -8.5

4 2012-13 135453 123294 12159 -9.0 995557 908652 86905 -8.7

5 2013-14 135918 129815 6103 -4.5 1002257 959829 42428 -4.2

6 2014-15 148166 141160 7006 -4.7 1068923 1030785 38138 -3.6

7 2015-16 153366 148463 4903 -3.2 929167 908663 20504 -2.2

8 2016-17* 165253 169503 -4250 +2.6 1214642 1227895 13252 +1.1

Source: Central Electricity Authority

* Anticipated power supply position

3.3 POWER SUPPLY AND DEMAND POSITION IN MAHARASHTRA

The power scenario i.e. installed capacity & actual power supply position in Maharashtra is

given below:

3.3.1 Overview of Western Region

Table 3.3 : Installed Capacity (MW) in Western Region

Sl. No Sector Thermal Nuclear Hydro

(Renewable) RES (MNRE) Total

1 State 25819.82 0.00 5480.50 311.19 31611.51

2 Private 37551.67 0.00 447.00 17993.27 55991.91

3 Central 17851.4 1840.00 1520.00 0.00 21211.54

4 Sub-total 81223.03 1840.00 7447.50 18304.43 108814.96

Source: Central Electricity Authority-31.05.2017

Table 3.4: Actual Power and Energy Supply Position in Western Region

Sl. No

Period Peak

Demand (MW)

Peak Gen. (MW)

Deficit (MW)

% Deficit

Energy Requi- rement (MU)

Energy Availa- bility (MU)

Energy Deficit (MU)

% Deficit

1 2012-2013 40075 39486 589 1.5 296475 286683 9792 3.3

2 2013-2014 41335 40331 1004 2.4 294659 291856 2803 1.0

3 2014-2015 44166 43145 1021 2.3 317367 314923 2444 0.8

4 2015-2016 48640 48199 441 0.9 346767 345967 800 0.2

5 2016-2017 48531 48313 218 0.4 345247 345127 120 0

Source : Central Electricity Authority


Feasibility Report

23

3.3.2 Maharashtra

Table 3.5 : Installed Capacity (MW) in Maharashtra

Sl. No.

Sector Thermal Nuclear Hydro

(Renewable) RES (MNRE) Total

1 State 11052.00 0.00 2884.84 208.12 14144.97

2 Private 12874.00 0.00 447.00 7439.47 20760.47

3 Central 6732.43 690.00 0.00 0.00 7422.43

4 Sub-Total 30658.43 690.00 3331.84 7647.60 42327.87

Source: Central Electricity Authority-31.05.2017

Table 3.6 : Actual Power and Energy Supply Position in Maharashtra

Sl. No

Period Peak Demand

(MW)

Peak Gen. (MW)

Deficit (MW)

% Deficit

Energy Requi- rement

(MU)

Energy Availability

(MU)

Energy Deficit (MU)

% Deficit

1. 2012-2013

17934 16765 1169 6.5 123984 119972 4012 3.2

2. 2013-2014

19276 17621 1655 8.6 126288 123672 2616 2.1

3. 2014-2015

20147 19804 343 1.7 134897 133078 1819 1.3

4. 2015-2016 20973 20594 379 1.8 141817 141361 456 0.3

5. 2016-2017 22516 22207 309 1.4 139294 139229 65 0.0

Source: Central Electricity Authority

As per the Government of Maharashtra proposal 14,400 MW capacity power projects

based on new and renewable energy sources are targeted and to be installed in the next

5 years in Maharashtra. The details of the projects are listed below:

5000 MW of Wind Power projects.

1000 MW of Bagasse -based Co-generation Projects

400 MW of Small Hydro Projects

300 MW of Biomass-based Power Projects

200 MW of Industrial Waste-based Power Projects

7500 MW of Solar Power Projects


Feasibility Report

24

3.3.3 Future Demand in Western Region

The future demand in the Western region upto 2021-22 as per the 19th Electrical Power

Survey is given below:

Table 3.7 : Future Demand in Western Region

Energy/Power Year Western Region India

Peak Demand (MW)

2016-17 50278 161437

2021-22 71124 222210

2026-27 94202 291084

Energy Requirement (MU) 2016-17 358580

1166590

2021-22 490013 1569400

2026-27 634822 2036227

Source : The demand forecast for the Western Region as per the 19th Electrical Power Survey, Govt. of India.

Projected future demand at the end of 12th plan and 13

th plan period indicates need for

capacity addition in western states.

Peak demand for western region during 2021-22 period is projected as 71124 MW which is

about 21000 MW more than the peak demand in 2016-17 period. Peak demand for All- India

during 2021-22 period is projected as 2, 22, 210 MW which is about 60000 MW more than

the peak demand in 2016-17 period.

India is now one of the rapidly growing economies in the world and electric power generation

capacity is central to achieving projected economic growth in the country. Rapid urbanization,

focus on infrastructure projects, expansion of manufacturing base and growth in income level

and quality of life would result in continuous increase in energy demand in the country and

specifically in western region.

3.4 REPLACEMENT PLAN IN MAHARASHTRA

Proposed Replacement Units Retiring Units & Status of the same,

Date for completion of 40 years of service

Bhusawal Unit #6

(660 MW)

Bhusawal #2 (210 MW) : Not in service, August 2019

Bhusawal #3 (210 MW) : In service, May 2022

Nashik #3 (210 MW) : In service, April 2019 (Retiring capacity 630 MW)


Feasibility Report

25

Proposed Replacement Units Retiring Units & Status of the same,

Date for completion of 40 years of service

Umred (1x 800 ) Shall be considered as a replacement

project of Ultra super critical technology

Nashik #4 (210 MW) : In service, July 2020

Nashik #5 (210 MW) : In service, Jan 2021

Koradi #5 (200 MW) : Not in service, July 2018

Koradi #7 (210 MW) : In service, Jan 2023

Parli #4 (210 MW) : Not In service, March 2025

Parli #5 (210 MW) : Not In service, Dec 2027

MAHAGENCO is planning to replace the older capacity plants with higher efficient and

higher capacity plants, the total capacity planned to be replaced is around 1880 MW.

3.5 JUSTIFICATION FOR THE PROJECT

a) To meet such increasing power demand as detailed above, power sector need to grow at

accelerated pace since there is a confirmed increase in demand in every five year period.

b) Government of India is planning to replace old underperforming units with modernised

high efficiency thermal plants.

c) As Maharashtra State is one of the most preferred state for industrialization, the industrial

demand for power will be ever increasing. Added to the industrial demand, the agriculture

need as well as domestic consumption coupled with the improved standard of living of

the population will be on the rise.

d) 19th power survey projects peak demand for Western region as 71124 MW in the year

2021-22, which is about 21000 MW more than the projected demand for the year 2016-

17.

e) The proposed projected capacity addition of power through renewable sources in Western

Region is around 54,010 MW (of which 28,140 MW is from Solar and 22,600 MW is from

Wind). Solar power is generated during sunny time and Wind power is seasonal

f) Though, Maharashtra state is planning to add 14,400 MW of power through renewable

sources in the next five years period, addition of pit head thermal power plant will cater to

the load demand during non sunny and non windy times. Also the thermal plant will

provide the necessary power for maintaining the load in the grid.


Feasibility Report

26

g) The proposed plant is also to be considered as a replacement for low efficiency existing

units of MAHAGENCO which are being phased out. This will also bring down the

CO2,SOx ,NOx SPM emission making it environment friendly.

h) Taking all these into consideration and Government of India vision for 24 x 7 for urban,

rural and remote areas through last mile connectivity to power starved areas,

establishment of the proposed Pit head power project is justified in all aspects.


Feasibility Report

27

4 Technology Selection


Feasibility Report

28

Table of Contents

4.0 Technology Selection .................................................................................... 4-29

4.1 Power Plant Technology ......................................................................... 4-29

4.2 Conclusion on Technology Selection ...................................................... 4-36


Feasibility Report

29

4.0 TECHNOLOGY SELECTION

4.1 POWER PLANT TECHNOLOGY

Higher steam pressure and temperature is one of the major factors contributing to efficiency

improvement for coal fired thermal power generation. Based on the steam conditions, coal

fired power generation is broadly classified as subcritical, supercritical and ultra-supercritical

technology.

Subcritical ( Main steam pressure below 224 kg/cm2)

Supercritical ( Main steam pressure above 224 kg/cm2)

Ultra Supercritical ( Main steam pressure above 224 kg/cm2, temperature >600 deg C)

In order to increase the thermodynamic cycle efficiency and resulting reduction in power plant

emissions including greenhouse gases, Coal fired power plants are now moving towards

Supercritical and Ultra supercritical steam parameters worldwide.

4.1.1 Sub-critical Units

Sub-critical conditions occur when the steam pressure is below 221.2 bar(a) where mixture of

steam and water co-exists. Typical steam pressures for sub critical units will be about 170

kg/cm2(a).

Subcritical power plant units in India operate at steam conditions 170 kg/cm2(a) main steam

pressure and at 540°C main steam and reheat steam parameters at turbine inlet.

4.1.2 Supercritical and Ultra supercritical Units

Supercritical conditions occur when the boiler steam pressure increases above the critical

pressure of 221.2 bar (a). Steam parameters for supercritical technology are generally

classified into two major groups - „Supercritical‟ and „Ultra supercritical‟.

a) Supercritical steam parameters:

Steam pressures up to 250 kg/cm2 (a) and Steam temperatures ranging from 538°C to

593°C at turbine inlet.

b) Ultra Supercritical steam parameters:

Steam pressures above 250 kg/cm2 (a) and steam temperatures ranging from 600°C to

620°C at turbine inlet.


Feasibility Report

30

4.1.3 Efficiency Gains

The following graph shows efficiency gains that can typically be achieved through the use of

higher steam pressures and temperatures on a single reheat cycle.

Figure 4.1: Curve for Efficiency Improvement

Other factors which affect the turbine cycle efficiency are the number of reheats (single or

double), the condenser pressure, single/dual condenser pressures, the number of feed water

heaters, pressure drops, inherent steam turbine efficiency etc.

4.1.4 Development of Supercritical/Ultra supercritical technology worldwide

Around mid to late 1980s, European countries and Japan embarked on a major program of

increasing the efficiency of the steam cycle with increased steam pressures/temperatures.

Need for reducing greenhouse gas emission and high cost of fuel were major drivers for

advancement in supercritical and ultra-supercritical pressures and temperatures for boiler

and turbine cycle.

Countries in Europe and Japan have adapted supercritical technology much earlier and have

further moved towards ultra-supercritical units with higher steam pressures and

temperatures. Significant improvement in steam conditions was mainly driven by the need for

reducing air pollutants and green house gas emissions.

Evolution of steam conditions from sub critical to supercritical happened in the last 30 years

and to ultra-supercritical parameters in the last 15 to 20 years. Many Large size Supercritical

and Ultra supercritical thermal power plants in the range of 660 MW to 1000 MW were

installed from 1995 onwards in Europe, Japan and China


Feasibility Report

31

Figure 4.2: Indicates the Evolution of SC and USC parameters

25 Mpa - 28 MPa/604°C/602°C

25 MPa/598°C/596°C

25 MPa/570°C/595°C

25 MPa/543°C/569°C

25 MPa/543°C/541°C

1985 1990 1995 2000 2005 2010

Fiscal year of Operation commencement

There are more than 600 Supercritical units operating in the world of varying Unit sizes.

Many Ultra Supercritical units of sizes between 600 MW and 1000 MW have also been

commissioned in Germany, Japan, Italy and USA in the past 10 to 15 years. Few Ultra

supercritical Units are under execution in China. These units adapted steam temperatures up

to 610°C.

SC/USC technology for thermal power generation could evolve successfully worldwide mainly

due to continuous research and development activities in US, Europe and Japan with regard

to materials for high temperature service with higher creep strength, advancements in

fabrication and manufacturing of high alloy ferritic and austenitic steel, improvement in Steam

turbine design and large size blades etc.

Suppliers of Supercritical/Ultra supercritical Units:

Suppliers for Supercritical / Ultra Supercritical Units are mainly from Europe, Japan, USA and

Korea.

Major OEMs from Europe are GE-Alstom and Siemens for both boilers & turbines and Hitachi

Babcock Borsig Power for boiler design. In Japan, MHI and Hitachi offer both boiler and

turbines; Toshiba offer only turbines; IHI only boilers. The major USA manufacturers also

offer supercritical / ultra supercritical boilers of a similar design to those offered by the

German and Japanese manufactures.

Recently Mitsubishi Hitachi Power Systems (MHPS) was established by merging thermal

power generation sectors of MHI Ltd and Hitachi Ltd in Feb 2014. Both the companies are

historically involved in the development of Boiler technology based on SC/USC steam

parameters.


Feasibility Report

32

Doosan from Korea offer supercritical Boilers and Turbines. Chinese manufacturers also offer

supercritical boilers under the licensees from European and Japanese manufacturers.

4.1.5 Supercritical experience in India

Post 2003, Government of India, Ministry of Power launched an initiative to facilitate

development of large size power plants with state-of- the art supercritical technology and

clean coal technology to accelerate pace of capacity addition in India. Thrust was given to

select higher unit sizes of capacity 660 MW, 800 MW and 1000 MW. Large capacity units

were required in the country to meet the power growth plan envisaged.

Supercritical steam parameters and technology were mandated in all the Ultra Mega Power

Projects (UMPP), which were launched during the period between 2006 and 2008 by Ministry

of Power & CEA through Special Purpose Vehicle (SPV). Subsequent period witnessed setting

up of many 660 MW and 800 MW Supercritical units by Central/ State/Private sector.

First 660 MW Supercritical Unit in India was commissioned in December 2010 by Adani

Power in Mundra, Gujarat. First 800 MW Supercritical Unit in India was commissioned in

2011 by Tata Power, also in Mundra, Gujarat as a part of 4000 MW UMPP.

Subsequently, National Thermal Power Corporation (NTPC) invited Bulk Tenders for 660 MW

units and 800 MW Units in 2 phases, totaling to 20 Supercritical Units. Localisation through

phased manufacturing program, transfer of technology and capacity building were

implemented through such bulk orders and competitive environment was created.

The above initiatives resulted in rapid capacity addition and adaption of supercritical

technology in India across the power sector industry.

11th Plan (2007-2012) witnessed commissioning of about 11 Supercritical Units of sizes

660/800 MW. 12th Plan (2012 – till 2015) witnessed commissioning of about 32 Supercritical

Units of sizes 660/700/800 MW. In addition to the above commissioned units, about 70

Supercritical Units are under various stages of execution.

Apart from BHEL, private sector firms such as L&T, JSW and Barath Forge formed JV

Company with OEMs from Japan and Europe to establish design, manufacture and execution

capabilities for Supercritical technology based Power Units in India. Doosan India and TBW

India has established facilities in India for supercritical Boiler through their Technology tie-up

with their respective parent company.


Feasibility Report

33

4.1.6 OEMs with manufacturing base in India for Supercritical units:

Table 4.1: OEM’s for Supercritical Units in India

Supplier Equipment Technology from

Country for Technology

Supplier

BHEL Boiler & Turbine GE-Alstom for Boiler Siemens for Turbine

France Germany

L&T MHI Boiler & Turbine MHPS for Boiler

MHPS for Turbine Japan

Toshiba JSW Turbine Toshiba Japan

Alstom Bharat

Forge Turbine GE-Alstom France

Doosan Boiler Doosan South Korea

TB&W Boiler Babcock & Wilcox USA

4.1.7 Ultra-Supercritical experience in India

First Ultra Supercritical thermal power project is initiated by NTPC in 2015 and the plant of

2 X 660 MW is being set up in Khargone, MP state with MHI technology, the total EPC is with

L&T and the project is under execution ,expected to be commissioned in 2019. The main

steam condition for this unit are 270 kg/cm2(a)/ 600°C/ 600°C.

4 x 1000 MW USC Power project, Pudimadakka, near Vishakhapatnam in AP state being

developed by NTPC is also under planning and design stage. The project was initially was

planned with 5000 GCV imported coal, which was subsequently changed to Indian coal. In

May 2017, NTPC was allotted a coal block at Ranigunj Coalfields for the plant.

Recently, BHEL has got the order from TANGEDCO for 2X660 MW Udangudi Thermal Power

Project and 2X800 MW Uppur Thermal Power Project. Both the plants are with ultra

supercritical technology.

4.1.8 Heat Rate improvement with Supercritical & Ultra Supercritical parameters

To determine the Steam conditions for the power cycle, potential increase in the cycle

efficiency gains at elevated steam pressures and temperatures needs to be considered. Plant

thermal efficiency and therefore environmental performance are enhanced by increasing

steam pressure and temperature.

Heat Rate improvement for supercritical/ultra supercritical steam parameters is presented in

Table 4.2.


Feasibility Report

34

Table 4.2 : Typical range of Turbine cycle heat rate for Supercritical (SC) / Ultra super critical (USC) parameters

Steam Conditions at Turbine inlet

(Pressure/ Steam Temperatures)

Cycle Heat rate (kCal/kWh)

(Note 1)

250 kg/cm2 (a)/ 565°C/ 565°C (SC) 1840 to 1860

250 kg/cm2 (a)/ 565°C/ 593°C (SC) 1810 to 1835

270 kg/cm2 (a)/ 600°C / 600°C C (USC) 1746 to 1800

Note 1 : Above Turbine cycle heat rates are considering turbine driven boiler feed

pump. 4.1.9 Environmental Benefit

Gains in efficiency will result in the environmental benefits, i.e. reduced specific coal

consumption and hence lower amount of CO2, NOx, SO2 and Mercury emission (Hg) per kWh

of power generated using efficient supercritical plants.

4.1.10 Steam Parameters for proposed 1x800 project

Supercritical (SC) technology and steam parameters are considered as the base case for

this feasibility study in order to have increased efficiency and to reduce the emissions per

kWh power generation. Steam parameters at steam turbine inlet for Supercritical 242 bar (a),

565/593°C.

Most of the leading OEMs are having proven design / operating experience with the above

parameters. Many utilities in India have started gaining operating experience with the

supercritical parameters. Proven materials for Boiler pressure parts, Critical piping, and

Steam turbine parts are available.

CERC/CEA have stipulated operating norms which requires turbine cycle heat rate of 1850

kCal/kWh with turbine driven boiler feed pumps and 1810 k Cal/kWh for motor driven boiler

feed pump. Most turbine suppliers can meet the above norms at 242 bar (a) steam pressure

with 565°C main steam and 593°C reheat steam temperatures.

As discussed in this report, Ultra supercritical (USC) technology and steam parameters, due

to higher pressure and temperature require use of high strength material for pressure parts. It

is expected that cost of USC unit will be relatively higher than SC Unit;

Ultra Supercritical technology:

Steam parameters for Ultra supercritical at Turbine inlet: Main steam pressure at 270 bar(a)

and Main steam / Reheat steam temperature at about 600 to 610˚C.


Feasibility Report

35

Many international OEM i.e. Hitachi, MHI, Alstom, Siemens and IHI have designed and built

USC thermal power plants worldwide and many USC plants of 700 MW/800 MW/ 1000 MW

sizes are in operation during the past 10 to 15 years.

For high pressure and high temperature conditions in USC boiler, it is necessary to select high

strength materials to reduce the wall thickness of pressure parts, resulting in low stresses. For

superheater and reheater in Boiler, high strength austenitic steel with higher creep strength at

elevated temperatures are used; High alloy ferritic pipe material is selected for main and

reheat steam piping. Similarly, for steam turbine design, many new concepts are introduced

such as selecting high temperature materials for turbine components, steam cooling

technology, high efficiency nozzle and blades, improving the Last stage blade design.

A heat & mass balance diagram for the above-mentioned configurations are furnished in

Exhibit – 5&6.

4.1.11 Techno-Economic Evaluation for SC & USC Technology

Following two (2) cases with regard to technology are considered for techno-economic

evaluation.

Case-1: 100 % Indian coal

1 x 800 MW Plant configuration

Ultra-supercritical parameters - 270kg/cm2(a)/600°C/600°C

Case-2: 100 % Indian coal

1 x 800 MW Plant configuration

Supercritical parameters - 247 kg/cm2(a)/565°C/593°C

S No Description Unit Case-1 Case-2

1 Plant configuration 1 x 800 MW 1 x 800 MW

2 Technology Ultra-supercritical Supercritical

3 Turbo generator capacity kW 800000 800000

4 GCV of coal kcal/kg 3400 3400

5 Plant load factor % 85 85

6 Turbine heat rate kcal/kWh 1746.6 1810

7 Boiler efficiency % 87 87

8 Plant heat rate kcal/kWh 2007.6 2080.5

9 Plant heat rate with 4.5% design margin

kcal/kWh 2097.9 2174.1


Feasibility Report

36


10 Specific coal consumption kg/kWh 0.6170 0.6394

11 Annual coal requirement Tons 36,75,569.13 38,08,988.97

12 Annual ash generation @ 42.45%

Tons 15,60,279.1 16,16,915.8

13 Excess coal consumption per annum

Tons - 1,33,419.83

14 Coal cost Rs/tonne 1623 1623

15 Coal cost escalation % 1.24 1.24

16 Plant Life Years 25 25

17 Discount rate % 11 11

18 Coal cost (NPV) for 25 years life due to additional coal consumption

Rs. In Crores

- 200

Life cycle cost for the SC & USC technology is presented below:


1 Project Cost Rs. In Crores 6019 5952

2 Coal cost (NPV) for 25 years life due to additional coal consumption

Rs. In Crores

- 200

3 Life Cycle Cost Rs. In Crores

6019 6152

4 Savings Rs. In Crores 133 -

Additional Benefits:

Since the specific coal consumption is lesser for USC technology as compared to SC

technology, additional benefits are as follows:

a. Reduction (approx. 5%) in Limestone & Ammonia consumption cost

b. Reduction in Annual Ash generation (i.e. 56,636.72 tons)

c. Reduction in CO2 emission will be around 1,80,000 tons per annum.

From the above, it can be observed that Ultra Super critical technology has an advantage

over Super critical technology.

4.2 CONCLUSION ON TECHNOLOGY SELECTION

Considering the factor of better heat rate, saving of fuel and reduction in emission Ultra super

critical technology is considered.


Feasibility Report

37

5 Project site, Land, Water, Fuel

Requirements & Power Evacuation


Feasibility Report

38

Table of Contents

5.0 Project Site, Land, Water, Fuel Requirements and Power Evacuation ... 5-39

5.1 Project site ........................................................................................ 5-39

5.2 Land .................................................................................................. 5-40

5.3 Overall Layout Planning and Plant Location ..................................... 5-43

5.4 Water ................................................................................................. 5-44

5.5 Fuel ................................................................................................... 5-46

5.6 Power Evacuation ............................................................................. 5-47


Feasibility Report

39

5.0 PROJECT SITE, LAND, WATER, FUEL REQUIREMENTS AND POWER EVACUATION

5.1 PROJECT SITE

The proposed site is located in Umred coal mine of WCL, in village Heoti in Umrer Tahsil,

Nagpur Dist., Maharashtra. The Major State Highway (MSH-9) is 5 km away on the eastern

side of the proposed site. The existing railway station at Umred is 6 km from the proposed

site. The nearest airport is Nagpur which is located at 42 km away from the proposed site.

The nearest harbor is Mumbai which is located at 850 km from away from the proposed site

on western side.


Feasibility Report

40


Feasibility Report

41

5.2 LAND

5.2.1 Current Usage and Topology

The proposed site is mined area which was back filled over a period 30 years. Presently the

site is having natural vegetation and trees. Soil dumped at this yard over a period of time has

a large variation of site contour level from 0 m to 30 m as observed from Google earth.

The proposed plant site is part of coal mine exploited & back filled long back, the depth and

nature of sub soil profile is unknown for dump or back filled material. Mahagenco has carried

out the Geo technical investigation which is attached as Annexure 7. Based on the report it is

noted that, the soil is basically a back filled soil with the low bearing capacity. Based on the soil

data provided by Mahagenco for the Umred site, pile foundation of 750 mm dia. (approx. 40m

depth) is considered for major structures and foundation system for cost estimation.

During project implementation stage, a detailed geo-technical investigation need to be carried

out to obtain all data necessary for finalising foundation system.

5.2.2 Extent of Land Requirement

Land requirement for 1 x 800 MW power plant configuration is worked out for Boiler Turbine

Generator (BTG) and Balance of Plant (BOP) system / equipment and other facilities required

within the power plant boundary and land required for ash pond, river water pipe corridor, etc.

as required.

Land requirement considering all facilities of power plant for 1 x 800 configuration is

summarized in the Table-5.1.

Table 5.1: Land Requirement Summary

[ Area in acres ]

Sl.No Facilities 1 x 800MW

1 Main power plant facilities

Power Block 60

Water system 42

Coal handling system 30

Non plant buildings 15

Green belt 49

Sub total of main power plant facilities 196


Feasibility Report

42

Sl.No Facilities 1 x 800MW

2 Ash pond

- Ash with 45 % 198

3 Corridors for treated waste water intake/ River water intake

90

4 Township 15

5 Total Area required 499

6 Area required /MW 0.62

7 Area required /MW for Pit

head plant as per CEA

0.67

Note

1. As per MOEF requirements, green belt area of 33% is considered inside power plant

boundary

2. Ash content of 45 % is considered for ash pond area sizing.

3. 45 km treated waste water intake/ River water intake for right of way is considered.

4. 0.77 Acres/MW is for 3 x 660 MW and 0.67 Acres /MW is for 4 x 800 MW as per CEA report.

Typical Plot Plan are presented for the above three plant configuration in Exhibit Nos. 2, 3

and 4.

5.2.3 Acquisition of Land and its Costs

The available areas measures approximately 475 acres and the exact availability shall be

ascertained by topographic survey. The identified site will be taken on long lease from WCL

and no land acquisition is required for the main power plant facilities including ash pond. The

township will also be located adjacent to the existing WCL township area. However right of

way needs to established for conveying the treated waste water from NMC/ River water

intake to the proposed power plant.

Around 500 acres is required for the main plant facilities and ash pond, depending on the

plant configuration. All the main plant facilities can be accommodated in the identified area,

additional area required for ash pond can be used in the adjoining area available near to the

identified site area.


Feasibility Report

43

Photograph of the proposed site

Index map of the proposed Site


Feasibility Report

44

5.3 OVERALL LAYOUT PLANNING AND PLANT LOCATION

The proposed site is located in the coal mine area. The identified area inside the coal mine

has river (part of coal mine area) on West and Southern side. A valley on the southern side of

the plot area because of the development of open cast mining. On the south eastern side of

the proposed plot area mining is progressing. The northern side of the proposed site is having

a railway line for the loading of coal in wagons to be transported from the mine area.

Considering these features available on the plot area, the plant layout has been conceived.

Site grading is planned in such a manner to optimise the cutting and filling and hence it is

proposed to have a terrace grading concept for BTG & BOP area.

BTG area and the cooling tower will be located at RL+289.00 on eastern side of dump area

by considering this level which is more than high flood level and other facilities like balance of

plant will be planned at RL+ 284.00 adjacent to BTG area in the western side. The coal stock

pile area is planned at RL + 282.0.

For the proposed power plant two entries are planned for plant entry, one is for main entry

and another is for material entry. Main entry to the plant will be planned in the north-west

corner of river and this access road is connected to Nagpur-Umrer state highway.

Material entry to the plant will be planned in the southern side of plant and this road is

connected to state highway in the southern side of plant. A Double lane bridge is required in

the southern side to connect material entry road to the state highway road.


Feasibility Report

45

AMB River runs around the proposed site. Earlier to expand coal mine, it was understood

that this river has been diverted from southern side by construction of check dam & made it

to flow on west & northern side. Since, this river lies in proposed power project area, it was

proposed to construct a check dam on north-west corner where the effective river width is

less.

Considering the proximity to site and its catchment details, it is suggested to use this north-

west portion of the river as the raw water reservoir for the proposed plant. Further a check

dam is proposed across the river on north-west side and south side with in the plant

boundary. The height of check dam shall be such that the minimum water requirement for the

plant is catered for, even during any future dry spell period. Average depth of 6 meter is

required to store the required water in reservoir within the plant boundary.

Raw water in-take pump house will be constructed at suitable location adjacent to river (raw

water reservoir) with due protections of the river banks on upstream as well downstream side.

Stone pitching is proposed along the sides of river bund. Embankment is proposed on both

sides of river bund to protect the stored water in the raw water reservoir.

For the purpose of storage of Treated waste water will be stored in a reservoir on the western

side of the plot area.

Considering river water as an alternate and additional source, the required water shall be

made available from Goshikhurd dam which is about 56 km from WCL Umrur area. Jack well

and In-take pump house will be proposed at Goshikhurd dam to discharge the required water

by buried pipe lines and it will be routed to the proposed plant by road. Necessary Box

culverts will be planned at the junction of road crossing of pipes wherever required.

Coal stock yard will be developed in the southern side of river and the eastern side of

proposed site will be used for power plant area as it happened to be higher level.

Ash pond is planned in the southern side of dump area which is lying at lower level of the

entire plant The ash pond will be developed in a phased manner ,necessary grading and

bund wall required for the ash pond will be developed.

A detailed Hydrology and Hydogeological study will be carried to evaluate the impact of

proposed TPP in and around water body.

5 . 4 W A T E R

5.4.1 Water Source and method of Intake

Based on the MOEF draft Notification released on October 2017, all the new plants to be

installed after 1st January 2017 shall have to meet specific water consumption upto maximum


Feasibility Report

46

3 m3/MWh. Based on this consideration, the proposed power project would require water of

around 17.87 Million cubic meter.


Feasibility Report

47

The available sources of water for the plant are viz Treated waste water from Nagpur

Municipal Corporation (NMC) and River water from Goshikhurd dam. The treated waste water

from NMC will have to sourced from Nagpur which is located at a distance of around 45 km.

The Goshikhurd dam is located at a distance of around 56 km from the proposed site.

Water conservation point of view Treated waste water from NMC would be a better option

instead of utilising the natural resources, hence Treated waste water would be considered as

the primary source.

Presently Nagpur municipality corporation (NMC) is supplying 130 MLD of treated waste

water to MAHAGENCO STP at Bhadaewadi, which is used for CW cooling, ash handling coal

washeries etc., for Power generation at Koradi Thermal power station. NMC is augmenting

the existing 100 MLD STP at Bhandewadi to 200 MLD capacity, the augmentation work is

likely to completed by Dec 2017. Availability of 28 MCM per annum is confirmed by NMC

through a consent letter. Right of way for waste water intake piping shall be obtained for the

proposed, which needs to be further explored during the execution stage.

As an alternative, Mahagenco has taken consent for about 28 million cubic meter from Chief

engineer Irrigation Goshikhurd project for use of river water for the proposed plant. For this

purpose existing river inside the plant shall be used as reservoir.

The River water intake piping shall be laid nearly 56 km from the Goshikhurd dam to the

proposed plant. Necessary Right of way for river intake piping shall be obtained for the

proposed, which needs to be further explored during the execution stage

Table 5.2 : Plant Water Intake Requirement

Description Unit 1x800MW

Total Water requirements(As per specific water consumption stipulated by MOEF)

M3/hr 2400

M3/day 57600

Annual Water consumption Million Cubic

meter 17.87

From the above table it can be observed that the availability of water is not a constraint,

primary water shall be sourced through treated water from NMC. Goshirkud dam is

considered as alternate source.


Feasibility Report

48

5.5 FUEL

5.5.1 Coal Source and Coal Analysis

The proposed project is a pit head power project located in Umred coal mine. WCL have

confirmed for supply of coal for the proposed project. Coal from the Umred coal mines of

WCL will be the source for the proposed power plant. Based on the discussion with WCL and

the data collected, 100 % coal will be sourced from the Umred coal mines of WCL.

The grade of coal for the project to be considered is G13 which has a calorific value of 3400

Kcal/kg. The distance from the coal mine to the proposed power project area is around 4.0

km, the coal from the mine area to plant shall be transported through conveyors.

The yearly target production of coal in WCL Umred area is tabulated hereunder :

Name of Mine

Total reserve of coal in MMT

Nominal Capacity

in MT

Mine Operation starting

date

Life up to Year


2017-18 2018-19 2019-20

Dinesh 87.36 4.0 Oct 2016 2040 2.6 3.5 3.75

Umrer 20.58 2.0 April 2016 2021 3.15 3.1 3.2

MKD-I 34.68 2.0 Dec 2014 2032 1.65 1.7 2

Gokul 15.30 1.5 May 2015 2025 1.65 1.8 1.8

Total 157.92 9.5

9.05 10.10 10.75

Dinesh coal mine is planned to be allocated for the proposed power plant, Dinesh mine has

started its coal mining from October 2016 onwards and the total reserve of this coal mine is

around 87.36 MT. Based on the above projected production targets for Umred coal mines

table, it can be observed that around 3.5 - 4.0 million tones per annum can be considered for

the proposed power plant. It is also seen from the coal balance scenario of WCL presented

as Appendix 5 of this report, the coal available in excess to the already committed supplies is

in the range of about 2.5 million tonnes per annum from the year 2021 – 22 onwards.


Feasibility Report

49

5.5.2 Annual Coal Requirement

Coal Requirements for 1X 800 MW with GCV of 3400 Kcal/kg is tabulated below:

Table 5.3: Annual Coal Consumption considering GCV of 3400 kcal/kg

Sl. No.

Description Unit 1x800MW

1 Turbine cycle heat rate kcal/kWh 1746.6

2 Boiler efficiency % 87

3 Station Heat Rate (Design)

kcal/kWh 2007.59

4

Station Heat Rate (Weighted Average, considering the factor as per CERC)

kcal/kWh 2098

5 Coal consumption TPH 494

TPD 11847

6 Annual Coal consumption (Note 1)

Million TPA

3.68

Note 1: Coal consumption is at 85% PLF.

The annual coal requirement considering the worst coal GCV of 3000 Kcal/kg for 1 x 800 MW

is 4.17 Million tonnes per annum at 85% PLF

Considering a GCV of 3400 Kcal/kg ,for 1 x 800 MW coal is available considering 4.0 million

tones as annual generation .

Mahagenco shall take a confirmation from WCL for supply of coal for a period of 25 years

with necessary allocation from WCL Umred mines by readjusting the coal supply to other

consumers of WCL Umred mines for 1 x 800 MW configuration considering that the project is

likely to commissioned in the year 2023.

5.6 POWER EVACUATION

1 X 800 MW Plant configuration

The total power generated from power plant will be about 800 MW. With minimum estimated

auxiliary power consumption of 42 MW (5.25%), the power available for evacuation will be

about 758 MW.


Feasibility Report

50

A 400 kV single circuit transmission line is presently operated by MSETCL between

Khaperkeda and Chandrapur. This line is passing at Bhivad, which is about 20 km distance

from the proposed Umred Site. It has twin moose ACSR conductor, which has SIL loading

capacity of 517 MW. By making Line IN Line Out (LILO) arrangement of this line for Umred

power plant site, about 1034 MW power can be evacuated. This proposal will involve

construction of 20 km long 400 kV double circuit transmission line from Umred power plant to

LILO point. This arrangement is subject to validation through Load flow study of the

transmission network by MSETCL.

In the State Transmission Utility (STU) 5 year transmission plan (2016-17 to 2021-22),

MSETCL have envisaged new transmission lines and substations including augmentation in

the Nagpur region. As the proposed power plant will be ready only by end of 2021-22,

MSETCL can be requested to consider suitable other evacuation plan from Umred Power

plant site to MSETCL substations or to Central Transmission Utility (CTU) Substations in

coordination with PGCIL.

Power map of 765 kV, 400 kV & 220 kV network in Maharashtra is shown below:


Feasibility Report

51

6 Socio Economic and Environmental

Aspects


Feasibility Report

52

Table of Contents

6.0 Socio Economic and Environmental Aspects ......................... 6-51

6.1 Socio Economic Profile and Development ....................... 6-51

6.2 Environmental Protection ................................................. 6-51

6.3 Ash Generation, Utilisation and Disposal ......................... 6-60

6.4 Green Belt ........................................................................ 6-61

6.5 Conclusion ........................................................................ 6-61


Feasibility Report

53

6.0 SOCIO ECONOMIC AND ENVIRONMENTAL ASPECTS

6.1 SOCIO ECONOMIC PROFILE AND DEVELOPMENT

There are no problems of displacement of population and no related impacts will be applicable

to the site since this proposed site is located within the boundary of existing coal mine in Umred.

Also livelihood is not affected as the proposed site doesn‟t cover any agricultural land.

Umred Karhandla wildlife sanctuary is located at a distance of 10.30 km from the proposed

power project site.

The project is expected to meet the future growing energy demand in the state and will have

a tremendous positive impact on enhancement in the economy of Maharashtra.

The proposed project is likely to have a positive impact on the socio-economic conditions of

the region. The social structure in the region is likely to change due to the creation of more

job opportunities and avenues for income generation. People will have higher incomes due to

direct employment as well as indirect employment and will have higher earning and buying

capacities.

The project would enable increase in the industries around the area due to improvement and

enhancement of water and other facilities. Creation of new infrastructure & up-gradation of

the existing infrastructure is likely to create a boost to the local economy and enhance the

quality of life of the people living in the region.

6.2 ENVIRONMENTAL PROTECTION

6.2.1 Introduction

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 in this chapter:

Air pollution

Water pollution

Sewage disposal

Thermal pollution

Noise pollution

Particulate matter

Pollution monitoring and surveillance systems


Feasibility Report

54

6.2.2 Air Pollution

The Air pollutants from the proposed units are:

Sulphur dioxide in flue gas

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.

6.2.3 Environment (Protection) Rules Amendment

Ministry of Environment, Forest and Climate Change, Government of India issued Gazette

notification on 7th December 2015 amending Environment (Protection) Rules, 1986. Amended

rules will be called Environment (Protection) Amendment Rule, 2015 and subsequently MOEF

issued draft Environment (Protection) Amendment Rules, 2017.

Emission standards for Thermal Power Plants as per Ministry of Environment, Forest and

Climate Change are given below:

Table 6.1 : Emission Standards as per MOEF


1 2 3 4

“5A.

Thermal Power plant

(Non sea water based

plants) (Water

consumption limit)

Water consumption

1. All Plants with Once Through Cooling (OTC) shall install Cooling Tower (CT) And achieve specific water consumption upto maximum of 3.5 m

3/MWh with in a period of

two years from the date of publication of this notification.

2. All existing CT -based plants reduce specific water consumption upto maximum of 3.5 m3/MWh MW with in a period of two years from the date of publication of this notification.

3. New plants to be installed after 1st January,

2017 shall have to meet specific water

consumption upto maximum of 3 m3/MWh

and achieve zero water discharged.

“25. Thermal Power Plants

TPPs (units) installed before 31st December, 2003*



Feasibility Report

55



600 mg/Nm3 (Units Smaller than 500MW

capacity units) 200 mg/Nm

3 (for units having capacity



3

Mercury(Hg) 0.03 mg/Nm



TPPs (units) installed after 1st

January,2003, upto 31st

December, 2016*



600 mg/Nm3 (Units Smaller than 500

MW capacity units) 200 mg/Nm



Oxides of Nitrogen (NOx) 300 mg/Nm

3


TPPs(units) to be installed from 1stJanuary,2017**


Sulphur Dioxide(SO2) 100 mg/Nm

3


3


a) This notification is effective from 7th December 2015.

b) As per the new rules all thermal power plant units, which are to be installed from 1st

January 2017 shall meet the following emission standards.

Table 6.2 : Emission Standards

Parameters Unit Standard

Particulate matter mg/Nm3 30

Sulphur Dioxide (SO2) mg/Nm3 100

Oxides of Nitrogen (NOX) mg/Nm3 100

Mercury (Hg) mg/Nm3 0.03


Feasibility Report

56

c) As per the new rules all thermal power plant units, which are to be installed from 1st

January 2017 shall meet the specific water consumption of 3 m3/MWh and achieve zero

water discharge.


Feasibility Report

57

6.2.3.1 SOx Emissions

As per the latest notification from Ministry of Environment, Forest and Climate change

thermal power stations to be installed from January 2017 shall be able to limit the Sulphur

Dioxide (SO2) to a level of 100 mg/Nm3.

It is necessary to use SO2 removal technology to bring down the SO2 level within the

permissible value. Wet FGD is proven technology used Worldwide for the control of SO2 from

utility power plants for high sulphur coal. It is proposed to install FGD system downstream of

ID fans for the power plant. FGD system is based on forced oxidation wet limestone process

with SO2 removal efficiency more than 95%.

In addition, sulphur dioxide level in ambient air shall be kept below permissible value 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:

Table 6.3 Stack Height Requirement for thermal power plants with FGD as per MOEF draft notification dated on 16

th October,2017

Generation Capacity Stack Height

100 MW and above

H=6.902(QXO.277)0.555

Or 100 m whichever is

more

Less than 100 MW

H=6.902(QXO.277)0.555 Or

30 m whichever is more

Where,

Q = Sulphur dioxide emission rate in kg/h

H = Physical Stack height in metres

With this, the stack height for the proposed power plant units under consideration will be

around 100 metres. However the stack height will be decided by MoEF based on the EIA

report.

The flue gas temperature at chimney inlet after installation of wet limestone FGD is around

100°C, which is below the acid dew point. Under this condition, the traces of SO3 present in

flue gas and moisture combine to form Sulphuric acid condensate on the internal surfaces of

the chimney flues. Hence internal anticorrosive lining for chimney flue can shall be provided.

The anticorrosive lining shall be of Borosilicate or high temperature poly glass flake.


Feasibility Report

58

6.2.3.2 NOx Emissions

At present, Advanced Low NOx combustion technology is used in all steam generator

combustion system with Low NOx burner and over fire air system. This will reduce the NOx

emission to a large extent. However, to meet the new emission standard in India, NOx

emission should be brought down to less than 100 mg/Nm3. Hence based on guaranteed NOx

emission that can be achieved with low NOx combustion technology by OEM, cost effective

post-combustion NOx control method is required to meet the current emission norms. In order

to meet the NOx emission level of 100 mg/Nm3, Selective Catalytic Reduction (SCR) method

will be provided.

6.2.3.3 CO Emissions

Carbon monoxide (CO) another kind of pollutant hardly exists in the modern power stations

as design of combustion control equipment and the furnace eliminates, almost completely the

possibility of incomplete combustion. The ground level concentration is expected to be within

the limit prescribed by Ministry of Environment and Forest.

6.2.3.4 Suspended Particulate Matter (SPM)

As per the latest notification from Ministry of Environment, Forest and Climate change

thermal power stations to be installed from January 2017 shall be able to limit the particulate

matter to a level of 30 mg/Nm3 and hence Electrostatic Precipitators (ESP) proposed in this

project will be designed to limit the emission level of particulate matter to 30 mg/Nm3 while

firing worst coal at 100% load.

6.2.3.5 Coal Dust Particles during Storage/Handling of coal

Dust generated in the coal handling area will be eliminated by providing suitable dust

suppression/extraction systems. Boiler bunkers will be provided with ventilation system with

bag filters to trap the dust in the bunkers. Wind barrier will be considered for coal stockpiles to

prevent coal dust from being carried by wind.

6.2.3.6 Mercury

The preliminary coal analysis does not indicate any mercury presence. Hence, no separate

mercury control system is envisaged. Based on the final coal analysis, if mercury traces are

available then necessary system requirement shall be provided.


Feasibility Report

59

6.2.4 Water Pollution

The wastewater treatment systems will be designed to collect and treat the various effluents

from the site, which are as follows:

Table 6.4 : Collection and Treatment of Various Effluents

Effluents Sources Method of treatment Disposal / Reuse

Oily wastes

Transformer yard,

TG hall floor wash

Fuel oil handling

area.

Tilted Plate interceptor,

oil skimmer to bring

down the treated water

oil level to less than

10 ppm.

Treated effluents are

reused for horticulture and

removed oil is taken offsite

for disposal.

Industrial

waste with high

suspended

solid levels

Boiler area floor

wash

Service water

wastes

Treatment through

Tilted Plate Interceptors

to reduce suspended

solid levels to within

PCB norms.

Treated effluents are

reused for horticulture and

sludge is disposed to ash

pond.

Chemical

contaminated

waste

DM Regeneration

waste

Neutralisation in a

neutralising pit to bring

the pH to acceptable

levels.

The acid and alkali

effluents generated during

the regeneration process

of the ion exchangers will

be drained into an

underground neutralizing

pit. The effluent will be

neutralized by the addition

of either acid or alkali to

achieve the required pH.

The effluent will then be

pumped for utilisation such

as ash handling plant by

effluent discharge pumps

and the excess will be

utilised for horticulture and

gardening purposes.

Sewage Canteen

Toilets

Sewage treatment Plant

where that sewage is

large and localised

anaerobic treatment

where generation of

sewage is limited.

Treated sewage is reused

for horticulture.

Cooling tower

blowdown

Cooling Tower No treatment is

envisaged.

Cooling tower blowdown

water will be used for ash

handling plant, coal

handling plant dust

suppression.

As per MOEF regulation, Zero water discharge philosophy will be followed for the proposed

plant for all the three configurations


Feasibility Report

60

6.2.5 Thermal Pollution

According to the Central Pollution Control Board stipulation, the thermal power plants using

river water should adopt closed cooling with cooling towers. For the proposed plant no hot

water discharge to ambient is envisaged.

6.2.6 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.

6.2.6.1 Equipment Noise

To achieve the noise limitations around the equipment, the main measures taken will be as

follows:

Providing noise enclosures for equipments with unacceptable noise levels.

Small units like condensate and vacuum pumps, will be designed so as to limit noise

emission,

Bypass valve, the desuperheater and the relevant piping will be covered with acoustic

insulation.

To achieve the noise limitations in the control room, the control equipment such as

computers and its accessories (printers, etc) and the air conditioning system will be

designed so as to limit noise emission.

During maintenance/inspection works, the personnel will wear ear

protections. 6.2.6.2 Far Field Noise

To achieve the far field noise limitations, the following main measures will be taken, as

appropriate for that purpose:

Steam vent pipes will be fitted with silencers.

The boiler thermal insulation will be designed to limit noise emission.

The boiler draught fans, the electrostatic precipitators and the air heaters will be

designed to limit noise emission.

The main transformers will be designed to limit noise emission.


Feasibility Report

61

Noise standards for the various areas/zone as per Central Pollution Control Board, 2001

Pollution Control Acts, Rules, and Notification issued there under are tabulated below:

Table 6.5 : Noise Standards

Area

Code Category of Area

Limits in dB(A)

Day Time (6 am to 9 pm)

Night Time (9 pm to 6 am)

A Industrial 75 70

B Commercial 65 55

C Residential 55 45

D Silence Zone 50 40

Notes;

1) dB(a) = decibel (acoustic).

2) Daytime is from 6 a.m. to 9 p.m.

3) dB(A) Leq denotes the time-weighted average of the level of sound in decibels on scale

A which is relatable to human hearing.

4) Night time is from 9 p.m. to 6 a.m.

5) Silence zone is defined as areas up to 100 meters around such premises as hospitals,

educational institutions, and courts.

The proposed site falls under the Industrial Area category.

6.2.7 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.

6.2.8 Air Quality Monitoring Programme

The purpose of air quality monitoring is acquisition of data for comparison against prescribed

standards, thereby ensuring that the quality of air is maintained within the permissible levels.


Feasibility Report

62

It is proposed to monitor the following from the stack emission:

Suspended particulate matter

Sulphur dioxide

Carbon Monoxide

Nitrogen oxides

For this purpose, it is proposed to acquire monitoring equipment as per following methods of

measurement:

Table 6.6 : Methods of Measurement for Monitoring Equipment

Sl. No. Emission

Parameters Measurement Methods

1. Particulates Gravimetric (High volume sampler ) , online

2. SO2 Barium Perchlorate-Thorin indicator method

3. NOX Chemiluminescence, Non Dispersive Infra Red, Non Dispersive Ultra-violet (for continuous measurement), Phenol disulphonic method

4. CO Non Dispersive Infra Red

It is proposed to monitor particulate emission qualitatively and quantitatively on the stack and

with the aid of a continuous particulate stack monitoring system. The stack monitoring data

would be utilised to keep a continuous check on the performance of ESPs.

Further it is proposed to monitor and record the weather parameters such as temperature

(Maximum. & Minimum), humidity, wind direction, wind speed, rainfall etc. on daily basis, for

this purpose, it is proposed to install Weather Monitoring Station with necessary gadgets.

6.3 ASH GENERATION, UTILISATION AND DISPOSAL

6.3.1 Ash Generation

The Ash generated in the plant with maximum ash content of 45.0 % considering 85% PLF

and the coal calorific value of 3000 kcal/kg is as follows:

Description Unit 1X 800 MW

Total Ash Generation TPD 6042

MTPA 1.87

Bottom Ash Generation

TPD 1208

MTPA 0.37

Fly ash Generation TPD 4834

MTPA 1.50


Feasibility Report

63

6.3.2 Ash Utilisation and Disposal

Fly ash has high pozzolonic properties and form cementaceous material when mixed with

lime and water and it is suitable for the following commercial uses:

a) Cement Industry

b) Brick Industry

c) Light Weight Aggregates

d) Road Sub-base

e) Grouting material

f) Roads / paving - used as filler in asphalt mix for roads.

g) Road enlargement

h) Land filling material

MoEF in their notification 3rd November 2009 has proposed that the fly ash utilization has to

be 100% during the fourth year from the date of commissioning of the plant.

Fly ash will be collected in dry form and transported to silos for discharging to the

consumers. The ash utilization will be partial during the initial period and will be gradually

increased to 100% during the fourth year from the date of commissioning of the plant. In

order to implement the stipulation by MoEF, Appropriate handling arrangement would be

envisaged for the following options:

Disposal of fly ash from silos to nearby small scale industries in road tankers

Dispatch of fly ash from silos to consumers through road tankers

The unutilized fly ash will be transported to the ash pond as high concentrate slurry using high

concentrate slurry pumps. All the bottom ash will be transported to ash pond in lean mode.

6.4 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.

6.5 CONCLUSION

Based on the above, it is observed that configurations have been designed to meet the

MOEF regulation.


Feasibility Report

64

7 Project Execution


Feasibility Report

65

Table of Contents

7.0 Project Execution ................................................................................................. 7-64

7.1 Method of Executing the Project .............................................................. 7-64

7.2 Project Completion Schedule ................................................................... 7-64

7.3 Logistics of Heavy Equipment .................................................................. 7-64

7.4 Project Development Requirements ........................................................ 7-64


Feasibility Report

66

7.0 PROJECT EXECUTION

7.1 METHOD OF EXECUTING THE PROJECT

The proposed project will be executed in EPC Turnkey basis including design, engineering,

manufacture, supply, erection, testing and commissioning of plant, equipment and facilities.

7.2 PROJECT COMPLETION SCHEDULE

The project completion schedule for the TPP is highlighted here under:.

1x 800 MW

For single unit of 800 MW plant, the unit will be put in to commercial operation in about 42

months reckoned from the zero date i.e. the date of award of the Letter of Award (LoA) for

EPC Contract.

7.3 LOGISTICS OF HEAVY EQUIPMENTS

Inland 660 MW plants are already in operation in the state of Maharashtra. For 800 MW plant

capacity, a logistics study to be conducted by EPC Contractor to inspect and examine the

site conditions and its surroundings, the transportation facilities available, the conditions of

roads, bridges, ports etc. for unloading and / or transporting heavy pieces of material.

7.4 PROJECT DEVELOPMENT REQUIREMENTS

Further to the finalisation of the configuration during the Feasibility study following project

development activities need to be initiated as a way forward:

Preparation of Detailed project report with cost estimates

Logistics study (shall be part of EPC Contract)

Site investigation, topography and geotechnical investigation

Lease agreement for the WCL land

Fuel Supply Agreement

Conducting EIA study and preparing Environment Management Plan (EMP) for the

project.

Treated waste water allocation from NMC and agreement

Water allocation from the Goshikhurd dam.

Study to finalise type of water intake system and its location

Study to finalise the Right of Way for water intake piping

Discussion with State/District authorities for approval for the water intake and pipe line

laying and Right of way


Feasibility Report

67

Environmental clearance from Ministry of Environment, Forest and Climate change

Consent to Establish from State Pollution Control Board.

Approval from civil aviation authority for Chimney

To take up with MSETCL to finalise the transmission line network for power evacuation

from the plant.

Study to finalise the Right of Way for transmission line.

Appoint of Owner‟s Engineer for the Execution of the project


Feasibility Report

68

8 Project Cost and Cost of Generation


Feasibility Report

69

Table of Contents

8.0 Project Cost and Cost of Generation ................................................................. 8-68

8.1 General..................................................................................................... 8-68

8.2 Basis for Project Cost ............................................................................... 8-68

8.3 Basis of Fixed Charge .............................................................................. 8-68

8.4 Basis of Variable Charge.......................................................................... 8-69

8.5 Project Cost Estimate (CAPEX) ............................................................... 8-69

8.6 Fixed Charge, Variable Charge and Cost of Generation ......................... 8-70


Feasibility Report

70

8.0 PROJECT COST AND COST OF GENERATION

8.1 GENERAL

Based on the feasibility 1 x800 MW is considered for the Project cost and Cost of generation

of the proposed plant . Basis of this estimation takes into consideration various aspects of the

plant configuration which will have bearing on CAPEX and OPEX. Landed cost of fuel is

calculated and determined considering the coal source of WCL at Umred mine.

8.2 BASIS FOR PROJECT COST

EPC cost include of FGD unit and SCR unit for SOx and NOx emission control to meet

Dec-2015 Environment Rules Amendment.

Treated water from Nagpur and Right of way of 45km / River water from Goshikhurd dam

and Right of way of 56 km is considered for water intake.

Transmission line cost is not considered in the Power plant project cost since this will be

part of State Transmission Utility (MSETCL).

8.3 BASIS OF FIXED CHARGE

Technology : Ultra Supercritical

Steam Parameters at Turbine inlet : Main steam pressure 270 kg/cm2(a)

Main steam temperature 600°C

Reheat steam temperature 600°C

Plant Configuration considered : 1 x 800 MW

Site location : Heoti in Umred mine

Cooling Water : Treated waste water from Nagpur / River water

from Goshikhurd dam

Land required (Including of Ash : 1 x 800 MW: 499 acres pond, corridor for water, Township)

Land cost : Rs.2.00 Lacs/ acre for Right of way for water piping.

Land Lease charges for the Power plant land is Rs. 25000 / acre with escalation of 5% per annum.

Debt : Equity : 80%: 20%

Interest Rate : 9.45 % p.a.


Feasibility Report

71

8.4 BASIS OF VARIABLE CHARGE

Design Coal : 100% Indian Coal (G 13 coal grade of WCL Umred mine )

Coal Analysis : Refer Appendix – 3

GCV of fuel : 3400 kCal/kg

Landed cost of fuel : Refer Appendix - 2 for details of cost of coal

Indian coal : Rs. 1623 / Ton

Plant Heat Rate : 2098 kCal / kWh for 800 MW

(considering the factor as per CERC)

Variable charge : Based on the above.

Fixed charge : Based on Project Cost & CERC norms.

8.5 PROJECT COST ESTIMATE (CAPEX)

Key Description 1x800 MW

BTG

BOP

Taxes & duties

EPC Cost

2129

1666

692

4487

Rs. Cr/MW 5.61

Land and Site development 43

Water Intake system and piping 355

Total Erected Cost 4885

Rs. Cr/MW 6.11

Cost towards Establishment, Consultancy and Contingency 280

IDC & FC 760

Margin Money 94

Project Cost (CAPEX) 6019

Rs. Cr/MW 7.52


Feasibility Report

72

Project Cost is based on preliminary estimate and in-house cost data taking into

consideration of the prevailing EPC cost.

Benchmark Capital Cost (Hard cost) for Thermal Power Stations with Coal as Fuel issued

by CERC on 2012 for 2x660 MW, 2x 800 MW and 1 x 800 MW are 5.01, 4.79 and 4.96

Crores / MW respectively.

Reference project cost (based on the data available in public domain).

BTG cost and BOP cost for Dr Narla Tata Rao Thermal Power Station for Andhra

Pradesh Power Generation Corporation Ltd in Vijayawada, Stage – V

(1X800MW) is Rs.2307 crores and Rs.2300 crores respectively (in the year of

EPC cost of Wanakbori Supercritical Thermal Power Project Unit-8, 1X800 MW is

around 3500 Crores (without FGD and SCR)

8.6 FIXED CHARGE, VARIABLE CHARGE AND COST OF GENERATION

Description Unit 1x800 MW

Station Heat Rate (Gross) kcal/kWh 2098

Auxiliary Power Consumption % 5.25

Net Heat Rate kcal/kWh 2214.68

Gross Calorific Value kcal/kg 3400

Cost of Fuel Rs./Ton 1623

Fixed Charge (First Year) Rs./kWh 1.98

Variable Charge (First Year) Rs./kWh 1.17

Cost of Generation (First Year)

Rs./kWh 3.15

Levelised Tariff

for 25 Years Rs./kWh 3.05

Levelised Tariff for 30 Years

Rs./kWh 3.08

Payback Years 17

Note : Levelised tariff for 25 years is followed considering the plant design life as per CERC.


Feasibility Report

73

9 Analysis and Conclusion


Feasibility Report

74

Table of Contents

9.0 Analysis and Conclusion .................................................................................... 9-73

9.1 Comparative Analysis ............................................................................... 9-73

9.2 Analysis and Observations ....................................................................... 9-73

9.3 Analysis of Project Cost and Cost of Generation ..................................... 9-74

9.4 Conclusion ................................................................................................ 9-75


Feasibility Report

75

9.0 ANALYSIS AND CONCLUSION

9.1 COMPARATIVE ANALYSIS

Land requirement, Water consumption, Coal requirement (design coal), Power evacuation

facilities have been worked out for the three configurations.

The Summary of the three configurations are tabulated hereunder:

Description Unit 2 x 660 MW 1 x 800 MW 2 x 800 MW

1 Land Acers 689 499 778

2 Water consumption per annum

3 Coal consumption per annum (Considering GCV of 3400 kcal/kg)

Million Cubic Meter

Million tonnes

29.48 17.87 35.74

6.11 3.68 7.36

4 Power evacuation 20 km of 400 kV Double circuit up

to LILO and additional One double circuit

220 kV transmission line

to be planned

20 km of 400 kV Double

circuit up to LILO to be considered.

20 km of 400 kV Double circuit up

to LILO and Additional

400 kV single circuit

transmission line to be planned

9.2 ANALYSIS AND OBSERVATIONS

a) Between three plant configurations under study with regard to land, the total land

requirement for 1 x 800 MW is less than the 2 x 660 MW and 2 x 800 MW considering

the water storage of 10 days, coal storage for 15 days and ash utilisation as per MOEF

norms.

b) For all the three configurations requirement of water can be met from the Treated waste

water from NMC and River water from Goshikurd dam.

c) Between three plant configurations with regard to coal, based on the projected

production target from coal mine and the coal balance scenario of WCL, coal

requirement is for 1x800 MW configuration only.


Feasibility Report

76

d) With regard to Power evacuation, existing 400 kV transmission line of MSETCL, between

Khaperkeda and Chandrapur, (which is passing at about 20 km distance from the

proposed Umred plant) can be exercised through LILO arrangement and laying 20 km

Double circuit line from Umred plant to LILO point. This arrangement will be adequate for

1x800 MW (Subject to MSETCL‟s confirmation. Whereas for 2X 660 MW plant, either

additional 400 kV line or one double circuit 220 kV transmission line up to nearby grid

substation will be required. For 2X800 MW plant, in addition to LILO arrangement,

additional 400 kV transmission line need to be planned.

e) For all the three configuration “Right of way” for pumping Waste water pipe from Nagpur

which is at distance of 42 km and River water Intake pipe from Goshikhurd dam which is

at distance of 56 km to the proposed site is required.

f) For all the three configuration “Right of way” for the transmission lines including 52 m

corridor for 20 km distance from the Bhivad LILO point to the proposed site is required.

g) All the three configuration will be designed to meet new environmental norms.

h) All the three configurations have the necessary infrastructure facilities.

9.3 ANALYSIS OF PROJECT COST AND COST OF GENERATION

Considering the feasibility, Project cost and Cost of generation have been worked out for the 1

x 800 MW and 2 x 800 MW are presented hereunder :

The Summary of the two configurations are tabulated hereunder:

Description Unit 1 x 800 MW 2 x 800 MW

1 Project Cost Rs.Crs/ 7.52 6.97

MW

2 Cost of generation

- Fixed cost Rs./kWhr 1.98 1.87

- Energy cost Rs./kWhr 1.17 1.17

- Cost of Generation (First Rs./kWhr 3.15 3.04

Year) - Levelised Tariff For 25 Rs./kWhr 3.05 2.96

Years

- Levelised Tariff for 30 Rs./kWh 3.08 2.99

Years

- Payback Years 17 17


Feasibility Report

77

9.4 CONCLUSION

From the techno economic evaluation, it can be seen that land availability and Water

requirement are met for all the three configurations .The Power evacuation is also not a

constraint for any of three configurations above. The project cost and the cost of

generation do not vary widely between the various options. The cost / MW for CAPEX

and the cost of generation is the lowest for 2 x 800 MW followed by 1 x 800 MW.

However it is observed that, the coal requirement vis- a-vis coal availability is met only

for the 1 x 800 MW configuration.

For 1 x 800 MW configuration, Mahagenco shall take a confirmation from WCL for supply

of coal for a period of 25 years with necessary allocation from WCL Umred mines by

readjusting the coal supply to other consumers of WCL Umred mines.

Considering the limitation imposed by coal availability from Umred mine it is suggested

that a plant configuration of 1 x 800 MW can be adopted for the proposed project.

However, in the event Mahagenco want to opt for 2 x 800 MW configuration considering

the operational flexibility of having two units, Mahagenco shall look for a suitable source

of coal for the additional requirement of around 4.33 million tonnes in additional to the

long term contract from WCL Umred mine.


Feasibility Report

78

List of Appendices


Appendix - 2 Landed Fuel Cost at site for Indian Coal

Appendix - 3 Coal Analysis

Appendix - 4 Coal Generation in WCL Umred Coal Mine

Appendix - 5 Coal Balance Scenario


Feasibility Report

79



Feasibility Report

80

Appendix – 1.0

Key Features of the Project Site

I

1.

PLANT LOCATION DATA

Location

a. Village / City : Heoti

b. District : Umred Tahsil, Nagpur District

c. State : Maharashtra

2. Longitude & Latitude :

3. Elevation above sea level (mean sea level) : 280 m (based on Umred MSL)

4. Nearest Railway Station : Umred & 6 km

5. Nearest Airport : Nagpur & 42 km

6. Nearest Harbour : Mumbai (Around 850 km)

7. Access Road (National / State Highway) : Around 5 km from MSH 9 state highway

8. Availability of effluent discharge facilities : --

9. Terrain of land : Uneven& backfilled soil for more than 30 years

10. Type of land : -

11. Whether the land is within irrigation command : Yes / No

12. Present status of land

II ENVIRONMENTAL DATA

1. Ambient temperature :

a. Max. dry bulb temp. : 47.8°C

b. Min. dry bulb temp. : 3.9°C

c. Design temperature for electrical equipment

/ device : 50


Feasibility Report

81

2. Relative Humidity

a . Max imum (Mean va lue o f summer months ) : 85%

b . Min imum (Mean va lue o f summer months ) : 61%

3. Rainfall

a. Max. recorded in 24 hrs. : 280.2 mm Annual rainfall

b. M a x . i n t e n s i t y o f r a i n f a l l p e r h o u r :

c. Period

- Monsoon showers :

- Summer showers :

4. Tropicalisation required for equipment : No

5. Wind Data

a . Maximum wind speed :

b . Minimum wind speed :

c . Wind direction :

6. Seismic Data

a. Zone : III

b. Basic horizontal Seismic coefficient : As per IS : 1893 2005

c. Importance factor : As per IS : 1893 2005

7. General nature of soil : Back filled soil (more than 30 years inside the Mine area)


Feasibility Report

82

Appendix – 2 Landed Fuel Cost at Site for Indian Coal


Feasibility Report

83

Appendix – 2.0

Landed Fuel Cost at Site for Indian Coal

1.0 Landed Cost of Fuel

Coal cost at WCL Umred mine end will be considered as the basis to arrive at landed cost.

a) Cost at Mine end

Basis for calculating landed WCL coal mine end are as follows:

1. Coal grade : G13 (exceeding 3400 and not exceeding

3700)

2. Basic Rate : Rs. 860 / tonne

3. Processing/crushing charges : Rs. 79 / tonne

4. Stowing excise duty SED : Rs. 10 / tonnes

5. STC ( Surface transport) : Rs. 57/ tonnes

6. Royalty : 14% of on basic price

7. MMDR ROY CFUND : 2% on Royalty

8. MMDR ROY CFUND : 30% on Royalty

9. Clean Environment cess : Rs.400 / tonne

10. GST : 5%

Coal cost at WCL Umred Mine end is RS 1623/ Tonne for G13 grade coal.

Source: Data provided by MAHAGECO / WCC data


Feasibility Report

84

Appendix – 3

Coal Analysis


Feasibility Report

85

Appendix – 3.0

Coal Analysis [ WCL coal at Umred Mine]

Proximate Analysis (As Received Basis)

Unit

Indian Coal

Design Coal Worst Coal

Total Moisture % 14.50 --

Ash % 42.00 --

Volatile Matter % 16.00 --

Fixed Carbon % 27.50 --

Sulphur % 0.60 --

GCV (As Received Basis)

kcal/kg 3400* 3000*

“*” Data provided by MAHAGECO, other‟s are based on database


Feasibility Report

86

Appendix – 4 Coal Generation in WCL Umred Coal Mine


Feasibility Report

87

ppendix – 4.0

Coal Generation in WCL Umred Coal Mine

Yearly Production of Coal in WCL Umred Area

Name of Mine

Total reserve

of coal in MMT

Nominal Capacity

in MT

Mine Operation starting

date

Life up to Year


2017-18 2018-19 2019-20

Dinesh 87.36 4.0 Oct 2016 2040 2.6 3.5 3.75

Umrer 20.58 2.0 April 2016 2021 3.15 3.1 3.2

MKD-I 34.68 2.0 Dec 2014 2032 1.65 1.7 2

Gokul 15.30 1.5 May 2015 2025 1.65 1.8 1.8

Total 157.92 9.5

9.05 10.10 10.75

Source: Data provided by MAHAGENCO


Feasibility Report

88

Appendix – 5 Coal Balance Scenario


Feasibility Report

90

Appendix – 5.0

Coal Balance Scenario (Figures in Million Tonnes)

S.No. Particulars

2018-19 2019-20 2020-21 2021-22 2022-23 2023-24 2024-25 2025-26 2026-27 2027-28 2028-29 2029-30 F

SA

Qty

(M

illi

on

ton

n)

Qty

at

Tri

gg

er

Le

ve

l (M

illio

n t

on

n)

FS

A Q

ty (

Mil

lio

n

ton

n)

Qty

at

Tri

gg

er

Le

ve

l (M

illio

n t

on

n)

FS

A Q

ty (

Mil

lio

n

ton

n)

Qty

at

Tri

gg

er

Le

ve

l (M

illio

n t

on

n)

FS

A Q

ty (

Mil

lio

n

ton

n)

Qty

at

Tri

gg

er

Le

ve

l

(Mil

lio

n t

on

n)

FS

A Q

ty (

Mil

lio

n

ton

n)

Qty

at

Tri

gg

er

Le

ve

l (M

illio

n t

on

n)

FS

A Q

ty (

Mil

lio

n

ton

n)

Qty

at

Tri

gg

er

Le

ve

l (M

illio

n t

on

n)

FS

A Q

ty (

Mil

lio

n

ton

n)

Qty

at

Tri

gg

er

Le

ve

l

(Mil

lio

n t

on

n)

FS

A Q

ty (

Mil

lio

n

ton

n)

Qty

at

Tri

gg

er

Le

ve

l (M

illio

n t

on

n)

FS

A Q

ty (

Mil

lio

n

ton

n)

Qty

at

Tri

gg

er

Le

ve

l (M

illio

n t

on

n)

FS

A Q

ty (

Mil

lio

n

ton

n)

Qty

at

Tri

gg

er

Le

ve

l (M

illio

n t

on

n)

FS

A Q

ty (

Mil

lio

n

ton

n)

Qty

at

Tri

gg

er

Le

ve

l

(Mil

lio

n t

on

n)

FS

A Q

ty (

Mil

lio

n

ton

n)

Qty

at

Tri

gg

er

Le

ve

l (M

illio

n t

on

n)

1 Production 50 55 60 60 60 50 60 60 60 60 60 60

A Existing commitments through FSAs, MOUs

and Linkage Auction 61.753 52.253 55.498 45.999 51.875 42.375 51.875 42.371 51.875 42.371 51.875 42.376 51.876 42.375 61.876 42.375 1.875 42.375 51.876 42.376 51.875 42.375 51.575 42.376

B FSA to be executed with Power sector 2.008 1.601 7.696 6.72 7.696 5.441 3.43 1.601 2.008 1.601 2.008 1.601 2.008 1.601 2 1.501 2 1.601 2.008 1.601 2.008 1.601 2.008 1.601

C Other LOA commitments 10.276 7.505 10.276 7.606 10.276 7.505 10.276 7.505 10.276 7.505 10.776 7.505 10.276 7.505 10.276 7.605 10.276 7.605 10.276 7.505 10.276 7.505 10.276 7.505

D Spot e-Auction 5 6 5.5 5.5 6 5 6 0 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6

E Other Auctions (Exclusive / Special Forward /

Special spot etc.) 4.846 4.845 5 5 5.5 5.5 6.6 5.5 5.6 5.5 5.5 5.5 5.5 5.5 5 5.6 5.5 5.6 5.5 5.5 5.5 5.5 6.5 6.5

F Total Commitment 79.036 66.359 78.969 66.724 75.846 62.601 71.58 57.481 70.158 57.481 70.158 57.481 70.158 57.481 70.158 57.481 70.158 57.481 70.158 57.481 70.158 57.481 70.158 57.481

G Net shortfall -29.036 -16.369 -23.969 -10.724 -15.646 -2.601 -11.54 2.519 10.158 2.519 -10.158 2.519 -10.158 2.519 10.158 2.519 -10.158 2.519 -10.158 2.513 -10.253 2.519 -10.168 2.519

Source: Data provided by MAHAGENCO


Feasibility Report

91

List of List of Exhibit Exhibit - 1 Key Plan

Exhibit - 2 Typical Plot Plan 1 x 800 MW

Exhibit - 3 Site grade in Plot are

Exhibit - 4 Study Area

Exhibit -5 Location of Coal Mines w.r.t. TPP

Exhibit -6 Location of TPP on Google

Exhibit -7 Distance of Umred TPP from ES area of Karhandla Wildlife Sanctuary


Feasibility Report

92

Exhibit -1: Key Map


Feasibility Report

93

Exhibit – 2: Typical HMBD for 1 x 800 MW with Supercritical Parameters


Feasibility Report

94

Exhibit- 3


Feasibility Report

95

Exhibit 4: Study Area


Feasibility Report

96

Exhibit 5: Location of Dinesh, Makardhokra, Umred and Gokul Coal Mines w.r.t. TPP.


Feasibility Report

97

Exhibit 6: Location of TPP on Google.


Feasibility Report

98

10.30 KM. Karhandla Wildlife Sanctuary

Exhibit 7: Distance of Umred TPP from ES area of Karhandla Wildlife Sanctuary


Feasibility Report

99

Environmental Setting for MAHAGENCO Umred TPP (10 km)

Sr No Particulars Details

1. Project 1 x 800 MW Ultra Supercritical Pit Head Thermal Power Plant

2. Project location Village : Heoti, Tehsil: Umred, District: Nagpur (Maharashtra)

3. Latitude 20°52'2.35"N

4. Longitude 79°16'31.28"E

5. Elevation above MSL 914 ft (278.58 mt)

6. Toposheet 55 P/1, 55 P/0, 55 P/5, 55 P/6

7. Present landuse Mined out area

8.

Climatic conditions

(Based on nearest IMD station data

Nagpur)

Maximum Temperature : 47.8°C

Minimum Temperature : 3.9°C

Relative Humidity (Summer Months) : 61 to 85%

Annual Rainfall : 280.2 mm

9. Nearest National Highway/State Highway SH - 9 (Gadchiroli-Nagpur Hwy) : 1.5 Km (E)

SH – 262 : 1.0 Km (S)

10. Nearest Airport/ Air Strip Nagpur Airport: 33 Kms (NW)

11. Nearest town Umred: 5.0 Km (ESE)

12. Forest

Muniya Reserved Forest : 6.0 km (SW)

Bhivapur Reserved Forest : 7.0 km (NW)

Chichla Reserve Forest : 10 Km (S)

13. Ecologically Sensitive Zones like wild life

sanctuaries, national parks and biospheres No

14. Water Bodies Amb River: Through project site

Pandharboli Talav: 5.0 km (S)


Feasibility Report

100

Umred Lake : 4.5 Km (ESE)

Makardhokra Reservoir: 5.5 Km (W)

Paradgaon Lake: 7.0 Km : (NW)

Ukkarwahi Talav: 8.0 km (NW)

Undri Nadi: 7.5 km (NE)

15. Seismic Zone Zone III (Moderate)

Environmental Setting for MAHAGENCO Umred TPP (15 km)

Sr No Particulars Details

16. Project 1 x 800 MW Ultra Supercritical Pit Head Thermal Power Plant

17. Project location Village : Heoti, Tehsil: Umred, District: Nagpur (Maharashtra)

18. Latitude 20°52'2.35"N

19. Longitude 79°16'31.28"E

20. Elevation above MSL 914 ft (278.58 mt)

21. Toposheet 55 P/1, 55 P/0, 55 P/5, 55 P/6

22. Present landuse Mined out area

23. Climatic conditions

(Based on nearest IMD station data Nagpur)

Maximum Temperature : 47.8°C

Minimum Temperature : 3.9°C

Relative Humidity (Summer Months) : 61 to 85%

Annual Rainfall : 280.2 mm

24. Nearest National Highway/State Highway SH - 9 (Gadchiroli-Nagpur Hwy) : 1.5 Km (E)

SH – 262 : 1.0 Km (S)

25. Nearest Airport/ Air Strip Nagpur Airport: 33 Kms (NW)

26. Nearest town Umred: 5.0 Km (ESE)

27. Forest Muniya Reserved Forest : 6.0 km (SW)

Bhivapur Reserved Forest : 7.0 km (NW)


Feasibility Report

101

Chichla Reserve Forest : 10 Km (S)

Ranbori Reserve Forest (Karhandla Wildlife sanctuary) : 10.30

Km (E)

28. Ecologically Sensitive Zones like wild life

sanctuaries, national parks and biospheres Karhandla Wildlife Sanctuary : 10.30 Km (E)

29. Water Bodies

Amb River: Through project site

Pandharboli Talav: 5.0 km (S)

Umred Lake : 4.5 Km (ESE)

Makardhokra Reservoir: 5.5 Km (W)

Paradgaon Lake: 7.0 Km : (NW)

Ukkarwahi Talav: 8.0 km (NW)

Undri Nadi: 7.5 km (NE)

Khapri Talav: 12.0 Km (NW)

Kalandri Talav: 11.0 Km (N)

Kolarmet Talav: 12.0 Km (N)

SonegaonTalav: 12.5 Km (N)

Botejhari Talav : 14.0 km (SSE)

Mangli Talav : 15.0 Km (NW)

30. Seismic Zone Zone III (Moderate)


Feasibility Report

102

DEMOGRAPHIC DATA OF UMRER TAHSIL

S. No.

VILLAGE NAME

Tahsil NO OF POPULATION SC ST LITERATES

HOUSEHOLDS TOTAL M F M F M F M F

1 Paradgaon Umred 42 235 120 115 36 38 40 35 75 61

2 Saiki Umred 140 628 313 315 52 44 3 2 235 161

3 Dahegaon Umred 56 282 144 138 0 0 107 108 94 61

4 Makardhokada Umred 973 4631 2375 2256 288 301 387 347 1691 1228

5 Welsakra Umred 227 990 507 483 259 234 38 44 350 244

6 Heoti Umred 303 1425 726 699 163 157 6 6 534 359

7 Shirpur Umred 277 1211 603 608 185 162 16 22 467 369

8 Kanwha Umred 159 772 401 371 184 174 0 0 315 220

9 Kumbhari Umred 54 254 132 122 2 2 54 53 81 57

10 Mohpa Umred 83 410 214 196 55 59 44 44 155 102

11 Dhurkheda Umred 243 1093 568 525 390 354 81 82 412 288

12 Thana Umred 174 733 388 345 127 107 44 38 266 170

13 Lohara Umred 118 536 275 261 94 96 2 5 198 133

14 Dewli Umred 110 453 222 231 4 4 62 60 119 100

15 Khairi (Ka) Umred 19 45 30 15 2 1 10 4 22 6

16 Tambekhani (m) Umred 49 230 129 101 39 30 48 38 84 49

17 Amgaon Umred 126 604 295 309 108 106 18 19 182 151

18 Murzadi Umred 32 164 90 74 37 25 40 41 54 35

19 Mendhepathar Umred 3 14 8 6 0 0 8 6 5 2

20 Pipardol Umred 69 253 131 122 92 78 9 11 88 62

21 Khursapar Umred 162 696 352 344 121 119 13 14 241 186

22 Kalamana Umred 212 886 452 434 168 176 11 7 313 218

23 Godhani Umred 95 383 194 189 169 159 0 0 126 93

24 Telkawadsi Umred 23 123 65 58 0 0 6 3 40 27

25 Junoni Umred 73 311 161 150 39 26 0 0 123 82

26 Dongargaon Umred 22 119 65 54 1 1 5 2 39 26

27 Dighori Umred 15 54 24 30 18 19 1 3 8 8

28 Masala Umred 27 113 62 51 0 0 27 23 30 11


Feasibility Report

103

S. No.

VILLAGE NAME

Tahsil NO OF POPULATION SC ST LITERATES

HOUSEHOLDS TOTAL M F M F M F M F

29 Umred (M Cl) Umred 10046 49577 25454 24123 3596 3405 4304 4202 20492 16283

Total 13932 67225 34500 32725 6229 5877 5384 5219 26839 20792

948.55 12106 10603 84.70 57.65

% 51.32 48.68 18.01 15.77 71.17

maharashtra state power generation co ltd feasibility ... state power generation co ltd feasibility...

Documents